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Home My WebLink About210-069By Samantha Carlisle at 9:28 am, Jan 04, 2021 12/22/2020 VTL 3/9/21 SFD 1/13/2021RBDMS HEW 1/25/2021 DSR-1/6/21 Well Name: OP12-01 OR Wellbore Name: OP12-01 Well Code: 23972 Job: WORKOVER WCEI Level: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 11/27/2020 Report #: 1 Page: 1 of 2 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 54.58 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rigs Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Rig Start Date 11/26/2020 Rig Release Date Daily Information Weather Overcast Temperature (°F) 2.5 Wind N @ 5 MPH Days LTI (days) Days RI (days) POB 36.0 Cost Summary Job Account 200287 Currency Code USD Total AFE Amount (Cost) 7,550,000 Daily Cost (Cost) 187,382 Cumulative Cost (Cost) 187,382 Daily Mud Field Est (Cost) 5,520 Cumulative mud Cost (Cost) 5,520 . Safety Incidents - Near Miss Date 11/27/2020 Category Type Subtype Severity Cause Lost time? No Comment Review and discussed one of the 7Cs: Competency, Discussed one of the Eni 12 Golden Rules: Lifting. Safety Drills Type # Occur Last Date Next Date Days Until Next Check (days) Safety Meeting 1 11/27/2020 11/28/2020 1 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date CASING 13 3/8 12.42 L-80 0.0 2,421.0 2,173.7 7/19/2010 CASING 9 5/8 8.68 L-80 -0.8 5,510.0 3,618.0 7/26/2010 LINER 5 1/2 4.89 L80 4,115.2 11,534.0 3,653.1 8/6/2010 Last Cementing Cementing Start Date:7/27/2010 String:CASING, 5,510.0ftKB Comment:Good returns during the job. Stg # Top (ftKB) Top Meas Meth Btm (ftKB) Com 2 35.7 5,510.0 Schlumberger pump 5 bbls. H2O & test lines to 4000 psi. - OK \ Pump 75 bbls. of 10.5 ppg Mudpush II @ 5.1 bpm with 410 psi. \ Drop bottom plug \ Batch mix & pump 110 bbls. of 12.5 ppg Deep Crete cement (404 sks) 1.54 ft3/sk yield with mix fluid @ 5.133 gal/sk @ 5.1 bpm with 732 psi.\ Drop top plug \ Schlumberger pump 5 bbls. H2O for wash -up \ Rig pump displace cement with 398 bbls. of 8.9 ppg mud @ 5 bpm, ICP 250 psi. - slow pump rate to 3 bpm @ 650 psi. @ 384 bbls away \ Bump plug to 1150 psi. (500 psi. over FCP @ 650 psi.) \ Hold for 2 minutes - bleed off & check floats - holding \ Full return through out job. CIP @ 1600 hrs.\ Reciprocated casing until 20.5 bbls. left to displace \ taking weight & land in hanger, PU=220K, SO=145K. Top of cement @ 3700' Job Information Job Phase WORKOVER Planned Start Date 11/27/2020 00:00 Start Date 11/27/2020 00:00 End Date P50 Duration (days) 15.00 P50 Cost (Cost) 7,550,000 Daily Summary Operations 24h Forecast Kill well as per well plan. Install BPV and Nipple down tree/ Nipple up BOPE. Perform BOP testing. 24h Summary Accept rig at 0001 HRS. Move rig to well OP12-01, set up and secure location. Rig to High Line, fill pits with brine and bleed down well pressures. Rig up kill line system to well. Operation at 07.00 Installing back pressure valve to nipple down tree. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. End Depth (ftKB) 00:00 12:00 12.00 12.00 MOB A 2 P Rig accepted @ 0001 hrs. PJSM and move rig to well OP12-01. Rig is set up on double matts. Lower BOP enclosure. 12:00 18:00 6.00 18.00 W.O. A 1 P Berm around rig and remove unneeded matts. Spot High Line unit, cuttings tank and berm. Rig up High Line unit to power cables. Install High Line protectors on 13.8K cable. 18:00 00:00 6.00 24.00 W.O. M 1 P Load pits with 9.0 PPG brine. Open well bay permit, spot bleed trailer and bleed down Tubing and IA pressures starting at OA 170, IA 202, TBG 240. Rig up on the IA and tubing for killing operations. Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas (%) Max Connection Gas (%) Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (%) Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Losses (bbl) Cum Additions (bbl) Additions (bbl) Cum Losses (bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Mike Grubb ASRC Energy Services Co. Man Michael.Grubb@external.eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Mark Hubler Beacon HSE mark.hubler@external.eni.com 907-685-1434 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Tool Push Al Hanson Nordic Toolpusher al.hanson@nordic-calista.com 907-685-1470 Safety Representative Matt Meinhold Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note Tesla Tesla Electrician 12.00 0 ASRC SOA 12.00 1 ASRC Lift Advisor 12.00 1 Beacon HSE 12.00 1 GE OIL & GAS Vetco Gray Wellhead Rep 12.00 1 SCHLUMBERGER / MI Swaco Mud Man 12.00 1 ASRC Energy Services Company Man 24.00 2 ARCHER Archer 24.00 2 Worley Equipment Operators 12.00 6 NORDIC CALISTA ONSHORE RIGS 24.00 21 Well Name: OP12-01 OR Wellbore Name: OP12-01 Well Code: 23972 Job: WORKOVER WCEI Level: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 11/27/2020 Report #: 1 Page: 2 of 2 BOP Stack & Components Description BOP Stack Start Date 11/27/2020 Last Certification Date 10/25/2020 Pressure Rating (psi) 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular Hydril GK 500 13 5/8 5,000.0 10/9/2020 Blind Shear Ram Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 2 7/8 x 5 1/2 Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 4 1/2 Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 Slow Circulation Rates Pump Number: Make:Model: Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Daily Bulk Supply Item Description:Equipment Fuel Unit Label:gal us Unit Size: Note: Date 11/27/2020 Consumed 134.0 Received 134.0 Returned Cum Consumed 134.0 Cum Received 134.0 Cum Returned 0.0 Cum On Loc 0.0 Note Supply Item Description:Rig Fuel Unit Label:gal us Unit Size: Note: Date 11/27/2020 Consumed 626.0 Received 8,875.0 Returned Cum Consumed 626.0 Cum Received 8,875.0 Cum Returned 0.0 Cum On Loc 8,249.0 Note Supply Item Description:Rig Water Unit Label:bbl Unit Size: Note: Date 11/27/2020 Consumed 14.0 Received 155.0 Returned Cum Consumed 14.0 Cum Received 155.0 Cum Returned 0.0 Cum On Loc 141.0 Note Last Authority Visit Date Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com NORDIC-CALISTA SERVICES 2PJSM General Notes Comment: Well Name: OP12-01 OR Wellbore Name: OP12-01 Well Code: 23972 Job: WORKOVER WCEI Level: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 11/28/2020 Report #: 2 Page: 1 of 2 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 54.58 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rigs Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Rig Start Date 11/26/2020 Rig Release Date Daily Information Weather Overcast Temperature (°F) 1.9 Wind NE @ 8 MPH Days LTI (days) Days RI (days) POB 41.0 Cost Summary Job Account 200287 Currency Code USD Total AFE Amount (Cost) 7,550,000 Daily Cost (Cost) 191,168 Cumulative Cost (Cost) 378,550 Daily Mud Field Est (Cost) 1,104 Cumulative mud Cost (Cost) 6,624 . Safety Incidents - Near Miss Date 11/28/2020 Category Type Subtype Severity Cause Lost time? No Comment Review and discussed one of the 7Cs: Commitment, Discussed one of the Eni 12 Golden Rules: Working at Heights. Safety Drills Type # Occur Last Date Next Date Days Until Next Check (days) Safety Meeting 2 11/28/2020 11/29/2020 1 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date CASING 13 3/8 12.42 L-80 0.0 2,421.0 2,173.7 7/19/2010 CASING 9 5/8 8.68 L-80 -0.8 5,510.0 3,618.0 7/26/2010 LINER 5 1/2 4.89 L80 4,115.2 11,534.0 3,653.1 8/6/2010 Last Cementing Cementing Start Date:7/27/2010 String:CASING, 5,510.0ftKB Comment:Good returns during the job. Stg # Top (ftKB) Top Meas Meth Btm (ftKB) Com 2 35.7 5,510.0 Schlumberger pump 5 bbls. H2O & test lines to 4000 psi. - OK \ Pump 75 bbls. of 10.5 ppg Mudpush II @ 5.1 bpm with 410 psi. \ Drop bottom plug \ Batch mix & pump 110 bbls. of 12.5 ppg Deep Crete cement (404 sks) 1.54 ft3/sk yield with mix fluid @ 5.133 gal/sk @ 5.1 bpm with 732 psi.\ Drop top plug \ Schlumberger pump 5 bbls. H2O for wash -up \ Rig pump displace cement with 398 bbls. of 8.9 ppg mud @ 5 bpm, ICP 250 psi. - slow pump rate to 3 bpm @ 650 psi. @ 384 bbls away \ Bump plug to 1150 psi. (500 psi. over FCP @ 650 psi.) \ Hold for 2 minutes - bleed off & check floats - holding \ Full return through out job. CIP @ 1600 hrs.\ Reciprocated casing until 20.5 bbls. left to displace \ taking weight & land in hanger, PU=220K, SO=145K. Top of cement @ 3700' Job Information Job Phase WORKOVER Planned Start Date 11/27/2020 00:00 Start Date 11/27/2020 00:00 End Date P50 Duration (days) 15.00 P50 Cost (Cost) 7,550,000 Daily Summary Operations 24h Forecast Continue rigging up BOP equipment, test BOPE. 24h Summary Bull head tubing with 80 BBLS 9.0 PPG brine followed with 425 BBLS down Annulus A. Monitor well for 60 min. Well on vac. Install BPV and nipple down tree. Nipple up riser then BOPE equipment. Crane de- completion equipment to rig floor. Pump 10 BPH down IA. Operation at 07.00 Rigging BOP equipment. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. End Depth (ftKB) 00:00 07:30 7.50 7.50 W.O. M 9 P Continue to bleed off well. Bullhead 80 bbls of 9.0 ppg brine tubing at 3 BPM, 1069 psi. Bullhead 425 bbls of 9.0ppg brine down annulus at 3 bbls per minute. Monitor well for 1 hour, tubing and annulus on vac. Blow down kill hoses and rig down. Load pits with brine. Work on Archer punch list, PVT system and pumps. 07:30 10:00 2.50 10.00 W.O. C 5 P Set BPV and N/D tree. Clean bowl and install false bowl installation plate. Cut and cap chemical injection line and install blanking plug. 10:00 12:00 2.00 12.00 W.O. C 5 P Pick up and make up riser. Pick up single gate and spool and make up. Pick up double gate and make up. Continue to nipple up BOPE. 12:00 15:00 3.00 15.00 W.O. C 5 P Continue with Nipple up BOPE. Spot GBR equipment. 15:00 17:00 2.00 17.00 W.O. C 5 P Continue to nipple up BOPE. Simops PJSM for Crane operations, open permit. Load all de-completion equipment to rig floor. 17:00 00:00 7.00 24.00 W.O. C 5 P Continue to nipple up BOPE. Make up test joint and install. Function test BOP components. Pumping 10 BPH down Annulus A. Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas (%) Max Connection Gas (%) Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (%) Mud Type: FW - KCI/NaCI - -- Depth (ftKB) Density (lb/gal) 9.00 Funnel Viscosity (s/qt) 27 PV Calc (cP) YP Calc (lbf/100ft²) pH Chlorides (mg/L) Electric Stab (V) Solids (%) Sand (%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (m) Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Loss 62.0 Tank 347.8 Hole 460.2 Cumulative Mud Volumes Active Volume (bbl) 808.0 Hole Volume (bbl) 460.2 Losses (bbl) 62.0 Cum Additions (bbl) 0.0 Additions (bbl) 0.0 Cum Losses (bbl) 62.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Mike Grubb ASRC Energy Services Co. Man Michael.Grubb@external.eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Mark Hubler Beacon HSE mark.hubler@external.eni.com 907-685-1434 Well Name: OP12-01 OR Wellbore Name: OP12-01 Well Code: 23972 Job: WORKOVER WCEI Level: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 11/28/2020 Report #: 2 Page: 2 of 2 Daily Contacts Position Contact Name Company Title Email Office Mobile Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Tool Push Al Hanson Nordic Toolpusher al.hanson@nordic-calista.com 907-685-1470 Safety Representative Matt Meinhold Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note ASRC SOA 12.00 1 ASRC Lift Advisor 12.00 1 Beacon HSE 12.00 1 GE OIL & GAS Vetco Gray Wellhead Rep 12.00 1 SCHLUMBERGER / MI Swaco Mud Man 12.00 1 ASRC Energy Services Company Man 12.00 2 ARCHER Archer 12.00 2 GBR Tubing hands 12.00 2 Baker Centrilift 12.00 3 Worley Equipment Operators 12.00 6 NORDIC CALISTA ONSHORE RIGS 12.00 21 BOP Stack & Components Description BOP Stack Start Date 11/27/2020 Last Certification Date 10/25/2020 Pressure Rating (psi) 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular Hydril GK 500 13 5/8 5,000.0 10/9/2020 Blind Shear Ram Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 2 7/8 x 5 1/2 Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 4 1/2 Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 Slow Circulation Rates Pump Number: Make:Model: Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Daily Bulk Supply Item Description:Equipment Fuel Unit Label:gal us Unit Size: Note: Date 11/28/2020 Consumed 455.0 Received 455.0 Returned Cum Consumed 589.0 Cum Received 589.0 Cum Returned 0.0 Cum On Loc 0.0 Note Supply Item Description:Rig Fuel Unit Label:gal us Unit Size: Note: Date 11/28/2020 Consumed 698.0 Received 0.0 Returned Cum Consumed 1,324.0 Cum Received 8,875.0 Cum Returned 0.0 Cum On Loc 7,551.0 Note Supply Item Description:Rig Water Unit Label:bbl Unit Size: Note: Date 11/28/2020 Consumed 13.0 Received 0.0 Returned Cum Consumed 27.0 Cum Received 155.0 Cum Returned 0.0 Cum On Loc 128.0 Note Last Authority Visit Date Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com NORDIC-CALISTA SERVICES 2PJSM General Notes Comment: Well Name: OP12-01 OR Wellbore Name: OP12-01 Well Code: 23972 Job: WORKOVER WCEI Level: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 11/29/2020 Report #: 3 Page: 1 of 2 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 54.58 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rigs Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Rig Start Date 11/26/2020 Rig Release Date Daily Information Weather Overcast Temperature (°F) -0.2 Wind N @ 8 MPH Days LTI (days) Days RI (days) POB 43.0 Cost Summary Job Account 200287 Currency Code USD Total AFE Amount (Cost) 7,550,000 Daily Cost (Cost) 207,313 Cumulative Cost (Cost) 585,863 Daily Mud Field Est (Cost) 1,104 Cumulative mud Cost (Cost) 7,728 . Safety Incidents - Near Miss Date 11/29/2020 Category Type Subtype Severity Cause Lost time? No Comment Review and discussed one of the 7Cs: Culture, Discussed one of the Eni 12 Golden Rules: Management Change. Safety Drills Type # Occur Last Date Next Date Days Until Next Check (days) Authority Visit 1 11/29/2020 12/27/2020 28 BOP Pressure Test 1 11/29/2020 12/6/2020 7 Safety Meeting 3 11/29/2020 11/30/2020 1 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date CASING 13 3/8 12.42 L-80 0.0 2,421.0 2,173.7 7/19/2010 CASING 9 5/8 8.68 L-80 -0.8 5,510.0 3,618.0 7/26/2010 LINER 5 1/2 4.89 L80 4,115.2 11,534.0 3,653.1 8/6/2010 Last Cementing Cementing Start Date:7/27/2010 String:CASING, 5,510.0ftKB Comment:Good returns during the job. Stg # Top (ftKB) Top Meas Meth Btm (ftKB) Com 2 35.7 5,510.0 Schlumberger pump 5 bbls. H2O & test lines to 4000 psi. - OK \ Pump 75 bbls. of 10.5 ppg Mudpush II @ 5.1 bpm with 410 psi. \ Drop bottom plug \ Batch mix & pump 110 bbls. of 12.5 ppg Deep Crete cement (404 sks) 1.54 ft3/sk yield with mix fluid @ 5.133 gal/sk @ 5.1 bpm with 732 psi.\ Drop top plug \ Schlumberger pump 5 bbls. H2O for wash -up \ Rig pump displace cement with 398 bbls. of 8.9 ppg mud @ 5 bpm, ICP 250 psi. - slow pump rate to 3 bpm @ 650 psi. @ 384 bbls away \ Bump plug to 1150 psi. (500 psi. over FCP @ 650 psi.) \ Hold for 2 minutes - bleed off & check floats - holding \ Full return through out job. CIP @ 1600 hrs.\ Reciprocated casing until 20.5 bbls. left to displace \ taking weight & land in hanger, PU=220K, SO=145K. Top of cement @ 3700' Job Information Job Phase WORKOVER Planned Start Date 11/27/2020 00:00 Start Date 11/27/2020 00:00 End Date P50 Duration (days) 15.00 P50 Cost (Cost) 7,550,000 Daily Summary Operations 24h Forecast Pull tubing string to floor and lay down tubing hanger. Pull 4.5” tubing and lay down while spooling ESP and cap line. 24h Summary Perform shell test against blind rams. Make up 4.5” test joint and Test BOPE witnessed by AOGCC rep Adam Earl and Archer. Add 10 BPH 9.0 PPG brine down Annulus A. Operation at 07.00 Pulling tubing string @ 2,500' MD Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. End Depth (ftKB) 00:00 06:00 6.00 6.00 W.O. C 12 P Continue to nipple up BOPE. Pull short low pressure riser above annular and replace with long low pressure riser. Fill stack and find leaking blind ram door seal. Empty stack and open both blind and both VBR doors and inspect door seals, wipe and clean debris and retest. Leaky blind ram door leak. Empty stack and Replace ODS ram door seal. Attempt to retest and found leaky flange on Choke manifold valve #14, tighten flange and Perform shell test against blind rams, mud manifold valve #5 and choke manifold valves 11, 12, 13, and #5, Good shell test at 5,000 psi. 06:00 09:00 3.00 9.00 W.O. C 12 P Make up test joint and rig up test subs. Perform initial test on annular and blanking plug. 09:00 10:00 1.00 10.00 W.O. C 12 P Testing gas alarms, good test. 10:00 21:30 11.50 21.50 W.O. C 12 P Test BOPE to 5000 psi / 250 psi, annular 2500 psi / 250 psi with 4.5” and 4” test JTS. Witnessed by AOGCC and Archer. All test good. 21:30 00:00 2.50 24.00 W.O. C 5 P Rig down testing equipment, make up floor safety valve, install mouse hole, change out grabber dies, hang cap line sheave and prep pipe shed for laying down tubing. Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas (%) Max Connection Gas (%) Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (%) Mud Type: FW - KCI/NaCI - -- Depth (ftKB) Density (lb/gal) 9.00 Funnel Viscosity (s/qt) PV Calc (cP) YP Calc (lbf/100ft²) pH Chlorides (mg/L) Electric Stab (V) Solids (%) Sand (%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (m) Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Loss 199.0 Tank 438.8 Hole 460.2 Cumulative Mud Volumes Active Volume (bbl) 899.0 Hole Volume (bbl) 460.2 Losses (bbl) 199.0 Cum Additions (bbl) 0.0 Additions (bbl) 0.0 Cum Losses (bbl) 261.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Mike Grubb ASRC Energy Services Co. Man Michael.Grubb@external.eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Well Name: OP12-01 OR Wellbore Name: OP12-01 Well Code: 23972 Job: WORKOVER WCEI Level: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 11/29/2020 Report #: 3 Page: 2 of 2 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Mark Hubler Beacon HSE mark.hubler@external.eni.com 907-685-1434 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Tool Push Al Hanson Nordic Toolpusher al.hanson@nordic-calista.com 907-685-1470 Safety Representative Matt Meinhold Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note ASRC SOA 12.00 1 ASRC Lift Advisor 12.00 1 ARCHER Archer 12.00 1 Beacon HSE 12.00 1 GE OIL & GAS Vetco Gray Wellhead Rep 12.00 1 SCHLUMBERGER / MI Swaco Mud Man 12.00 1 ASRC Energy Services Company Man 12.00 2 GBR Tubing hands 12.00 3 Baker Centrilift 12.00 5 Worley Equipment Operators 12.00 6 NORDIC CALISTA ONSHORE RIGS 12.00 21 BOP Stack & Components Description BOP Stack Start Date 11/27/2020 Last Certification Date 10/25/2020 Pressure Rating (psi) 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular Hydril GK 500 13 5/8 5,000.0 10/9/2020 Blind Shear Ram Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 2 7/8 x 5 1/2 Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 4 1/2 Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 Slow Circulation Rates Pump Number: Make:Model: Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Daily Bulk Supply Item Description:Equipment Fuel Unit Label:gal us Unit Size: Note: Date 11/29/2020 Consumed 323.0 Received 323.0 Returned Cum Consumed 912.0 Cum Received 912.0 Cum Returned 0.0 Cum On Loc 0.0 Note Supply Item Description:Rig Fuel Unit Label:gal us Unit Size: Note: Date 11/29/2020 Consumed 608.0 Received 0.0 Returned Cum Consumed 1,932.0 Cum Received 8,875.0 Cum Returned 0.0 Cum On Loc 6,943.0 Note Supply Item Description:Rig Water Unit Label:bbl Unit Size: Note: Date 11/29/2020 Consumed 32.0 Received 0.0 Returned Cum Consumed 59.0 Cum Received 155.0 Cum Returned 0.0 Cum On Loc 96.0 Note Last Authority Visit Date 11/29/2020 Tot insp. Nbr Total I.N.C. number Comment AOGCC Adam Earl Witnessed BOP Test next test due 12/6/2020. STOP Cards Submitted Company # Rpts Com NORDIC-CALISTA SERVICES 2PJSM General Notes Comment: Well Name: OP12-01 OR Wellbore Name: OP12-01 Well Code: 23972 Job: WORKOVER WCEI Level: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 11/30/2020 Report #: 4 Page: 1 of 2 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 54.58 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rigs Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Rig Start Date 11/26/2020 Rig Release Date Daily Information Weather Overcast Temperature (°F) 7.7 Wind NE @ 21 MPH Days LTI (days) Days RI (days) POB 44.0 Cost Summary Job Account 200287 Currency Code USD Total AFE Amount (Cost) 7,550,000 Daily Cost (Cost) 205,914 Cumulative Cost (Cost) 791,777 Daily Mud Field Est (Cost) 1,104 Cumulative mud Cost (Cost) 8,832 . Safety Incidents - Near Miss Date 11/30/2020 Category Type Subtype Severity Cause Lost time? No Comment Review and discussed one of the 7Cs: Change of Management, Discussed one of the Eni 12 Golden Rules: Energized Systems. Safety Drills Type # Occur Last Date Next Date Days Until Next Check (days) Authority Visit 1 11/29/2020 12/27/2020 27 BOP Pressure Test 1 11/29/2020 12/6/2020 6 Safety Meeting 4 11/30/2020 12/1/2020 1 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date CASING 13 3/8 12.42 L-80 0.0 2,421.0 2,173.7 7/19/2010 CASING 9 5/8 8.68 L-80 -0.8 5,510.0 3,618.0 7/26/2010 LINER 5 1/2 4.89 L80 4,115.2 11,534.0 3,653.1 8/6/2010 Last Cementing Cementing Start Date:7/27/2010 String:CASING, 5,510.0ftKB Comment:Good returns during the job. Stg # Top (ftKB) Top Meas Meth Btm (ftKB) Com 2 35.7 5,510.0 Schlumberger pump 5 bbls. H2O & test lines to 4000 psi. - OK \ Pump 75 bbls. of 10.5 ppg Mudpush II @ 5.1 bpm with 410 psi. \ Drop bottom plug \ Batch mix & pump 110 bbls. of 12.5 ppg Deep Crete cement (404 sks) 1.54 ft3/sk yield with mix fluid @ 5.133 gal/sk @ 5.1 bpm with 732 psi.\ Drop top plug \ Schlumberger pump 5 bbls. H2O for wash -up \ Rig pump displace cement with 398 bbls. of 8.9 ppg mud @ 5 bpm, ICP 250 psi. - slow pump rate to 3 bpm @ 650 psi. @ 384 bbls away \ Bump plug to 1150 psi. (500 psi. over FCP @ 650 psi.) \ Hold for 2 minutes - bleed off & check floats - holding \ Full return through out job. CIP @ 1600 hrs.\ Reciprocated casing until 20.5 bbls. left to displace \ taking weight & land in hanger, PU=220K, SO=145K. Top of cement @ 3700' Job Information Job Phase WORKOVER Planned Start Date 11/27/2020 00:00 Start Date 11/27/2020 00:00 End Date P50 Duration (days) 15.00 P50 Cost (Cost) 7,550,000 Daily Summary Operations 24h Forecast Run in hole with new ESP completion as per ENI plan and set. 24h Summary Pull BPV, make up landing joint to tubing head and back out lock down screws. Pull tubing hanger and false bowl out @ 200K. De-complete hanger. Pull out of hole with ESP completion. Crane lift old spools and install new completion equipment. Make up new ESP completion and service. Operation at 07.00 Running in hole with 4 1/2" ESP completion string at 250' MD. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. End Depth (ftKB) 00:00 02:00 2.00 2.00 W.O. L 5 P Pull BPV and well on a vac. Make up landing joint and back out upper and lower lock down screws. Work tubing hanger free at 200K and pull hanger to rig floor. 02:00 03:30 1.50 3.50 W.O. L 5 P Disassembly tubing hanger and lay down. Rig up tubing tongs. 03:30 10:30 7.00 10.50 W.O. L 4 P Pull out of hole with ESP completion laying down tubing and spooling ESP and cap line from 3982’. Total of 94 JTS 10:30 13:30 3.00 13.50 W.O. L 5 P Disassemble and lay down ESP completion equipment. 13:30 14:30 1.00 14.50 W.O. L 1 P Secure ESP cable & cap line spools with absorb and shrink wrap. Clear and clean rig floor, organize pipe shed and prep for craning operations. 14:30 19:00 4.50 19.00 W.O. K 1 P Lift plan meeting and permit to work. Off load de-completion spools and load new completion spools and completion components to rig and stage for pick up. 19:00 00:00 5.00 24.00 W.O. K 5 P PJSM, Make up shroud and ESP assembly and service same. Install cap lines and plug in MLE cable. Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas (%) Max Connection Gas (%) Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (%) Mud Type: FW - KCI/NaCI - -- Depth (ftKB) Density (lb/gal) 8.97 Funnel Viscosity (s/qt) PV Calc (cP) YP Calc (lbf/100ft²) pH Chlorides (mg/L) Electric Stab (V) Solids (%) Sand (%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (m) Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Loss 224.0 Tank 197.0 Hole 477.6 Cumulative Mud Volumes Active Volume (bbl) 674.6 Hole Volume (bbl) 477.6 Losses (bbl) 224.0 Cum Additions (bbl) 0.0 Additions (bbl) 0.0 Cum Losses (bbl) 485.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Mike Grubb ASRC Energy Services Co. Man Michael.Grubb@external.eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Well Name: OP12-01 OR Wellbore Name: OP12-01 Well Code: 23972 Job: WORKOVER WCEI Level: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 11/30/2020 Report #: 4 Page: 2 of 2 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Mark Hubler Beacon HSE mark.hubler@external.eni.com 907-685-1434 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Tool Push Al Hanson Nordic Toolpusher al.hanson@nordic-calista.com 907-685-1470 Safety Representative Matt Meinhold Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note ASRC SOA 12.00 1 ASRC Lift Advisor 12.00 1 ARCHER Archer 12.00 1 Beacon HSE 12.00 1 GE OIL & GAS Vetco Gray Wellhead Rep 12.00 1 SCHLUMBERGER / MI Swaco Mud Man 12.00 1 ASRC Energy Services Company Man 12.00 2 GBR Tubing hands 12.00 3 Baker Centrilift 12.00 6 Worley Equipment Operators 12.00 6 NORDIC CALISTA ONSHORE RIGS 12.00 21 BOP Stack & Components Description BOP Stack Start Date 11/27/2020 Last Certification Date 10/25/2020 Pressure Rating (psi) 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular Hydril GK 500 13 5/8 5,000.0 10/9/2020 Blind Shear Ram Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 2 7/8 x 5 1/2 Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 4 1/2 Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 Slow Circulation Rates Pump Number: Make:Model: Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Daily Bulk Supply Item Description:Equipment Fuel Unit Label:gal us Unit Size: Note: Date 11/30/2020 Consumed 434.0 Received 434.0 Returned Cum Consumed 1,346.0 Cum Received 1,346.0 Cum Returned 0.0 Cum On Loc 0.0 Note Supply Item Description:Rig Fuel Unit Label:gal us Unit Size: Note: Date 11/30/2020 Consumed 569.0 Received 0.0 Returned Cum Consumed 2,501.0 Cum Received 8,875.0 Cum Returned 0.0 Cum On Loc 6,374.0 Note Supply Item Description:Rig Water Unit Label:bbl Unit Size: Note: Date 11/30/2020 Consumed 15.0 Received 120.0 Returned Cum Consumed 74.0 Cum Received 275.0 Cum Returned 0.0 Cum On Loc 201.0 Note Last Authority Visit Date 11/29/2020 Tot insp. Nbr Total I.N.C. number Comment AOGCC Adam Earl Witnessed BOP Test next test due 12/6/2020. STOP Cards Submitted Company # Rpts Com NORDIC-CALISTA SERVICES 2PJSM General Notes Comment: Well Name: OP12-01 OR Wellbore Name: OP12-01 Well Code: 23972 Job: WORKOVER WCEI Level: 3 Selected table has no valid attachments that can be displayed Daily Report Date: 12/1/2020 Report #: 5 Page: 1 of 2 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 54.58 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rigs Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Rig Start Date 11/26/2020 Rig Release Date Daily Information Weather Overcast Temperature (°F) 7.7 Wind NE @ 17 MPH Days LTI (days) Days RI (days) POB 48.0 Cost Summary Job Account 200287 Currency Code USD Total AFE Amount (Cost) 7,550,000 Daily Cost (Cost) 224,152 Cumulative Cost (Cost) 1,015,929 Daily Mud Field Est (Cost) 1,104 Cumulative mud Cost (Cost) 9,936 . Safety Incidents - Near Miss Date 12/1/2020 Category Type Subtype Severity Cause Lost time? No Comment Review and discussed one of the 7Cs: Communication, Discussed one of the Eni 12 Golden Rules: Working at Heights. Safety Drills Type # Occur Last Date Next Date Days Until Next Check (days) Authority Visit 1 11/29/2020 12/27/2020 26 BOP Pressure Test 1 11/29/2020 12/6/2020 5 Safety Meeting 5 12/1/2020 12/2/2020 1 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date CASING 13 3/8 12.42 L-80 0.0 2,421.0 2,173.7 7/19/2010 CASING 9 5/8 8.68 L-80 -0.8 5,510.0 3,618.0 7/26/2010 LINER 5 1/2 4.89 L80 4,115.2 11,534.0 3,653.1 8/6/2010 Last Cementing Cementing Start Date:7/27/2010 String:CASING, 5,510.0ftKB Comment:Good returns during the job. Stg # Top (ftKB) Top Meas Meth Btm (ftKB) Com 2 35.7 5,510.0 Schlumberger pump 5 bbls. H2O & test lines to 4000 psi. - OK \ Pump 75 bbls. of 10.5 ppg Mudpush II @ 5.1 bpm with 410 psi. \ Drop bottom plug \ Batch mix & pump 110 bbls. of 12.5 ppg Deep Crete cement (404 sks) 1.54 ft3/sk yield with mix fluid @ 5.133 gal/sk @ 5.1 bpm with 732 psi.\ Drop top plug \ Schlumberger pump 5 bbls. H2O for wash -up \ Rig pump displace cement with 398 bbls. of 8.9 ppg mud @ 5 bpm, ICP 250 psi. - slow pump rate to 3 bpm @ 650 psi. @ 384 bbls away \ Bump plug to 1150 psi. (500 psi. over FCP @ 650 psi.) \ Hold for 2 minutes - bleed off & check floats - holding \ Full return through out job. CIP @ 1600 hrs.\ Reciprocated casing until 20.5 bbls. left to displace \ taking weight & land in hanger, PU=220K, SO=145K. Top of cement @ 3700' Job Information Job Phase WORKOVER Planned Start Date 11/27/2020 00:00 Start Date 11/27/2020 00:00 End Date P50 Duration (days) 15.00 P50 Cost (Cost) 7,550,000 Daily Summary Operations 24h Forecast Land and complete the 4.5" ESP completion as per procedure and planned tally. 24h Summary Pick up the 4.5" ESP and 7 5/8" shroud. Complete all "prep" completion checklists and service the ESP motor and pumps. RIH w/ the 4.5" Completion to Joint #11. Find a damaged spot in the ESP cable and diagnose the line with OHM checks. Decision is made to POOH to surface and replace the ESP spool. Conduct a lift meeting and swap out the Esp cable via Worley Crane. Make up the MLE splice and have ENI electrical witness. RIH w/ 4.5" completion while utilizing the GBR torque turn equipment to 2809'. Operation at 07.00 Performing ESP penetrator slice. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. End Depth (ftKB) 00:00 04:30 4.50 4.50 W.O. K 5 P Pick up the 4.5" ESP and 7 5/8" shroud. Complete all "prep" completion checklists and service the ESP motor and pumps. Ensure the motors are topped off with oil and the pump / motor connections arte torqued with all clamp bolts. 04:30 06:30 2.00 6.50 W.O. K 12 P Pressure test the CAP line to 4000 psi and open the check valve. Monitor the CAP line pressure throughout the job moving forward. Test the ESP MLE connection and make up the connector to the ESP motor. 06:30 10:00 3.50 10.00 W.O. K 4 P Begin RIH w/ 4.5" coated 563 Pipe and find damage in the ESP cable while making up on joint #11. Decision is made to POOH to surface and replace the ESP cable 10:00 15:00 5.00 15.00 W.O. K 4 TD03 POOH with ESP completion string. Mobilize and prep the ESP cable spooler to replace the ESP cable with the new designated cable. Conduct the lift meeting with the Worley Crane Crew, ENI Production DSO and Lead, ENI Lift advisor and all Nordic Personnel. Review and mitigate all hazards and verify all responsibilities and tasks are covered. Complete the ESP spool swap via lift plan procedure. 15:00 16:30 1.50 16.50 W.O. K 12 TD03 Complete the MLE connector splice with Centrilift personnel and ENI Electrician witnessing. Verify OHM readings and test the ESP cable via ENI Procedure. 16:30 17:30 1.00 17.50 W.O. K 4 TD03 PJSM, Run in hole with ESP completion till 500’. 17:30 00:00 6.50 24.00 W.O. K 4 P Continue run in hole with 4.5" ESP completion to 2809', 69k DW. MLE splice 12' in on joint #1. Test ESP cable every 1000'. Pump 10 BPH down Annulus A. Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas (%) Max Connection Gas (%) Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (%) Mud Type: FW - KCI/NaCI - -- Depth (ftKB) Density (lb/gal) 9.00 Funnel Viscosity (s/qt) PV Calc (cP) YP Calc (lbf/100ft²) pH Chlorides (mg/L) Electric Stab (V) Solids (%) Sand (%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (m) Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Loss 253.0 Tank 234.0 Hole 477.6 Cumulative Mud Volumes Active Volume (bbl) 711.6 Hole Volume (bbl) 477.6 Losses (bbl) 253.0 Cum Additions (bbl) 0.0 Additions (bbl) 0.0 Cum Losses (bbl) 738.0 Well Name: OP12-01 OR Wellbore Name: OP12-01 Well Code: 23972 Job: WORKOVER WCEI Level: 3 Selected table has no valid attachments that can be displayed Daily Report Date: 12/1/2020 Report #: 5 Page: 2 of 2 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Chad Gueco ASRC Energy Services Co. Man Chad.Gueco@external.eni.com 907-685-0710 907-232-2289 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Mark Hubler Beacon HSE mark.hubler@external.eni.com 907-685-1434 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Tool Push Al Hanson Nordic Toolpusher al.hanson@nordic-calista.com 907-685-1470 Safety Representative Matt Meinhold Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note ASRC SOA 12.00 1 ASRC Lift Advisor 12.00 1 ARCHER Archer 12.00 1 Beacon HSE 12.00 1 GE OIL & GAS Vetco Gray Wellhead Rep 12.00 1 SCHLUMBERGER / MI Swaco Mud Man 12.00 1 ASRC Energy Services Company Man 12.00 3 GBR Tubing hands 12.00 3 Baker Centrilift 12.00 6 Worley Equipment Operators 12.00 9 NORDIC CALISTA ONSHORE RIGS 12.00 21 BOP Stack & Components Description BOP Stack Start Date 11/27/2020 Last Certification Date 10/25/2020 Pressure Rating (psi) 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular Hydril GK 500 13 5/8 5,000.0 10/9/2020 Blind Shear Ram Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 2 7/8 x 5 1/2 Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 4 1/2 Schaefer LXT 5000 13 5/8 5,000.0 10/25/2020 Slow Circulation Rates Pump Number: Make:Model: Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Daily Bulk Supply Item Description:Equipment Fuel Unit Label:gal us Unit Size: Note: Date 12/1/2020 Consumed 517.0 Received 517.0 Returned Cum Consumed 1,863.0 Cum Received 1,863.0 Cum Returned 0.0 Cum On Loc 0.0 Note Supply Item Description:Rig Fuel Unit Label:gal us Unit Size: Note: Date 12/1/2020 Consumed 698.0 Received 0.0 Returned Cum Consumed 3,199.0 Cum Received 8,875.0 Cum Returned 0.0 Cum On Loc 5,676.0 Note Supply Item Description:Rig Water Unit Label:bbl Unit Size: Note: Date 12/1/2020 Consumed 14.0 Received 0.0 Returned Cum Consumed 88.0 Cum Received 275.0 Cum Returned 0.0 Cum On Loc 187.0 Note Last Authority Visit Date 11/29/2020 Tot insp. Nbr Total I.N.C. number Comment AOGCC Adam Earl Witnessed BOP Test next test due 12/6/2020. 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Casing13-3/8", 68 # 2,421 MD, 2,174 TVD51º Inc. Interm. Casing 9-5/8", 47 #5,527' MD, 3,620' TVD85º Inc.4-½” 12.6ppf TK-15XT L80 Hydril-563 Production Tubing (Internal Coated)Slotted Liner,5-½” 17 ppf11,534 MD, 3,647 TVD90ºIncHAL Zonal Isolation Swell Packers4-½” cable clamps, for ESP Power Cable,Q.ty(1) 3/8" Chem. Inj LineConfidentialOP12-01Oil Producer withESP LiftNikaitchuq Field – Oliktok Point PadTubing Hanger with 4" nom. Type “H” BPV profile4,111' MD / 3,193' TVD 55ºInc Baker SLXP Liner Hanger/Packer5-½” Silver Bullet Ecc. Nose Guide ShoeAs CompletedDec-3-20203,898.5' MD / 3063.7' TVD – DGU Assembly3,970.3' MD / 3108.2' TVD Bottom of 7-5/8" 29.7 ppf Shroud Assembly with cable, chemical injection ¼” line feed-thru3,972.2' MD / 3109' TVD, 53.3º Inc – Bottom of Motor CentralizerBHGE (ALS) ESP, 66-stage, Flex 47, 538 PMSXD pump, 250HP MTR 562XP motor3,967.5' MD / 3107.1' TVD – Motor Gauge MGUESP CableTD 12,860' MD/3,616' TVD STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Supry aio Zz'?, BOPE Test Report for: NIKAITCHUQ OP12-01 i Comm Contractor/Rig No.: Nordic 4 PTD#: 2100690 - DATE: 11/29/2020 - Inspector Adam Earl - Insp Source Operator: Eni US Operating Company Inc. Operator Rep: Grubb/Wimmer Rig Rep: Hiler/Hansen Inspector Test Pressures' Type Operation: WRKOV Sundry No: Type Test: INIT 320-436 , Rams: Annular. Valves: MASP: Inspection No: bopAGE201202131743 Related Insp No: 250/5000- 250/2500 - 250/50010 - 988 TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Quantity P/F Quantity Visual Alarm P/F Time/Pressure P/F Location Gen.: P_ Trip Tank _ P P_- System Pressure _ _ 300.0--- P_ Housekeeping: P Pit Level Indicators P P - Pressure After Closure 2050 P ' PTD On Location P Flow Indicator P " P 200 PSI Attained 22 P " Standing Order Posted P Meth Gas Detector FP ✓ FP Full Pressure Attained 79 P ' Well Sign P H2S Gas Detector P - P Blind Switch Covers: All Stations - P " Drl. Rig _ P-' MS Misc 0 _NA NA Nitgn. Bottles (avg): 4 (8),2925 • P " Hazard Sec. P ACC Misc 0 NA Misc NA NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly I P - Stripper - 0 NA No. Valves 14 - P Lower Kelly -- 1- P ' Annular Preventer 1 13518 _- FP Manual Chokes 1 P ' Ball Type 2 P #1 Rams I_ Blind/Shear -P - _ Hydraulic Chokes I - P-_ Inside BOP I P #2 Rams 1 2 7/8 x 5 1/2 P CH Misc 0 NA FSV Misc 0 NA #3 Rams 1 4.5" S.B. P #4 Rams 0 NA #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 31/8 P Quantity P/F HCR Valves 2 31/8 FP Inside Reel Valves __ 0_ NA Kill Line Valves 2 31/8 P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 4 / Test Results Test Time 12.5 Remarks: Both floor and pit methane failed . Re -Cal. All LEL. Heads and retest. The bag needed functioned to hold. FP. HCR choke FP. 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1RWH 6XSSO\,WHP'HVFULSWLRQ5LJ:DWHU 8QLW/DEHOEEO 8QLW6L]H 1RWH 'DWH &RQVXPHG 5HFHLYHG 5HWXUQHG &XP&RQVXPHG &XP5HFHLYHG &XP5HWXUQHG &XP2Q/RF 1RWH /DVW$XWKRULW\9LVLW 'DWH 7RWLQVS1EU 7RWDO,1&QXPEHU &RPPHQW $2*&&$GDP(DUO:LWQHVVHG%237HVWQH[WWHVWGXH 6723&DUGV6XEPLWWHG &RPSDQ\ 5SWV &RP 125',&&$/,67$6(59,&(6 3-60 *HQHUDO1RWHV &RPPHQW By Samantha Carlisle at 3:55 pm, Oct 13, 2020 320-436 BOPE test to 3500 psi. 24 hour notice to AOGCC to witness. MGR16OCT20 10-404 -00 DLB X DSR-10/15/2020DLB10/13/2020 10/20/2020 dts 10/20/2020 RBDMS HEW 11/12/2020 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.pierfelici@eni.com October 12th, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP12-01 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP12-01. OP12-01 was completed on Oliktok Point on August 9thth, 2010 with a TTC electric submersible pump set at a depth of 3,982’ MD. This ESP producer was completed without a packer. The well was operated until September 30th, 2011 when fluid stopped flowing to surface. The well was shut-in, a pump change-out was performed and the well was restarted on October 25th, 2011. Shortly thereafter, on October 31st, 2011, the well suffered an electrical failure; a workover was performed to pull the tubing and replace the TTC-ESP. In January 2018, a workover was performed to pull the TTC-ESP tubing completion and upgrade with a new conventional ESP system to increase production. The well has then been continually operated until August 9th, 2020, when the ESP suffered an electrical failure. Scope of this workover is to pull the current ESP tubing completion and recomplete with a new conventional ESP system and coated tubing. The estimated date for beginning this work is December 1st, 2020. 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 Alessio Medea at 907- 865-3347. Sincerely, Stefano Pierfelici Well Operations Project Manager OP12-01 Workover – Proposal Summary and Wellbore Schematic PTD#: 210-069 Current Status Well OP12-01 is currently shut down due to an ESP electrical failure occurred on August 9th, 2020. Scope of Work Scope of this workover is to pull the current ESP tubing completion and recomplete with a new conventional ESP system and coated tubing. Repair has to be completed with no HSE accidents or incidents, to comply with state AOGCC and company requirements. General Well Info Reservoir Pressure/TVD: The well is expected to have a static max bottom hole pressure of approximately 1,250 psi (3,620 ft 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 Well type: Producer TIFL/MIT-IA/MIT-OA: Intermediate 9-5/8” casing was tested to 1500 psi during workover on January 17th, 2018. Estimated start date: December 1st, 2020 Drilling Rig: Nordic Calista Rig 4 Drilling Engineer: Alessio Medea Alessio.medea@eni.com Work: 907-865-3347 Well Operations Project Manager: Stefano Pierfelici Stefano.pierfelici@eni.com Work: 907-865-3320 Procedure Summary 1. MURU Nordic Calista Rig 4; 2. Kill the well; 3. Set BPV; 4. N/D X-tree; 5. Set Blanking Plug; 6. N/U BOP and test to 250/3500 psi; 7. Pull out of hole Blanking Plug and BPV; 8. POOH tubing and lay down ESP assembly; 9. Perform a contingent clean-out run; 10. MU new ESP assembly and RIH new coated tubing to setting depth; 11. Land hanger and test it; 12. Install BPV; 13. N/D BOP; 14. N/U tubing adapter and X-tree; 15. Pull BPV; 16. Install Two Way Check Valve and test X-tree; 17. Circulate Freeze protect through X-tree down IA; 18. RDMO. 24 hour notice to AOGCC to witness. Below the current schematic of the well: Vetco Gray, MB-247/5000 psi • • iJilteactitAy 01)1z-0 Prb 2404,40 Regg, James B (DOA) From: Smith David <David.Smith@enipetroleum.com> on behalf of Enipetroleum OPPDrilling <OPPDrilling@enipetroleum.com> Sent: Wednesday,January 17, 2018 11:09 AM ( j 'Z f 16 To: Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Cc: Cesale Davide; Ravagli Bruno; Chaudhry Amjad Subject: OP12-01 Productio Casing Test 01-17-18 Attachments: OP12-01 Casing Test on 9.625_01-17-18.xlsx Gents, Attached is the Mechanical Integrity Test of OP12-01 production casing test(9-5/8"). Regards, David 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. SCAN €3 ';'. • 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reggt5lalaska.00v AOGCC.Inspectors(S(alaska.gov phoebe.brookst alaska.gov chris.wallace(Walaska.00v - OPERATOR: Eni Petroleum i FIELD/UNIT/PAD: Nikaitchuq/Oliktok Point Pad �.J P- ,I(1 DATE: 01/17/18 OPERATOR REP: Dr.Supervisor(Wimmer Russ/Smith David) AOGCC REP: Witness waived by Jeff Jones Well OP12-01 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 210-069<S Type Inj N Tubing 0 0 0 0 X X Type Test P Packer TVD 3096 BBL Pump 1.5 IA 0 1780 1750 1750' X X Interval 0 Test psi 1500 „ BBL Return 1.5 OA 180 260 260 260 X X Result P 4.--- Notes: Notes: 9-5/8"Production Casing Pressure Test at 1,500 psi requested by AOGCC in the Approved Sundry(318-004) Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test • Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval . Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval . Test psi BBL Return OA Result Notes: Well - Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 80 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes • W=Water P=Pressure Test 1=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance 1=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting • Form 10-426(Revised 01/2017) OP12-01 Casing Test on 9.625_01-17-18(002) .0.-‘•\ ,/,„,-t. THE STATE • Alaska ska Oil and Gas �,�►."'t^d��a of jLA S}(J\ Conservation Commission 'ittsi.# 333 West Seventh Avenue - GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 cI `, 'r'��r P Main: 907.279.1433 ALASY` Fax: 907.276.7542 www.aogcc.alaska.gov Stefano Pierfelici Well Operations Project Managera j, Eni US Operating Co. Inc. o��'� `!iyi\` 1 9 7 3 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP12-01 Permit to Drill Number:210-069 Sundry Number: 318-004 Dear Mr. Pierfelici: 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, Hollis S. French Chair DATED this day of January, 2018. RBDMS ---JAN 1 1 2%18 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 0 3018 APPLICATION FOR SUNDRY APPROVALS p:rS i ,° ( /g �""� 20 AAC 25.280 O G° C 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ 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 Drill Number: Eni US Operating Co.Inc. Exploratory ❑ Development Q- 210-069 e 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23426-00. 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 Er fie. OP12-01 ` 9.Property Designation(Lease Number): 10.Field/Pool(s): 355024,373301, 390616, 391283 - Nikaitchuq Schrader Bluff Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): • 12860 3616 • 11532 % 3647• 988 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 2421 13-3/8" 2421 2174 5,020 2,270 Intermediate 5527 9-5/8" 5527 3620 6,870 4,760 Production 11534 5-1/2" 11534 3647 slotted slotted Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5,527-11,534 • 3,620'-3,647 4-1/2" L-80 3,982 Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch n Exploratory ❑ Stratigraphic ❑ Development❑✓ • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL Q , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stefano Pierfelici Contact Name: Amjad Chaudhry Authorized Title: Well Operations Project Manager Contact Email: amiad.chaudhrvt eniDetroIeuracom Contact Phone: 907-865-3379 Authorized Signature: .7k. ,......)"" U _,N____ Date: Q ( lir] �( 1 8 COMMISSION U ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. /t i g r o Lt Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ �{, 'u( ((( Other: / 3506 r5, 61 Os" (e I / ) -V- Pet dl 44.4.41-; e b.._ -.5;,-.2 t" , C '4-' ;4.. Post Initial Injection MIT Req'd? Yes ❑ No ❑ J fes y� Spacing Exception Required? Yes ❑ NoAI � Subsequent Form Required: / 6 - 5 0 c% RBDMS '. L_ �,1„i 1 2:18 APPROVED BY I Approved by: COMMISSIONER THE COMMISSION Date: I I s )9,4z '1h1r6 ArI4& ORIGINAL f 'L k\- Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate t • . trojoil • Enil PetirolleLuimRECEIVED 3800 Centerpoint Drive Suite 300 JAN 3 2018 Anchorage,Alaska 99503 A"1oG C w Stefano Pierfelici Phone(907) 865-3320 Email: Stefano.pierfelici(a�enipetroleum.com January 3rd, 2018 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP12-01 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP 12-01. OP 12-01 was completed on Oliktok Point on August 9thth, 2010 with an TTC electric submersible pump set at a depth of 3,982' MD. This ESP producer was completed without a packer. The well was started up for production in August 2010 Scope of this workover is to pull the current TTC-ESP tubing completion and upgrade with a new conventional ESP system to increase production. / a_S;" 4t The estimated date for beginning this work is January 12`h, 2018. ° ' 2 t•i l 7 Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907- 865-3379. Sincerely, Stefano Pierfelici Well Operations Project Manager • • OP12-01 Workover— Summary Page OP12-01 Rig Workover PTD#:210-069 Current Status Well OP 12-01 is currently producing Scope of Work Scope of this workover is to pull the current TTC-ESP tubing completion and upgrade with a new conventional ESP system to increase production. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1,350 psi (3,620' TVD) during the time of work over, which places the fluid level well below surface. Wellhead type/pressure rating: Vetco Gray, MB-247/5,000 psi BOP configuration: Annular/pipe/blind rams 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 July 2010. Well type: Producer Estimated start date: January 12th 2018 '1-12 Drilling rig: Nordic 4 Completion Engineer: Amjad Chaudhry: amjad.chaudhry@enipetroleurn.com Work: 907-865-3379 Drilling & Completion Engineering Manager: Marc Kuck: Marc.Kuck@enipetroleum.com Work: 907-865-3322 Well Operations Project Manager: Stefano Pierfelici: Stefano.pierfelici@enipetroleum.com Work: 907-865-3320 • . Procedure: 1. MIRU Nordic 4. 2. Shear upper GLM valve and circulate 8.9 ppg brine with 3 % KCl kill fluid through tree. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. 4. Pull tubing to upper GLM. 5. Shear lower GLM valve and circulate 8.9 ppg brine with 3 %KC1 kill fluid 6. Circulate out remaining production fluid. 7. Continue POOH and lay down TTC ESP assembly. 8. Clean out and pumping a heavy weigh brine pill above csg window, POOH. 1 9. AMU new ESP assembly and RIH to setting depth. Rt, w—rei- , 10. Land hanger, and test it. pL�,,.4-a y"O 11. Install BPV and nipple down BOP. ,� C50 12. NU tubing adapter and tree. 13. Pull BPV, install test plug and test tree.( 5000 psi test) 11 15-112/5� 14. Circulate Freeze protect through tree down IA. / 15. Shut in well. C3 a` 16. RDMO. Below the current schematic of the well: EEMI l es U l"roNGNllnni Vacuum Insulated Tubing(VIT),4-/'x 5-%", 0P12-01 Mk approx 80',two joints Oil Producer with ESP Lift 4-'/,'12.8 ppf Production Tubing MI As Completed 4-W cable clamps.for ESP Power 69;10 Cable.{1)3/8"Chem Inj Line 3.788 MD,2.998'TVD,53°Inc.-GLM.KBMG 4-h"x 1 with 2.000 psi STS-1 SOV installed Surf.Casing 3,982 MD,3,116 TVD,53°Inc.—Bottom of Motor Centralizer 13-3/8 68# Centrilift TTC-ESP.62-stage 380P18 pump.513 GSB3DB seals. 126 HP MSP1 motor 2,421 MD, 2,174 TVO 51°Inc. ' 4,111'MD,3,197'TVD,58°Inc,- Baker SLXP Liner Hanger/Packer HAL Zonal Isolation 5-'/.-Silver Bullet Ecc. Swell Packers Nose Guide Shoe Nmoorm...." Interm Casing Slotted Liner. 9 5/8 47# 5-15"17 ppf 6.627'MO.3,620'TVD 11,634'MD, 85°Inc 3,647 TVD, Nikeitchuq Field- 90°Inc. Oliktok Poled Pad Confidential hr., r • • ( kielio ��z��t�� . . W 1 i v a 0 +_CO U c, zo a Z V O J W ct O Y D LA0 F : Z W Q. M U ce nnn 0 W d• _> Y CL _� 22 >, U , i 1 QW 11161 460 . iiir. 0 IN Z °a U CY VII III 1,4 LU - = - - LU - W Co ..:X - I '_ a. CO (1) ! :--, > =-- = CC = Z ��II 1111 o . . . IIP 4.-, ,.4 114 _ J IX U 2 f .H u • NORDIC CALISTA EM 3 1/8" 5000# NAGE TRIM CHOKE & KILL MANIFOLD SYSTEM MAY 2016 ITEM SERIAL # CUST. I.D. DESCRIPTION 1 AS1410024 PV-4519 3-1/8" 5000# CNV SLAB GATE VALVE 2 14110802 PV-4520 3-1/8" 5000# x 3"XXH BUTT WELD FLANGE 3 AS1410021 PV-4521 3-1/8" 5000# CNV SLAB GATE VALVE 4 14110802 PV-4522 3-1/8" 5000# x 3"XXH BUTT WELD FLANGE 5 AS1410018 PV-4523 3-1/8" 5000# CNV SLAB GATE VALVE 6 14110802 PV-4524 3-1/8" 5000# x 3"XXH BUTT WELD FLANGE 7 A9877A PV-4525 3-1/8" 5000# BLIND FLANGE 8 AS1410020 PV-4526 3-1/8" 5000# CNV SLAB GATE VALVE 9 C16363 PV-4527 3-1/8" 5000# x 9.125" OAL FLANGED SPACER SPOOL 10 Q22831-1 PV-4528 3-1/8" 5000# Q.O.T SWACO STYLE ACTUATED CHOKE 11 AS1410015 PV-4529 3-1/8" 5000# CNV SLAB GATE VALVE 12 AS1410014 PV-4530 3-1/8" 5000# CNV SLAB GATE VALVE 13 14110802 PV-4531 3-1/8" 5000# x 3"XXH BUTT WELD FLANGE 14 AS1410017 _ PV-4532 3-1/8" 5000# CNV SLAB GATE VALVE 3-1/8" x 3-1/8" x 3-1/8" x 3-1/8" x 2-1/16" 5000# STUDDED 15 N/A PV-4076 5-WAY BLOCK 16 AS1410010 PV-4533 3-1/8" 5000# CNV SLAB GATE VALVE 17 AS1410016 PV-4534 3-1/8" 5000# CNV SLAB GATE VALVE 17A CC141554/1-1 PV-4535 3-1/8" 5000# CORTEC "NH-2" ADJUSTABLE CHOKE 18 AS1410023 PV-4536 3-1/8" 5000# CNV SLAB GATE VALVE 19 AS1410025 PV-4537 3-1/8" 5000# CNV SLAB GATE VALVE 20 N/A PV-4538 3-1/8" 5000" x 12.75" OAL FLANGED SPACER SPOOL 21 AS1410026 PV-4539 3-1/8" 5000# CNV SLAB GATE VALVE 9" NOMINAL BORE BUFFER CHAMBER 22 68870-ACD PV-4540 c/w 8-3-1/8" INLET/OUTLET FLANGES 23 AS1410009 PV-4541 3-1/8" 5000# CNV SLAB GATE VALVE 24 31KA6443 PV-4542 3-1/8" 5000# x 3" WECO UNION FLANGE 25 AS1407007 PV-4543 2-1/16" 5000# CNV SLAB GATE VALVE 26 17DC1350 PV-4544 2-1/16" 5000# x 2" WECO UNION FLANGE 1 i • • iv riTW t a. 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El 25' 7-1/4" n TOP OF WELLHEAD 5.00' EL 25' 2-1/4" P 1 a o ELECTRICAL 9 or �, _ FEEDnu2U 21.61 ,3-6/a•5000 PSI tAW1w VG 5137 CLAMP I "lir SOON PSI iE�„RII ---_,_.L_ —• --- ,'--„,.........,.p.„ 1,1.....,,.. ■' ■Ii "I''. 3.437 OFFSET 106.0 ,n ,,, 2-1 16' IIS • 5000PSI n 2-1/16" 1of n - _= ';_ :� 5000 PSI . , 66.71 OUT52.66• POSAION _ I r ---- is 3 NOD _28.5. `I I • ' rY•. • ' •••:' r ._i ,?--.1:_6 34.00" 2_1/16- -:- r1.`. 5000 PS •.'• I OUT 1' •l PosmON 24.2 . I., .' 12.15" _' � ;. 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E t an d O Z c E aE O O O O0- O O N0 Z n N n CON COM COM re W ZZ o d o 0 0 0 4N' 4 d m 00) o <O o p d N t5 m ? ` ch 4 n c6 1.6 0 0 ro e c to z w 3 a a a a 0 a n. a 0_ a a a O. a 0. a a a a a a a a a a a a a a r a 0 0 0 0 0 0 0 0 0 0 0 0 (n W N CO N 1n (n u) (o m (n y co co co co (n y Q _ OF 7,4 Alaska Oil and Gas `,w\��,�s� THE STATE ofALASKA Conservation Commission � _ 2 333 West Seventh Avenue = Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g °PMain: 907.279.1433 ALAS*¢' Fax• 907.276.7542 www.aogcc.alaska.gov Marc Kuck Drilling and Completion Engineering Manager Eni US Operating Co. Inc. ` 3800 Centerpoint Dr., Ste. 300 O 9 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP 12-01 Sundry Number: 315-069 Dear Mr. Kuck: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. " oerster Chair DATED this /01-4 of February, 2015. Encl. OM° Y'► 4 . '>� • STATE OF ALASKA FEB 10 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 2.(18 1,5APPLICATION FOR SUNDRY APPROVALS 'OGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well E Change Approved Program ❑ Suspend ❑ Plug Perforations p Perforate ❑ Pull Tubing u Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ Other: _ESP Change Out E 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Eni US Operating Co.Inc.' Exploratory ❑ Development Q • 210-069 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23426-00-00 • 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 ❑ OP12-01 • 9.Property Designation(Lease Number): 10.Field/Pool(s): 0373301,0355024,0391283,390616 • 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): 12,860 3,616 11,534 3,647 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 154 154 Surface 2,421 13.375 2,421 2,174 5,210 2,480 Intermediate 5,527 9.625 5,527 3,620 6,890 4,790 Production Liner 7,423 5.5 11,534 3,647 slotted slotted Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5,527-11,534 ` 3,620-3,647 41/2 L80 3,981 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A r ill 11' 'Kb 019 1-1- 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development [• Service ❑ 14.Estimated Date for 27-Mar-15 15.Well Status after proposed work: Commencing Operations: Oil ❑, • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Giuseppe Maugeri Email giuseppe.maugeri@enipetroleum.com Printed Name Marc Kuck Title Drilling&Completion Engineering Manager Signature Phone Contac 907-865-3328 Date 2/9/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\5 – () LOCI V Plug Integrity ❑ BOP Test 2/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ;t 35-06 r Sc 1•3&'f - f" 01445r = )p5,1 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /(j C7 / 1 APPROVED BY _ Approved by: A / /2„„,(64..., COMMISSIONER THE COMMISSION Date: 2—/ ' -is- __ / J /,3-l-3 01ef I �K� °Z I II�� Z 2-4r-i5 Submit Form and Form 10-403(-1 ised 10/2012) (3111aNilld for12 months fro date f aPI.L RBDMS FEB 2 3 2015 RECEIVED EnD i) tircIeum� AOGGC 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone(907)865-3322 Email: Marc.Kuck@enipetroleum.com February 9th, 2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP12-01 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP12-01. OP12-01 was originally completed by ENI Petroleum at Oliktok Point on August 10th, 2010. In November 2011 a work over was performed and the well was completed with a Thru Tubing Conveyed Electric Submersible Pump(TTC-ESP) set at 3,981' MD. Currently the well run at 64.9 Hz, so in order to improve production rate a new ESP system will be installed. The estimated date for beginning this work is March 27th,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, Marc Kuck Drilling&Completions Engineering Manager OP12-01 Workover— Summary Page OP12-01 Rig Workover PTD#:210-069 Current Status Well OP12-01 is currently in production. Scope of Work Scope of this workover is to pull the current TTC-ESP tubing completion and run in with a new conventional ESP system. General Well info Reservoir Pressure/TVD: The ESP downhole gauge are still functioning and reading 535 psi at 3,981'MD/3,116'TVD on February 9th (well in production). Reservoir depth is 5,527'MD/3,620'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. M Rsr U y Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind/Flowcross/pipe TIFL/MIT-IA/MIT-OA: Due to the completion design these tests were not performed. Intermediate csg 9 5/8" was tested prior to drill out in July 29th 2010. Well type: Producer Estimated start date: March 27th 2015 Drilling rig: Nabors 245 RWO Engineer: Giuseppe Maugeri: Giuseppe.Maugeri@enipetroleum.com Work: 907-865-3328 Drilling&Completion Engineering Manager: Marc Kuck: Marc.Kuck@enipetroleum.com Work: 907-865-3322 Procedure: 1. MIRU Nabors 245. 2. Shear upper GLM valve and pump 9.1 ppg 3% KCl 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: Wilk IVacuum Insulated Tubing(VIT),4'r4'x 5 Y:', gni Petroleum approx 80',two)Dints 0P12-01 am 'a Oil Producer with 4-W 12.6 ppf Production Tubing ESP Lift 4-%'cable clamps,for ESP Power 1111111,, Cable,(1)318"Chem Inj Line 3,778 MD,2,998'ND GLM,KBMG, 4-W x 1",with 2,000 psi STS-1 SOV installed 401, % 3981 MD,3,116 TVD-Bottom of Motor Centralizer Surf.Casing Centrilift TTC-ESP,116-stage 380P18 pump,513 GST3 13-3/8",68# seal,126 HP MSP1-250 motor 2,421 MD,2,174 ND ' 51°Inc. 4,111'MD,3,197'TVD % 53°Inc Baker SLXP HAL Zonal Isolation 5-%"Silver Bullet Ecc Liner Hanger/Packer Swell Packers Nose Guide Shoe I _ INK Interni.Casing Slotted Liner, ppf 9-5/8",47# 11 534 W1DD 5,527'MD,3,620'N 3'647 TVD D 3 6 , 85°Inc. 47 90°Inc Nikaitchug Field- /� n" 1 nr1r1n 'Y t F Psnt Pad onrdp ti3 Mot. VetcoGray MB-247 SURFACE COMPLETION SYSTEM AMAIN/CL 3.50 J "15' 37.19 F-6--...... ...!. 8 0 40 un100/lit* • iF• . 13. ,silA�i 11'..<">. . c 4,, - **moo.ii, ID to ..;10 i 41.._7C) .d,:,..., ir 5i � / vT.0.5. EL 26' 5-3/4" i ‘ 1.062 OFFSET C/L• 1 B.O.S. EL 25 7-1/4" TOP OF WELLHEAD 5.00' EL 25' 2-1/4' 1 Il in ill CI PfT 6 DI1-mELECTRICAL M qlq• FEE07HRU 2161 's 13-5/8.5000 PSI '�j . VG S137 CLAMP � 1111 4—I/16' it* 5000 PSI IN11-- III �` _._�G •LJi-- _ 1� 1 .3.437 OFFSET 108.0 8.50.71407- - .:I` I. 2—i 16" ■� 5000 PSI__=I y; __ Hyl__�_ 2-1/18' ®,'�1.' 5000 PSI ;' ',_ 66.71 Our AI_ _ �a POSMON 13-soon PSI vc 134 MOO. 5296' • u�tlI ) UR 8.5..\�� `.�. 34.00' 2.116* �••�'Ai ilii II=11 1 Y, PSI OUT OF 24.2 �- 15.25' POSRION .r-Fol 1=• rig I 1 I TOG 1 TOP OF GRADING I EL 16' 1-1/4' L1.00 PROPRIETARY ponce tie v� ��.. •01a••.wr�_ 20" OD 133# K-55 ray- � ice." 13-3/8' OD 68# L-80 wog rt ALV ENI ALASKA � nOO 9-5/8" OD 53.5 L-80 Men laHORIZONTAL MULTI-BOWL SYSTEM 4-1/2' OD WITH 6-5/8 VIT 20 X 13-3/8 X 9-5/8 X ^ ,�;, X 4-1/2 WITH 6-5/8 MT mem AND ESP FIAT CABLE 23 PPP&06 041. IgIcc r H173370-1 jr. PP WO OF MR 5XXI•a•c oat x I•O I s1 PRP 10161, NC 10 OF 10 23 JANUARY 2009 0 Ca G=imagination o:work gi El. 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W = N > o Z Q w O ao o Z 5 cC o Q o zI- cn m y o I J o � I Om � I T E Ct1 • � � a) 0 `_ ■ O N a E V 0 0 U J I Q o i F— co co 1 I r o O N N I� r O I 5 N MG O a I W •- I a= O O d m V) r o °' a E I— o a D z o 0) m E ca z a) • co co M Z O ,� �j Q[ZJ m c F- lam} aa)i 0 cc N rn O m co J a) re tr) pOp U Q a) C.) a� O .N• Z a) 'p C C co E o U T.> E a 0 N ct- c� E C-= � -"C A ....=ASKA SEAN PARNELL,GOVERNOR O 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 Operations Manager Eni US Operating Co. Inc. 16 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP12-01 Sundry Number: 311-347 Dear Mr. Grandi: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. S•ncerely, 4 Daniel T. Seamount, Jr. d Chair DATED this - r day of November, 2011. Encl. RE ` pilacka Oil&Gas Gans•Commission• Enii pncnor� 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio November 4,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP12-01 ESP Replacement Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP12-01. OP12-01 was originally completed on August 9, 2010. The well was put on production on February 7, 2011. The well was then operated until September 30th, 2011 when it would not surface fluid and was shut in. The ESP electrical system checked out positively. A pump changeout was performed and the well was restarted on Oct 25th. The well then failed due to downhole electrical fault unexpectedly on Oct 31St with fuses blown on the input side of the VSD. This well now requires a tubing pull and ESP replacement. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information,please contact me at 907-865-3320. Sincerely, Maurizio Gra di Well Operations Manager ' 11J4')1 �Y ED NOV 04 1, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION commissicklefika Oil &Gas Cons.COmmiSSion APPLICATION FOR SUNDRY APPROVALS Ancnaragc 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing 0 • Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: EEO a4/16,,,i,:_-4.L El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Numbe /f i/,i4.ii Eni US Operating Co.Inc. Development Q Exploratory ❑ 210-069 - 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23426-00-00 . 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ OP12-01 9.Property Designation(Lease Number): 10.Field/Pool(s): 355024,373301, 390616, 391283 - 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): /2 4° r j C/-�/ X364`/- // 3Z ' 1 3647 N/A N/A Casing ;i.i( Length 1-1i,q-if Size As?tl y.-/f MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 2421 13-3/8" 2421 2173 5,020 2,270 Intermediate 5510 9-5/8" 5510 3618 6,870 4,760 Production 11534 5-1/2" 11534 3647 slotted slotted Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5510-11534 3618-3647 4-1/2" L-80 3982 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal 0 d13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ISI Service ❑ 14.Estimated Date for ,JJ'Nov-11 15.Well Status after proposed work: Commencing Operations: Oil eg • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Maurizio Grandi 'I Printed Name Maurizio Grandi Title Well Operations Manager Signature Ait ^ ,I \ Phone 907 865-3322 Date I ,t_(_^IV(� Li • 4.61 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3/ 1 -3 /(� i C Plug Integrity ❑ BOP Test li Mechanical Integrity Test ❑ Location Clearance ❑ Other: )- 3 Soo Yes 1OT eg k.s r_ Subsequent Form Required: ! 6 ^ Yoy 0 r APPROVED BY � I � 1 , Approved bye COMMISSIONER THE COMMISSION Date: J w Nf1V/f h oAIr .. ., w • - - - iti1 / i II OP12-01 Workover- Additional Data Sheet 11/4/11 Workover Objectives: • Objective of this workover is to pull the failed TTC-ESP tubing completion and run in with a ,/ new TTC-ESP system. • Complete the planned work with no HSE accidents or incidents. Well History: OP12-01 was originally completed on August 9, 2010. The well was put on production on February 7, 2011. The well was then operated until September 30th, 2011 when it would not surface fluid and was shut in. The ESP electrical system checked out positively. A pump changeout was performed and the well was restarted on Oct 25th. The well then failed due to , downhole electrical fault unexpectedly on Oct 31st with fuses blown on the input side of the VSD. This well now requires a tubing pull and ESP replacement. Pressure Data: This well is expected to have a static pressure of approximately 900 psi. 8.8 ppg hot seawater with 3% KCI is planned as kill wt fluid for this workover. 34p0 1-rya Operational Plan Summary: 1. MIRU Nabors 245E. 2. Shear GLM valve and circulate hot 8.8 ppg hot 3% KCI seawater kill fluid through tree. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. 4. Pull tubing to GLM. Rig up wireline and pull tubing stop, check valve. 5. Circulate out remaining production fluid. 6. Continue POOH and LD ESP assembly. 7. MU new ESP assembly and RIH to setting depth. 8. Land hanger, RILDS and test hanger. 9. Install BPV and nipple down BOP. 10. NU tubing adapter and tree. 11. Pull BPV, install test plug and test tree. / 12. Circulate Freeze protect through tree down IA taking returns up tubing. 13. Shut in well. 14. RDMO. • V M 0 N o E -0 O o O N QC C O (n J 2 > C Tts J a }� > > o I w ,-- M 3 a � N L Y N u) as si) d Q. a a� 0 0oW o a) (7) co •=- a N o"= ^ C-...' 0 ' m 2 Q N �LQ 45 I L IJ •....O +. co J I (n 0 CL 0 • • 1 L O M X U X 2 In N U I Tts a. ISE lib o Q N3 1 0 0 J C 2 m d = < 000 0 i J U' M X I ILO TA N L N 4 N ; Cfl o - c 3 i– d a a c I- w CO ri x�I I C o 0 rn c W —J "� U - o o I � N o � � I I > - c o Q0 rn L- Ti C o o L H N 01 .N (N ro., d c6 to t) co o .� p M 0 0 _ E p CO c 7 2 co N V ti O i 1;:z _ _ _ _- ' # cc 4:t U ,- v. — ii c N ti ° a o (n N N � Yo F15 Y Y_ 2O 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: March 25, 2011 P. I. Supervisor Rea )Oil/( FROM: Lou Grimaldi SUBJECT: No Flow Verification Petroleum Inspector ENI Petroleum OP12-01 PTD # 210-069 Nikaitchuq Field Friday, March 25, 2011; I witnessed the No-Flow test on ENI Petroleum's well OP12-P01 in the Nikaitchuq Field. I had been in contact with the operator Delton Carrol about equipment and procedure. When I arrived he was very prepared for the test. I arrived at the facility to find the well open to atmosphere. The tubing and annulus were tied together with a "C" section used to vent free gas on the backside to the flowline. This well is a packer-less completion. After verifying the position of the pertinent valves The Flow (if any) would be measured by an Erdco "Armor flo" gas meter capable of measuring 150-1500 scf/hour of gas flow. There also was a calibrated 30 psi "Test" gauge (0.1 psi increment) used to monitor the tubing/annulus pressure. A 1/4 turn block valve downstream of the gauge was used to close the flow from the tubing/annulus to atmosphere/tankage. I required 2 equal-time tests, both involving shut-in and flowing intervals. During the 2 tests, tubing pressure never rose above 3.7 psi and sustained gas flow was well below the measurable capacity of the flow meter (150 scf). There was no ,— fluid produced to surface during the entire no flow test I monitored. The following table describes the details of the test: 2011-0325 No_Flow NikaitchugOP12-01_lg.doc —1 nf') Nikaitchuq OP12-01 No Flow Test Time Pressure Flow Notes (scf/hr) 0900 0 Whisper Flowing to Bleed trailer 0915 0 0 Shut-in well 0920 0.3 Well Shut-in 0925 0.7 Well Shut-in 0930 0.9 Well Shut-in 0945 1.9 Well Shut-in 1000 2.9 Well Shut-in 1015 3.7 Well Shut-in, Open for 1st flow period 3.2 800 Flowing to Bleed trailer 1020 1.0 400 Flowing to Bleed trailer 1025 0.1 200 Flowing to Bleed trailer 1030 0 <150 Flowing to Bleed trailer 1045 0 <150 Flowing to Bleed trailer 1100 0 Whisper Flowing to Bleed trailer 1115 0 Whisper Flowing to Bleed trailer, Shut-in well 1120 0.4 Well Shut 1125 0.6 Well Shut 1130 1.0 Well Shut 1145 1.8 Well Shut 1200 2.8 Well Shut 1215 3.5 Well Shut-in, Open for 2nd flow period. 3.1 800 Flowing to Bleed trailer 1230 0 <150 Flowing to Bleed trailer 1245 0 Whisper Flowing to Bleed trailer 1300 0 Whisper Flowing to Bleed trailer 1315 0 Whisper Flowing to Bleed trailer The test was concluded at this point. I observed less buildup in the second shut-in test and quicker bleed down in the second flow test. This well appears to meet the criteria set forth in 20 AAC 25.265 for No-Flow status. Attachments: None Non-Confidential 2011-0325 No_Flow—Nikaitchuq_OP12-01_1g.doc nc,, 1 Schiumberger 1 Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Christine Mahnken Well No OP12-01 Date Dispatched: 27-Aug-10 Installation/Rig Nabors 245 E Dispatched By: Paul Wyman Data No Of Prints No of CDs OP12-01 Logs 1 2in MD 1 2in TVD 1 i 0/0 -6(®9 96)2/ 1 Received By: Please sign and return to: j Drilling&Measurements LWD Division 2525 Gambell Street,Suite 400 J w1 Anchorage,Alaska 99501 pwymanslb.com ,? 3s' :a,;z,` Fax:907-561-6317 "" LWD Log Delivery V1.0,01/22/2010 T* .n1ti Schlumberger Private STATE OF ALASKA • ALASK,. .AIL AND GAS CONSERVATION COMMIS...JN WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 Gasp Plugged❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development EI • Exploratory GINJ❑ WINJ❑ WDSPL❑ WAG❑ Other❑ No.of Completions: Service ❑ Stratigraphic Tests 2.Operator Name: 5. Date Comp.,Susp.,or 12. Permit to Drill Number: ENI US Operating Co Inc Aband.: 8/10/2010 • 210-069 • 3.Address: 6. Date Spudded: r i�� 13.API Number: 3800 Centerpoint Drive Suite 300,Anchorage 99503 ),/,.1.,14-201i) `/'/4- /,, 50-029-23426-00-00 . 4a. Location of Well(Governmental Section): T Date TD Reached: ` /1:' 14.Well Name and Number: Surface: 3182.4 FSL 1604.3 FEL S5 T13N R9E UM 8/3/2010 • OP12-01 • ! Top of Productive Horizon: 8. KB(ft above MSL): 53.2 • 15. Field/Pool(s): 832'FSL, 3625'FEL,S32 T14N R9E UM Ground(ft MSL): 12 . Nikaitchuq Total Depth: 9.Plug Back Depth(MD+TVD): - 883 FSL 3254 FEL 30 T14N R9EUM 11,532 MD/3647 TVD 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 516675.72 • y-6036535.64 . Zone- 4 ' 12860 MD/3616 TVD ' 355024,373301,390616,391283• TPI: x- 514640.3392 y-6039459.027 Zone- 4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 509702.5078323 y-6044783.08748337 Zone- 4 none ADL 417493 18. Directional Survey: Yes 191 No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) (ft MSL) 1896 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 2173 16 332 bbls 10.85#ASL,72 bbls 12#Crete 9-5/8" 47 L-80 SURFACE 5510 SURFACE 3618 12.25 110 bbls 12.5#Litecrete 5.5" 17 L-80 4111 11534 3192 3647 8.5 slotted liner 23.Open to production or injection? Yes Ei No El 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 RECEIVED 4.5 3982 NA/ESP completion 25. ACID,FRACTURE,CEMENT SQUEEZE, ETC. AUG 2 h 2O l L' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED A&ska MI t Gas Cwt .CEVolission ". Ici„ory ge - 26. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): NA(to be Jan 1,2011) ESP Completion Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: NA NA Test Period -4 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate 27. CORE DATA Conventional Core(s)Acquired? Yes❑ No. Sidewall Cores Acquired? Yes ❑ No 0 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. iPLEl1Ot. r, RBDMS AUG 2 6 2010 4,/jrn 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? n Yes 0 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 1896 1784 • OA sand top 5403 3607 Formation at total depth: OA sand 12860 3616 • 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 Printed Name: Maurizio Grandi I Title: Well Operation Project Manager / Signature: /,A,.Ctl Phone: Date: 39(2‘i5/ 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 Injection,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. Pr rm 1 n_dr17 Ravisarl 9/9nn7 1 Eni E&P Division Well Name: OP12-01 Daily Report ENI Petroleum Weil Code: 23972 Field Name: Nikaitchuq � Co. Inc. Date:7/14/2010 - Report#: 1 API/UWI: 500292342600 °�II II I page 1 of 1 Wellbore name: OP12-01 Well Header PermIt/Concesslon N° Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM 100.00 (HORIZONTAL Rotary Table Elevation(ft) I Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 j 12.20 1 0.00 Rig information Contractor Rig Name I 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) 0P12-01 DRILLING 1 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 -1.67 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB (Temperature(°F) Weather Wind 79.0 ICI 38.8 Partly Cloudy,WC 261°W @ 2.9 mph 37.2° Daily summary operation 24h Summary Rig dn,split rig modules,prep gravel for mats,set mats,spot derrick module. Operation at 07.00 Move in/rig up on OP12-01I, 24h Forecast Move in/rig up on OP12-01 Lithology !Shows MAASP Pressure(psi) Mud Weight(Ib/gal) Time Log Cum Start End Dur Our Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 MOB A 2 'P PJSM,commence rig dn/prep for rig move.R/D de-gasser,roil up curtains,hang cellar box,remove shaker screens, secure BOP stack.Blow dn steam/water lines,Disconnect elect to modules,remove all connecting plumbing to modules. Jack up modules,set on crib blocks.Warm up Lampsons.Remove cuttings tank.Remove berm surrounding rig. 12:00 00:00 12.00 24.00 MOB A 2 P PJSM,Split modules.Transport sub to east,utility to west.Remove rig mats.Dispose old berm.Surveyors shoot/grade/ stake pad.Take load gravel,spread to new drill site.Grader/loader/compactor level pad.Raise BOP scaffolding in cellar.Roll out herculite over new pad.Set mats for sub,and plywood for"stomper".Spot derrick module. Daily Contacts Position I Contact Name Company Title E-mail I Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 1907-670-8623 907-841-8759 Eni representative Dave Morris ENI Sr.Drilling Spvr. Dave.Morris©enipetroleum.com 1907-670-8623 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 1907-685-1227 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 1907-670-8607 907-229-6100 Eni representative 'Alvin Criswell ENI IExpediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor 1907-865-3337 907-952-7880 Last Casing seat _ _ Cas.Type OD(M) I ID(In) Grade Top(RKB) I Bottom(ftKB) _ — Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) I Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) I I Eni E&P Division Well Name: OP12-o1 ENI Petroleum Daily Report Well Code: 23972 Field Name: Nikaitchuq • n n Co. Inc. Date:7/15/2010 - Report#: 2 API/UWI: 500292342600 2" '�,t page 1 of 1 Wellbore name: OP12-01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 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) 0P12-01 DRILLING 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 -0.67 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind ', 87.0 40.5 Partly Cloudy,WC 111°ESE @ 11.5 ■ 33.6° mph Daily summary operation 24h Summary Move in/ri.u.on OP12-01 NU riser .re.for s.ud. Operation at 07.00 MU BHA#1 and PU DP 24h Forecast PU DP,mix spud mud,MU BHA Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log cum Start End Dur Dur Time Time (Ms) (hrs) j Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 MOB A 5 P Spot utility module,mate to denick/drilling module.Jack do on rig mats. 03:30 05:00 1.50 5.00 MOB A ,5 P Rig up flowline/degasser.Lower cellar box,berm in rig. 05:00 08:30 3.50 8.50 MOB A 5 I P Install riser/spacer spools.NU Vetco wellhead,test 500 psi/10 min. 08:30 12:00 3.50 12.00 DRILL A 5 I P Service top drive,replace steam heater in boiler room.Spot CCB modules. 12:00 18:00 6.00 18.00 DRILL E 1 P Nipple up modified riser and spacer spools.NU up to wellhead.Install flowline,turnbuckles,catch can.Install hatch cover. Build landings/step downs around rig.Install shaker screens.Load mud product to pits.Spot cuttings tank skid.Remove parts house top of utility module.Weld pad eyes in cellar.Test pit lines. 18:00 22:30 4.50 22.50 DRILL E 8 P Commence build mud volume,load pipe to pipe shed.Pre spud check list. 22:30 00:00 1.50 24.00 DRILL E 4 P PJSM,PU drill pipe for spud while continue mix spud mud. Daily Contacts Position Contact Name Company ( Title _ E-mail I Office Mobile _ Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative IDave Morris ENI ;Sr.Drilling Spvr. Dave.Morris @enipetroleum.com 907-670-8623 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907-670.8607 907-229-6100 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell©enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI I Project Advisor 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(in) I ID(in) Grade Top(ftKB) Bottom(kKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type [Fluid Density(lb/gal) I P(Surf)(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) • err/77 Eni E&P Division Well Name: OP12-01 ENI Petroleum Daily Report Well Code: 23972 Field Name: Nikaitchuq �• Co. Inc. Date:7/16/2010 - Report#: 3 API/UWI: 500292342600 21III page 1 of 1 Wellbore name: OP12-01 Well Header Permit/Concession N° Operator ENI Sham(%) Well Configuration type 210069 I ENI PETROLEUM 100.00 'HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) I Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 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(RKB)'Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) OP12-01 DRILLING 1 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 0.33 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) 'Average ROP(ft/hr) POE 'Temperature(°F) Weather Wind 250.0 250.0 128.00 1.66 77.1 91.0 49.5 Overcast,Light Rain, 207 SSW @ 11 mph WC 45 Daily summary operation 24h Summary P/U 5"DP(52 stand in derrick),HWDP/Jars and BHA#1(clean out assembly)-Pre-Spud meeting-Clean out conductor f/122'-t/160'-POOH-Held PJSM&P/U Schlumberger/Gyro Data directional tools.Drill ahead f/160'-U 250'-POOH&P/U two NMDC&stab-M/U stand 5"HWDP to drill. Operation at 07.00 Drill ahead @ 392'as per Schlumberger&well plan to increase pump flow rates. 24h Forecast Drill ahead f/250'to TD as per Schlumberger-Gyro as required for directional plan-sweep as needed-Maintain 8.8 to 9.2 with 100+vis per well plan. Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 8.75 Time Log Cum Start End Dur Dur Time Time (hrs) ( ) Phase Opr. Act. Plan Oper.Descr. 00:00 08:30 8.50 8.50 DRILL E 4 P P/U 5"Drill Pipe and rack back in derrick,a total of 52 stands-4976'(enough to drill surface&intermediate hole sections) Spud mud mixed&ready. 08:30 10:30 2.00 10.50 DRILL E 4 P P/U 5"HWDP&jars,rack back in derrick,430' 10:30 12:00 1.50 12.00 DRILL E 4 P P/U BHA#1(clean out assemble)with 1.83 bend in mud motor,XO,Smith XR+16"bit.(Jets;1 x 16/3 x 20,TFA=1.12- as per Schlumberger DD/M W D. 12:00 13:00 1.00 13.00 DRILL E 1 P Hold pm-spud meeting with all personnel and reviewed plan forward.Fill stack with mud to check for leaks,small leak coming form bottom of Vetco Gray starting lead. 13:00 14:30 1.50 14.50 DRILL C 20 U Vetco Gray Rep.pump graphite packing grease into void between 0-ring seals retested OK.Filled stack with mud and circulated mud system,check for leaks-OK,no leaks. Irt.f 14:30 15:00 0.50 15.00 DRILL E 4 P Make up stand HWDP and RIH-Tag @ 122' _ 0'01 15:00 16:00 1.00 16.00 DRILL E 3 P 55-n8K.Up wt.55K-fDn wt.55K-Rot pwt.55k.Back ream stand twice and c9ro circulated 375 psi,bottom35 p.POOH back ream HWDP._ LI P,` 16:00 19:30 3.50 19.50 DRILL E__ 4 P Held PJSM-Pick-up BHA#2 Schlumberger/Gyro Data tools orient UBHO sub. 19:30 20:30 1.00 20.50 DRILL E 7 U Circulate to perform shallow hole test.Had some new software problems with Schlumberger&Gyro Data.Starting head leaked a little,Vetco Gray pump graphite packing grease into seal area&retested to 500 psi,OK. 20:30 23:30 3.00 23.50 DRILL E 2 P Drill f/160'-U 250'as per Schlumberger DD with pump rate 450 gpm @ 585 psi-40 RPM @ 1K torque-WOB 10-15K- Up wt.68k-Dn wt.68K-Rot wt.68K. Total drilling=1.54 hrs. Total rotating =0.33 hr. Total sliding=1.21 hrs. Drilling Jar=56.54 hrs. '23:30 00:00 0.50 24.00 DRILL E 4 P POOH one stand 5"HWDP-P/U two NMDC&stab(15.88").M/U stand of 5"HWDP to drill ahead. Daily Contacts Position Contact Name Company Title E"mall 1 Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com '907-670-8623 907-841-8759 Eni representative David Smith ENI Sr.Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bemie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 1907-685-1227 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI ,Project Advisor :.907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(In) I ID(In) Grade Top MKS) Bottom(RKB) Run Date Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type I Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(Ib/gal) ,Leak Off Pressure(psi) I • • �' if Eni E&P Division ENI Petroleum Daily Report Well Name: 0P12-01 Well Code: 23972 • Feld Name: Nikaitchuq Co. Inc. Date:7/17/2010 - Report#: 4 API/UWI: 500292342600 {?hilt Wellbore name: OP12-01 page 1 of 1 ---- Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210069 iENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) !Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 g Information Contractor [Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wetlbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) 0P12-01 DRILLING 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 1.33 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 1,074.0 1,060.2 824.00 14.48 56.9 94.0 39.7 Overcast.Fog.WC 346 NNW @ 7.7 34.5 mph Daily summary operation 24h Summary Drill ahead(rotate&slide)f/250'-t/1074'as per Schlumberger DD.Increasing pump f/450 gpm-t/715 gpm while still maintaining angle build as required for direction well plan.Maintain 9.0 ppg mud wt,&100 vis.ECD @ 9.79 ppg. Operation at 07.00 Drill ahead @ 1264'with flow rate 715 gpm @ 1292 psi./Mud wt.=9.0 ppg/Vis 96/ECD @ 10.15 ppg. 24h Forecast Drill to TD @+/-2340 MD casing point/pump#1 sweep&CBU 3 or 4/short trip to HWDP/RIH back to bottom/Pump#2 sweep&CBU 3 or 4(until clean)POOH for 13 3/8"ca sing. Lithology -_--Shows - ----- ----_--- MAASP Pressure(psi) !Mud Weight(lb/gal) 9.00 Time Log Cum ! -_ Start End Dur Dur ' Time Time (hrs) (b►s) Phase Opr. Act. Plan Oper.Descr. 00:00 07:00 7.00 7.00 DRILL E 3 P Drill f/250'-11482'(35%rotate&65%slide)as per Schlumberger DD with pump rate 500 gpm @ 560 psi-40 RPM @ 1.7K torque-WOB 15-20K-Up wt.82K-Dn wt.82K-Rot wt.82K. 07:00 12:00 5.00 12.00 DRILL E 3 P Drill f/482'-1/597'(6%rotate&94%slide)as per Schlumberger DD with pump rate 440-500 gpm @ 620-680 psi-40 'RPM @ 1-3K torque-WOB 20-25K-Up wl.90K-Dn wt.90K-Rot wt.90K.Mud wt.9 ppg w/101 vis.Wash up&down @ connection w/survey. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill f/597'-1/775'(7%rotate&93%slide)as per Schlumberger DD with pump rate 500 gpm @ 800 psi-40 RPM @ 2.7K torque-WOB 15-25K-Up wt.90K-Dn wt.90K-Rot wt.90K.Wash up&down @ connection w/survey. 18:00 00:00 6.00 24.00 DRILL E 3 P Drill f/775'-t/1074'(rotate 13%&slide 87%)as per Schlumberger DD with pump rate 610 gpm @ 850 psi&increased to 715 gpm @ 1200 psi-40 RPM @ 3K torque-WOB 15-20K-Up wt.105K-Dn wt.94K-Rot wt.100K.Mud wt.9.0 ppg- Vis 100 sec.-ECD 9.79 ppg.Wash up&down @ connection w/survey. Total drilling=16.02 hrs. Total rotating =2.63 hr. Total sliding=13.39 hrs. . Drilling Jar=71.02 hrs. Daily Contacts Position I Contact Name Company L Title E-mail Office Mobile Eni representative Scott Beauchamp ENI ''Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative !David Smith ENI Sr.Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com '907-685-1227 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Last Casing seat Cas:'Type OD(in) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) 1TVD(ftKB) 1 Fluid Type Fluid Density(lb/gal) l P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) • Eni E&P Division Q .. Well Name: 0P12-01 ENI Petroleum Daily Report Well Code: 23972 -. ._. Field Name: Nikaitchuq • �} Co. Inc. Date:7/18/2010 - Report#: 5 API/UWI: 500292342600 2„ "n page 1 of 1 Wellbore name: OP12-01 Well Header Permit/Concession N° Operator ENI Share(%) TWell Configuration type 210069 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig Information Contractor !.Rig Name Rig Type NABORS ALASKA ' NABORS 245 E 'LAND RIG Job Information Wellbore Job Phase i Spud Date Target Depth(ftKB)!Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) 0P12-01 DRILLING 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 2.33 ■ Daily Information Depth End(ftKB) Depth End(TVD)(...'Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 2,223.0 2,040.5 1,149.00 11.32 101.5 94.0 36.3 Overcast.Rain.WC 49 NE @ 19 mph 25.9 Daily summary operation 24h Summary Drill ahead(rotate&slide)f/1074'-t/2223'as per Eni Rep.Pump rate was increased 800 gpm w/1750 psi;but lowered to 600 gpm @ 1100 psi.to slide.Ream/wash f/1170'-U 1265'to reduce 6.27 dog leg to 5.42.Pump 25 bbl.wt./vis.sweep with minimum increase in cuttings.Back ream\wash f/1845'-U 1935'due to torque&pump pressure,cleaned-up spot @ 1845'-1895'. At 0020 hours,CCB !so Pump hopper inside module had mechanical gasket failure causing 2 barrel spill of water based mud. Approximately 15 gallons leaked out of module spilling onto liner between skid pans. AIII necessary notifications were made. Eni Environmental has a spill report forthcoming. Agencies will be notified at 8:00 AM. Operation at 07.00 Drill ahead(rotate&slide)f/2223'-U 2430'TD for 13 3/8"csg.Circulate 24h Forecast TD well @ 2430'MD-Pump sweep#1,circulate 3-to 4 CBU(clean)-Short trip to HWDP-RIH to TD-Circulate sweep#2 with 3 to 4 CBU until clean-POOH-L/D BHA#2-R/U&run 13 3/8"csg.- Circulate&condition mud-Schlumberger pump cement. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Cum !. Start End Dur Dur Time Time (hrs) (hrs) Phase Op r. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 3 P Drill f/1074'-V 1265'(16%rotate&84%slide)as per Eni Rep with pump rate 710 gpm @ 1300 psi./40 RPM @ 34K torque/WOB 25K/Up wt.100K-Dn wt.95K-Rot wt.100K/Mud wt.9.0 ppg&100 vis.ECD=9.85 ppg./Survey @ 1220.30 indicated a 6.27°dog leg. 03:30 08:00' 4.50 8.00 DRILL E 6 U Ream&wash f/1170-V 1265'to reduce dog leg,Resurvey @ 5.42°Pump rate 800 gpm @ 1420 psi./80 RPM @ 2K torque. 08:00 12:00 4.00 12.00 DRILL E 3 P Drill f/1265'-U 1536'(53%rotate&47%slide)as per Eni Rep @ 800 gpm with PSI Off=1530,PSI On=1740/40 RPM 1 with Torque @ 2K Off,3-4K On while Rotating/WOB 25K/Up wt.110K-Dn wt.95K-Rot wt.100K/Mud wt.9.0 ppg w/ 102 vis.ECD=10.01/Wash up&down @ connection w/survey. 12:00 17:30 1- 5.50 17.50 DRILL E 3 P Drill f/1536'-U 1934'(21%rotate&79%slide)as per Eni Rep @ 800 gpm with PSI Off=1530,PSI On=1750/40 RPM with Torque @ 2K Off,4-6K On While Rotating/550 gpm @ 955 psi.while Sliding/WOB 25-30K/Up wt.110K-Dn at 95K-Rot wt.100K/Mud wt.9.2 ppg w/96 vis.ECD=10.09 ppg./Pumped 25 bbts.wt/vis sweep with minimum increase in cutting returns.Wash up&down @ connection. 17:30 18:30 ( 1.00 18.50 DRILL E 6 U Circulate bottoms-up/back ream f/1825'-U 1935'slow to clean up hole due to torque&tight f/1845'-U 1895'.Pump rate 700 gpm @ 1400 psi.Washing down with no problems. 18:30 00:00 5.50 24.00 DRILL E 3 P Drill f/1934'-U 2223'(36%rotate&64%slide)as per Eni Rep @ 800 gpm with PSI Off=1590,PSI On=1750 psi/45 RPM with Torque @ 2K Off,5K On while Rotating/600 gpm @ 1100 psi.While Sliding/WOB 10-20K/Up wt.130K-Dn wt.102K-Rot wt.110K.Mud wt.9.6 ppg w/96 vis.ECD=9.92 ppg.Wash up&down @ connection.Started back reaming @ 2125' Total drilling=27.34 hrs. Total rotating =5.27 hr. Total sliding=22.07 hrs. Drilling Jar=82.34 hrs. Daily Contacts Position I _Contact Name Company 1 Title E-mail i Office Mobile Eni representative 'Scott Beauchamp ENI 'Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com '907-670-8623 907-841-8759 Eni representative (David Smith ENI Sr.Drilling Spvr. 1907-670-8623 907-632-3085 Eni representative Bemie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Last Casing seat Gas.Type OD(In) I ID(In) Grade Top(ftKB) I Bottom(ftKB) Run Date Last Leakoff Test _ Depth(ftKB) rTVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) • tfooli Eni E&P Division Well Name: OP12-01 ENI Petroleum Daily Report Well Code: 23972 i Field Name: Nikaitchuq n Co. Inc. Date:7/19/2010 - Report#: 6 APUUWI: 500292342600 II Welibore name: OP12-01 page 1 of 1 Well Header Permit/Concession N° ,Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM 100.00 iHORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig Information Contractor Rig Name 'Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Welibore Job Phase 1 Spud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) 1 Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) OP12-01 DRILLING ! 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 3.33 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) 'Average ROP(ft/hr) POB ITemperature(°F) Weather Wind 2,430.0 2,179.7 207.00 1.52 136.2 94.0 I 36.9 Cloudy.Fog.WC 50 NE @ 9 mph 30.6 Daily summary operation 24h Summary Drill ahead(rotate&slide)f/2223'-U 2430'TD.Beck ream tight spot f/2381-t/2381'Pump rate 800 gpm w/1840 psi.\Circulate pump weight sweep#1&CBU x 4(clean)\Short trip to 5"HWDP I RIH to 2430'TD I Circulate weight sweep#2&CBU x 4(clean)I POOH to BHA&UD I Perform dummy run with landing joint-Held PJSM-R/U&run 13 3/8"csg. Operation at 07.00 P/U&run 13 3/8"CSG.1811 every joint with Franks tool&break circulation @ 1839'I Continue P/U csg.&P/U landing joint/hanger\Circulate&condition mud. 24h Forecast ..__.- Finsh P/U 13 3/8"csg.&cement I N/D drill nipple\N/U Well Head&BOPE\Test BOPE I install wear ring 1 P/U BHA#3. Lithology -__-- Shows --- MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log Cum ■ Start End Dur Dur Time Time (hrs) (hrs) I Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 3 P Drill f/2223'-t/2414'(31%rotate&69%slide)as per Eni Rep @ 800 gpm with psi.Off=1690,psi.On=1840 psi/40 RPM with Torque @ 3K Off,4-5K/WOB 10-20K/Up wt.=130K-Dn wt.=102K-Rot wt.=110K.Mud wt.9.3 ppg w/96 vis. ECD=9.72 ppg. Back ream&wash down @ connection. 03:00 04:00 1.00 4.00 DRILL E 6 U Back ream f/2414'-U 2324'to clean up to torque&tight area f/2331-U 2381'.Reduce pump rate 550 gpm @ 1065 psi.and increase to 60 RPM w/5-14K torque.Final pass Increased rate to 800 gpm @ 1680 psi.-OK. I 04:00 04:30 0.50 4.50 DRILL E 3 P Drill f/2414'-U 2430'(100%rotate)as per Eni Rep @ 800 gpm with PSI Off=1690,PSI On=1840 psi/40 RPM with Torque @ 3K Off,4-5K On/WOB 25K/Up wt.=130K-Dn wt.=102K-Rot wt.=110K.Mud wt.9.3 ppg w/96 vis.ECD= I 9.72 ppg. ADT=28.86 hrs. I ART=5.27 hrs. AST=23.59 hrs. Drill Jam=83.9 hrs. 04:30 07:30 3.00 7.50 DRILL E 7 P Circulate&condition mud\pump sweep#1&CBU x 4(clean)\Rotating&reciprocating pipe w/800 gpm @ 1680 psi\ with 70 RPM @ 3-4k torque.1 Up wt.=130K-Dn wt=102K-Rot wt.=110K 1 Monitor well for 10 minutes. 07:30 09:00 1.50 9.00 DRILL E 4 P Short trip-POOH f/2430'TD-U HWDP @ 691'w/25K over pull f/2280'-U 2270'/work pipe&wipe out-OK. 09:00 10:00 1.00 10.00 DRILL E _ 4 P RIH f/691'-U 2430'TD-took 25K wt.@ 1858'work pipe wipe out-OK 10:00 13:00 3.00 13.00 DRILL E 7 P Circulate&condition mud I pump sweep#2&CBU x4(clean)\Rotating&reciprocating pipe w/800 gpm @ 1789 psi\ with 70 RPM @ 4-5K torque./Up wt.=130K-Dn wt.=105K-Rot wt.=110K I Mud wt.9.5 ppg w/78 vis. 13:00 15:00 2.00 15.00 DRILL E 4 P Flow check-static I Pump slug&POOH f/2430'-U BHA @ 691'\No tight hole,correct pipe displacement I Up wt=130K- Dn wt=102K 15:00 18:30 3.50 18.50 DRILL E 4 P UD BHA#2-Stand back NMDC-Clear&clean floor,drain stack for dummy hanger run. 18:30 19:30 1.00 19.50 DRILL G 1 P P/U landing joint hanger&perform dummy run with Vetco Gray Rep.\Good 1 UD same. 19:30 21:00 1.50 21.00 DRILL G 4 P Held PJSM to run 133/8"csg.-R/U GBR equipment&Franks tool. 21:00 00:00 3.00 24.00 DRILL G 4 P P/U 13 3/8"-68#surface casing to 880'\Up wt.105K-Dn wt.87K\Check float equipment\Centralizer per procedure\ Average M/U torque 9K\Franks tool to fill pipe. J.Daily Contacts Position I Contact Name-1 Company This E-mail F Office Mobile Eni representative :Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative David Smith ENI Sr.Drilling Spvr. 907-670-8623 907-632-3085 Eni representative ;Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative ;Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Eni representative !Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com i 907-980-7545 Eni representative I Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(RKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,421.0 7/19/2010 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) - - Well Name: OP12-01 ' Eni E&P Division - ENI Petroleum Daily Report Well Code: 23972 • CO, Inc. ield Name: Nikaitchuq 2 r Date:7/20/2010 - Report#: 7 API/UWI: 500292342600 �I page 1 of 1 Wellbore name: OP12-01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig Information Contractor ;Rig Name 1Rig Type NABORS ALASKA I 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) 0P12-01 DRILLING i 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 4.33 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB [Temperature(°F) Weather Wind 2,430.0 2,179.7 0.00 91.0 1 36.9 Partly Cloudy.Fog. 64 ENE@ 3.4 mph WC 34 Daily summary operation 24h Summary P/U&run 13 3/8"CSG to 2421'-break circulation @ 18399 Circulate&condition mud for cement job\Held PJSM for cement job&pump cement,in place @ 1110 hrs.\Flush-out stack&surface equipment\N/D surface riser&starting head\N/U 13 5/8"BOPE. Operation at 07.00 - --- -- - ---- ---- _ _. _. Finish N/U BOP stack&spill containment-R/U&test BOPE 250/3500 psi. 24h Forecast Test BOPE\P/U BHA#3&RIH t/2243'\Test 13 3/8"csg.to 2500 psi\Drill out float equipment&20+new hole\Change well over to LSND mud\Perform LOT\Drill ahead 12 1/4'hole. Lithology Shows TMAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log Cum Start End Dur Dur Time Time (hr.) (hrs) i Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00,DRILL G 4 P P/U 13 3/8"-68#surface casing f/880'-t/2420'I Up wt.210K-Dn wt.110K\Break cicrculation @ 1839'with 105 gpm @ 235 psi.\P/U Landing joint w/hanger. 04:00 05:00 1.00 5.00 DRILL G 7 P Circulate&condition mud for cement job\bottoms-up+with Franks tool\stage rate up @ 212 gpm @ 240 psi.\ Reciprocating 13 3/8"csg.1 Up wt.205K-Dn wt.135K 1 Held PJSM with Schlumberger,rig&support crews for cement job -reviewed procedure-discuss task&contingency. 05:00 05:30 0.50 5.50 DRILL G 5 P Shut down-R/U Franks tool&P/U Schlumberger cement head. 05:30 07:30 2.00 7.50 DRILL G 7 P Circulate&condition mud for cement Job\stage-up rate to 360 gpm @ 440 psi.\Reciprocating 13 3/8"csg. 07:30 11:30 4.00 11.50 DRILL H 7 P Schlumberger pump 5 bbls.H2O&test lines to 2500 psi.-OK I Pump 107.3 bbls.of 10.1 ppg Mudpush II @ 5.3 bpm with L/i,r 300psi.I Drop bottom plug\Mix&pump 332 bbls.of 10.85 ppg Lead Slurry(451 sks)5.31 yield with mix fluid @ 20.852 " gla/sk @ 5.5 bpm with 460 psi.\Schlumberger mix&pump 72.6 bbls.of 12 ppg Tail Slurry(244 sks)1.58 yield with mix q� 1 I 1 fluid @ 5.043 gal/sk @ 4.2 bpm with 365 psi\Drop top plug\Schlumberger pump 10 bbls.H2O for wash-up\Rig pump Cis displace cement with 339.3 bbls.of 9.5 ppg mud @ 8 bpm,ICP @ 385 psi.-slow pump rate to 2 bpm @ 319 bbls away\ ir I Bump plug to 850 psi.(500 psi.over FCP @ 350 psi.)\Hold for 2 minutes-bleed off&check floats-holding\Total of �/ 107 bbls of Mudpush&20 bbls of cement to surface.CIP @ 11:10 AM\Reciprocated casing until 50 bbls.Mudpush back [i -taking weight&land in hanger,PU=225K,SO=135K. - --- - Note:Lead Slurry was supposed to be 356 bbls.(443 sks)and 4.52 yield.Due to Schlumberger electric scales were reading light by 0.15 ppg;we were 24 bbls.short&lead slurry was 10.85 ppg.and yield was 5.31 ft/sk.This was confirmed by checking with mud scales. 11:30 15:00 3.50 15.00 DRILL G 5 P Flush-out stack&mud system\UD cement head&landing joint I P/U stack flushing tool-flush out riser stack\UD all tools from casing&cement job. 15:00 18:30 ' 3.50 18.50 DRILL E 5 P N/D flow line,surface riser&staring head UD same 1 prep conduct for well head with Vetco Gray Rep. 18:30 21:30 3.00 21.50 DRILL E 5 P Install well head on conductor per Vetco Gray Rep.-test to 5000 psi for 10 minutes,witness ENI Company Rep.\install ' well head valves\record RKB's measurements-top flange @ 31.51' 21:30 00:00 2.50 24.00 DRILL E 5 P N/U 13 5/8"riser&BOP stack-install bell nipple/flow line,Choke&Kill lines. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Enl representative David Smith ENI Sr.Drilling Spvr. 1907-670-8623 907-632-3085 Eni representative Bemie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com '1907-670-8607 907-575-9427 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com X907-685-1227 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Last Casing se at ----- Caa.Type I OD(In) _.. 1 ID(in) I _.._Grade Top( ) 1 Bottom(ftKS) Run Dab----_ CASING 133/8 12.415 L-80 0.0 2,421.0 7/19/2010 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) • iliyos Eni E&P Division Well Name: 0P12-01 EN!Petroleum Daily Report Well Code: 23972 • Co. Inc. Field Name: Nikaitchuq en• Date:7/21/2010 - Report#: 8 API/UWI: 500292342600 page 1 of 1 Wellbore name: OP12-01 Well Header Permit/Concession N° 'Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM i 100.00 HORIZONTAL Rotary Table Elevation(ft) I Ground Level(ft) I Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA I 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) 0P12-01 DRILLING 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 5.33 Daily Information Depth End(ftKB) Depth End(TVD)(...I Depth Progress(ft) Drilling Hours(hrs) IAverage ROP(ft/hr) POB Temperature(°F) Weather Wind 2,430.0 2,179.7 0.00 I 85.0 53.1 Mostly Clear. 181 S @ 8.1 mph Scattered Clouds. WC 53.1 Daily summary operation 24h Summary Finish N/U BOPE\Test BOPE-NT2 connection @ stack leaking\N/D BOPE&replace seal ring,N/U\Test BOPE 250 low/3500 high AOGCC John Crisp waived witnessing 07-20.10\P/U BHA#3 per Schlumberger\RIH U 2300'\Test 13 3/8"csg.to 2500 psi for 30 mins.\Tag cement @ 2325'. Operation at 07.00 Drilling float equipment(Tag cement @ 2325') 24h Forecast Drill out float equipment&25'new hole U 2455'\Change well over to LSND mud\perform LOT\drill ahead as per Eni Rep t/TD @ 5422' '.. Lithology ---- Shows __-- --_-- MAASP Pressure(psi) Mud Weight(lb/gal) 8.90_. Time Log Cum 1 I Start End Dur Dur 1 Time Time (hrs) (hrs) I Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50,DRILL C 5 [Fr N/U BOPE-finish flow line,install bleeder&fill hoses,also turn buckles(center stack)\R/U Katch-Kan&well bay roof spill containment. '03:30 06:00 2.50 6.00 DRILL C 12 P R/U Test equipment\BOPE 250 psi low/3500 psi high-chart record\NT2 connection adapter flange from riser to BOP leaking,Vetco Gray re-torque lock down screws&attempt to test still leaking.L/D test equipment&drain stack. - -- 06:00 09:00 3.00 9.00 DRILL C 5 u Remove Katch-Kan flow nipple,N/D BOP-split adapter flange-inspect&clean connection replace seal ring @ V/G NT2 �e / connection per Vetco Gray rep. '09:00 11:30 2.50 11.50 DRILL C 5 U N/U BOPE @ NT2 connection,install bell nipple&flow line,bleeder/fill-up lines&Katch-Kan. 11:30 16:30 5.00 16.50 DRILL C 12 P R/U test equipment\Test all rams,annular preventer,choke manifold valves,Kill&choke valves,IBOP's 7 floor valves to 250 psi.low/3500 psi.high for 5 minutes each test\chart record test\AOGCC John Crisp waived witness 7-20-10. 16:30 18:00 1.50 18.00 DRILL C 12 P UD test equipment&install wear bushing as per Vetco Gray rep.Prep rig floor for BHA. _ I 18:00 21:30 3.50 21.50 DRILL E 4 P P/U BHA#3 as per Schlumberger-RIH w/HWDP&4 stds 5*DP-P/U Ghost Reamer. 21:30 22:00 0.50 22.00 DRILL E 7 P Circulate-surface test Schlumberger MWD tools-665 gpm @ 920 psi.-OK. 22:00 22:30 0.50 22.50 DRILL E 4 P RIH f/1031'-V 2276'\Up wt.125k-Dn 120K. 22:30 00:00 1.50 24.00 DRILL E 12 P R/U to test 13 3/8'csg.0 Break circulation&pump drill pipe volume/Test 13 3/8"csg to 2500 psi for 30 mins.I record on chart-good. Dail Contacts Position Contact Name Company j Title E-mail OfITUT-7 Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative David Smith ENI Sr.Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bernie( Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com .907-670-8607 907-575-9427 Eni representative 'Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 1 907-980-7545 Eni representative 'Michael Seward ENI ;Project Advisor 1907-865-3337 907-952-7880 Last Casing seat I Cas.Type OD(in) 1 ID(in) Grade Top(ftKB) { Bottom(MB) Run Date 1 CASING 13 3/8 12.415 L-80 0.0 2,421.0 7/19/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,421.0 2,174.18 LSND 8.90 283.0 11.41 ; 1,288.2 Eni E&P Division � Well Name: 0P12-01 r9i* Daily Report r Well Code:23972---- ---- -- EN/Petroleum Field Name: Nikaitchuq • CO. Inc. Date:7/22/2010 - Report#: 9 API/UWI: 500292342600 e n n Wellbore name: OP12-01 page 1 of 1 Well Header Permit/Concession N° Opera I ENI Share(%) Well Configuration type 210069 ENI PETROLEUM 1 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) ,Water Dew RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 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) OP12-01 DRILLING J 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 6.33 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(f/hr) POB ,Temperature(°F) Weather Wind 2,930.0 2,481.3 500.00 6.76 74.0 85.0 44.8 Cloudy.Light Rain. 11N @ 9.2 mph WC 39.9 Daily summary operation 24h Summary RIO frnrn 133/1r csg test\Drill cement/float eauioment&25'+new hole(W 2455'\CBU-pump spacer&displace well over to new LSND mud\Perform LOT 13.7 ppg.EMW\Drill rotary steerable f/ 2455'-U 2930'. Operation at 07.00 - -- -- -_--- ----- - Drilling ahead rotary steerable as per Schlumberger\Added 1/2%by volume of Lube 776 to active system.Continue stage production liner&tubing on OPP pad. 24h Forecast Drill ahead as per Schlumberger DD f/2930'to TD @ 5422'.Prep for 9 5/8"casing\Stage production liner,tubing&mud products to finish well on OPP pad for the up-coming arrival of production modules. Lithology 1Shows MAASP Pressure(psl) IMud Weight(lb/gal) 8.95 Time Lam_ Cum Start End Our Dur Time Time (hre) (hrs) I Phase-- O pr. ...Act Plan Oper.Descr. 00:00 00:30 j 0.50 0.50 DRILL E 12 P R/D from 13 3/8"csg test&blow down. 00:30 11:30 11.00 11.50.DRILL E 3 P Drill cement&shoe track f/2325'-U 2430'(tag cement(0 2325',FC @ 2333',Shoe @ 2321')pump rate 560 gpm @ 822 psi.160 rpm @ 4-6K torque\WOB=2-12K\Up wt.=125K-Dn wt.=95K-Rot wt.=110k 11:30 12:00 0.50 12.00 DRILL E 3 P Drill f/2430'-V 2455'New hole for LOT test 1600 gpm @ 860 psi.\60RPM @ 4-5K torque\WOB=5-10K\Up wt.= 125k-Dn wt.=95k-Rot wt.=110K. 12:00 13:00 1.00 13.00 DRILL E 7 P Circulate botoms up-recprocating pipe with 600 gpm @ 850 psi.\60RPM @ 5k torque\Up wt.=125k-Dn wt.=95k-Rot wt=110K. 13:00 14:30 1.50 14.50 DRILL E 7 P Displace well with new LSND mud\pump 40 bbl.s.Steel Lube-EP spacer pill followed by 8.9 ppg LSND mud\Dump old 9.5 ppg spud mud&space to slop tank. 14:30 15:30 1.00 15.50 DRILL E 12 P Pulled into casing @ 2421'1 Perform FIT-LOT to 13.7 ppg.EMW\Test pressure to 543 psi;test mud wt.8.9 ppg;hold for 10 minutes. 15:30 16:00 0.50 16.00 DRILL E 7 P Circulate-Record new slow pump rates\PWD data to established ECD base-line&parameters. 16:00 00:00 8.00 24.00 DRILL E 3 P Drill rotary steerable f/2455'-t/2930'1 Pump rate 893 gpm @ 1420 psi.1100 RPM @ w/4-11k torque\WOB=10-15K\ ECD @ 9.26 ppg.\Up wt.=125K-Dn wt.=100K-Rot wt.=110K.\Schlumberger tool slip/stick problems f/2820'-V 2930' due to erratic torque levels from 4-11K-Increased Lotorq to 2%by volume. • ADT=6.76 hrs. ART=6.76 hrs. Drilling Jars=6.76 hrs. Dail Contacts Position I Contact Name Company I Title E-mail I Office Mobile Eni representative I Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative David Smith ENI ',Sr.Drilling Spvr. .907-670-8623 907-632-3085 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 1907-670-8607 907-575-9427 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com '.907-685-1227 Eni representative Alvin Criswell ENI !Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(In) I ID(in) Grade Top(ftKB) I Bottom(ftKB) Run Data CASING 13 3/8' 12.415 L-80 0.0 2,421.0 7/19/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type I Fluid Density(lb/gal) I P(Surf)(psi) ,Eq.Mud Weight(lb/gal)'Leak Off Pressure(psi) 2,421.0 2,174.18 LSND j 8.90 �__- 283.0 I 11.41 l 1,288.2 I I 1041 Eni E&P Division Well Name: 0P12-01 - - ENI Petroleum Daily Report Well Code: 23972 • Field Name: Nikaitchuq CO. Inc. Date:7/23/2010 - Report#: 10 API/UWI: 500292342600 page 1 of 1 Wellbore name: OP12-01 Well Header Permit/Concesslon N° Operator ,ENI Share(%) !Well Configuration type 210069 j ENI PETROLEUM J 100.00 HORIZONTAL Rotary Table Elevation(ft) (Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E !LAND RIG Job Information Wellbore Job Phase ISpud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) 0P12-01 DRILLING j 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 7.33 j Daily information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) !Average ROP(ft/hr) POB !Temperature(°F) Weather Wind 4,345.0 3,316.4 1,415.00 18.66 75.8 85.0 39.9 Cloudy.Fog.WC SN @ 13 mph 32.5 Daily summary operation 24h Summary Drill rotary steerable f/2930'-1/4345'\Fluid loses started 4188'MD\ROP slowed down @ 4345'MD-3318'TVD to 3-5 ft/hr. Operation at 07.00 Drill rotary steerable as per Schlumberger-encountered hard formation f/4345'-U 4353'-samples show 85%calcite/cemented sandstone,10%chart,5%clay.Consult with rig geologist to correlate with other wells&consult with town. 24h Forecast Drill ahead f/4345'to T/D @ 5275'\CBU 2X+\Short trip to shoe\RIH&CBU 3-4X(dean)\POOH&L/D BHA#3\Dummy run w/hanger\Hold PJSM w/GBR&R/U equipment&Frank's tool\P/U 9 5/8'csg&RIH. Lithology Shows - _- - MAASP Pressure(psi) Mud Weight(lb/gal) ` 9.15 Time Low__ Cum ' Start End Dur '... Dur Time Time (hrs) ! (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00, 12.00 DRILL E 3 P Drill rotary steerable f/2930'-t/3593'\Pump rate 900 gpm @ 1560 psi.\120 RPM @ w/3-5k torque\WOB=5-12K\Mud wt.9.0 ppg\ECD @ 9.56 ppg.\Up wt.=130K-Dn wt.=105K-Rot wt.=110K.\Added % by volume of Lube 776 to active system for slip/stick problems. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill rotary steerable f/3593'-U 4055'\Pump rate 898 gpm @ 1675 psi.\120 RPM @ w/6-7K torque\WOB=5-20K\Mud wt.9.0+ppg\ECD @ 9.6 ppg.\Up wt.=140K-Dn wt.=110K-Rot wt.=122K. 18:00 00:00 --/- 6.00 24.00 DRILL E 3 P Drill rotary steerable f/4055'-t/4345'\Pump rate 902 gpm @ 1775 psi.\120 RPM @ w/6-7K torque\WOB=5-20K\Mud wt.9.1+ppg\ECD @ 9.62 ppg.\Up wt.=145K-Dn wt.=110K-Rot wt.=125K.Hole started taking fluid @ 4188'@ 5.10 bbl/hr.with no static loses.Total lose last 24 hrs.@ 35 bbls. ADT=25.42 hrs. ART=25.42 hrs. Drilling Jam=35.92 hrs Daily Contacts Position I Contact Name I Company Title E-mail - Office Mobile Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith ENI iSr.Drilling Spvr. '907-670-8623 907-632-3085 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 1907-670-8607 907-575-9427 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Alvin Criswell ENI ',Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) j Bottom(f1KB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,421.0 7/19/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,421.0 2,174.18 LSND 8.90 283.0 11.41 1,288.2 ■ I Eni E&P Division Well Name: 0P12-01 1"fl* ENI Petroleum Daily Report WellCode: 23972 • CO. Inc. Field Name: Nikaitchuq en• Date:7/24/2010 - Report#: 11 API/UWI: 500292342600 (ri page 1 of 1 Wellbore name: OP12-01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210069 (ENI PETROLEUM 1 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E lLAND 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) OP12-01 DRILLING 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 - 80.3 8.33 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 5,518.0 3,617.6 1,173.00 17.31 67.8 89.0 38.7 Cloudy.Fog.WC 53 NE @ 12 mph 31.1 Daily summary operation 24h Summary Drill rotary steerable f/4345'-U 5518'as per Schlumberger DD\Encountered hard formation f/4345'-U 4353'-samples show 85%calcite/cemented sandstone,10%chart,5%day.ROP increased to 150'f/4353-1/4357'and then drop back to 3-5'ft/hr.ROP increased @ 4375't/5493'-encountered concretion f/5493'-1/5506'-f/5514'-U 5518'. Operation at 07.00 Drill rotary steerable U 5518'-1/5525'TD,drilling on concretion;ROP @ 1-3 ft/hr:discussed with Geologist. 24h Forecast T/D well per Geologlist\CBU 2-3X\Short trip to 13 3/8"shoe\CBU(+\-)4X\POOH\L/D BHA#3\Pull wear bushing&Dummy run w/hanger\Change rams 1/9 5/8"&test to 3500 psi.\PJSM w/ GBR r/u&run 9/58"csg. Llthology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) , -.---9.35 Time Log Cum Start End Dur Dur Time Time (hrs) (hr.) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 DRILL E i3 P Drill rotary steerable 0 4345'-1/4838'(3,501 TVD)\Pump rate 900 gpm @ 1880 psi.\120 RPM @ w/5-6k torque\WOB= 8-12K\Mud wt.9.12 ppg\ECD @ 9.76 ppg.\Up wt.=140K-Dn wt.=105K-Rot wt.=125K. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill rotary steerable f/4838'-1/5275'\Pump rate 902 gpm @ 1980 psi.\120 RPM @ w/7K torque\WOB=12-16K\Mud wt.9.2+ppg\ECD @ 9.68 ppg.\Up wt.=136K-Dn wt.=102K-Rot wt.=115K. 18:00 18:30 0.50 18.50 DRILL E 7 U Circulate&reciprocate pipe\900 gpm @ 2000 psi\120 rpm @ 4-5k torque\Lost connection from Schlumberger Interact data link from to town. 18:30 00:00 5.50 24.00 DRILL E 3 P Drill rotary steerable f/5275'-t/5518'\Pump rate 902 gpm @ 2050 psi.\120 RPM @ w/6K torque\WOB=12-16K\Mud 1 wt.9.3+ppg\ECD @ 9.82 ppg.\Up wt.=135K-Dn wt.=100K-Rot wt.=115K.Encounter gas 5449'MD/3617'TVD, highest reading of 1262 units,flow check-Static. I ADT=42.73 hrs. ( I I ART=42.73 hrs. Drilling Jam=53.23 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith ENI Sr.Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Last Casing seat Gas.Type OD(in) I ID(in) Grade Top(RKB) 1 Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 0.0 2,421.0 7/19/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) rEq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,421.0 --..� 2,174.18 LSND 8.90 283.0 11.41 1,288.2 • Eni E&P Division Well Name OP12-01 -.. ENI Petroleum Daily Report Well Code: 23972 . Field Name: Nikaitchuq�j n Co. Inc. Date:7/25/2010 - Report#: 12 API/UWI: 500292342600 ?n I) Wellbore name: OP12-01 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) (Well Configuration type 210069 ENI PETROLEUM 100.00 'HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 g 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) 1Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) OP12-01 DRILLING 7/16/2010 12,709.9 1 3,633.2 12,738.00 158.63 80.3 9.33 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind ',. 5,527.0 3,618.8 9.00 4.19 2.1 91.0 44.8 Clear.WC 44.8 22 NNE @ 2.2 mph Daily summary operation 24h Summary Drill rotary steerable f/5518'-t/5527'as per Schlumberger DD\Encountered concretion f/5493'-1/5506'-f/5514'-t/5527';ROP @ 1-2 ft/hr.Consult with Geologist&Anchorage to TD well\POOH on elevators to BHA\L/D BHA#3\P/U BHA#4(12"hole opener)\RIH to 2400'inside shoe\Cut drilling line,service rig,recalibrate SLB/MWD I RIH 1/4600'-Tag @ 4360'-ream twice f/4350'-1/4375' with hole opener-pass through free. Operation at 07.00 RIH f/4600'-t/5527'with no problem\Circulate&condition mud,pump weighted sweep&CBU 4x-until clean\POOH. 24h Forecast --- -- Circulate weighted sweep CBU 4 X\POOH&UD BHA#4 I Pull wear bushing&Dummy run hanger I Test plug&change rams 1/9 5/8"&test\R/U GBR equipment tools\P/U 9 5/8"csg.&RIH\ Circulate. Lithology --- _ _----- Shows - _--- ___-- --- MAASP Pressure(psi) (Mud Weight(lb/gal) !..1 9.30 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan _--.-._Oper.Descr. 00:00 06:00 - 6.00 6.00.DRILL E 3 P Drill rotary steerable f/5518'-t/5527'(3,619')I Pump rate 900 gpm @ 2030 psi.1 660-100 RPM @ w/6-9K torque\ WOB=18-20K\Mud wt.9.3 ppg I ECD @ 9.61 ppg.\Up wt:135K;Dn wt.-100K;Rot wt-115K.Drilling on concretion f/ 5518'-1/5527';ROP @ 1 ft/hr.Metal increase in drilling cutting sample I torque cycling from 5-9K I Drilling consulted with Anchorage and decided to TD intermediate section of well. ADT=46.53 hrs. ART=46.53 hrs. Drilling Jars=57.03 hrs. 06:00 06:30 0.50 6.50 DRILL E 7 P Circulate I TD survey point&down link SLB Exceed\monitor well-static\Mud properties good mud wt.@ 9.3 ppg\ ECD dropped to 9.6 ppg. 06:30 12:00 _ 5.50 12.00 DRILL E 4 P POOH on elevators f/5527'-U 173'@ Schlumberger tools I no swabbing&proper hole fill no problems,smooth. 12:00 15:30 3.50 15.50 DRILL E 4 P L/D BHA#3-Schlumberger tools&clean floor\Ghost reamer in gauge-string stabilizer blades wore down to 9 5/8'on the bottom 2-3"-middle 6"gauged 2 11 13/16"-top 6"gauged @ 12 1/8".The Arc had 1'wear on bottom pads\Bit&near bit stabilizer showed minor wear&in gauge. 15:30 17:00 1.50 17.00 DRILL E 4 P P/U BHA#4-12"hole opener as per Schlumberger DD-P/U ghost reamer. 17:00 18:30 1.50 18.50 DRILL E 4 P RIH f/580'-1/2400'I Up wt.-100K,Dn wt.-90K. 18:30 19:00 0.50 19.00 DRILL E 7 P Circulate Bottoms-up @ 2400'1 200 gpm @ 840 psi. 19:00 21:00 2.00 21.00 DRILL E 5 P Slip&cut drilling line I Service rig I Recalibrate block height SLB/MWD. 21:00 00:00 3.00 24.00 DRILL E 4 P RIH f/2400'-1/4600'-Tag @ 4360'-ream twice f/4350'-1/4375'with hole opener-pass through free. Daily Contacts Position I Contact Name Company i Title Emall I Office Mobile Eni representative .Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith ENI Sr.I Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bemie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com :907-670-8607 907-575-9427 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 1907-685-1227 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com '. 907-980-7545 Last Casing seat Cas.Type 1 OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Data CASING 13 3113 12.415 L-80 0.0 2,421.0 7/19/2010 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psl) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,421.0 2,174.18 LSND 8.90 283.0 11.41 1,288.2 Eni E&P Division Well Name: 0912-01 11* Daily ort EN!Petroleum Y Re p Well Code: 23972 (• Co. Inc. Field Name: Nikaitchuq ill• o. Date:7/26/2010 - Report#: 13 API/UWI: 500292342600 te page 1 of 1 Wellbore name: OP12-01 Well Header Permit/Concession N° ',Operator ENI Share(%) Well Configuration type 210069 IENI PETROLEUM _! 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 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) 0P12-01 DRILLING 7/16/2010 12,709.9 l 3,633.2 12,738.00 158.63 80.3 10.33 Daily information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft)frilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 5,527.0 3,618.8 0.00 0.50 0.0 92.0 41.2 Fog.WC 35.1 40 NNE @ 10 mph Daily summary operation 24h Summary --- ----- RIH f/4600'-U 5527'with no problem\circulate&condition mud-pump weight sweep&CBU 4+(clean)-monitor well\POOH on elevators\UD BHA#4\Pull wear bushing&set test plug\Change tnn R(lP mms_t/o F/R"esg\Tent In 28/1/3500 nci•nhnrt record\Perform hanger dummy run as per Vetco Gray rep.\R/U GBR equipment&Frank's tool\Held PJSM for 9 5/8"csg.\P/U&run 9 5/8'csg. As per ENI procedure.\Nabors Pipe skate down due to electrical problems(broken wire). Operation at 07.00 --- --- -_-- -- Finished electrical repairs on pipe skate&function tested-good @ 0030 hrs.\Continue to P/U 9 5/8"csg f/710'-install centralizers as per procedure-stop @ 2396'(58 joints)Up wt.=135K-Dn wt.= 122K 5 CBU-stage rate up to 2l0gpm @ 225 psi. 24h Forecast P/U 9 5/8"csg.to bottom\Circulate&condition mud\PJSM w/Schlumberger mix/pump MudPush&cement\displace w/Versa Pro,rig pumps\RID cement equipment&install pack-off&test\ Freeze protect annulus\P/U 5"drill pipe. 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 01:00 1.00 1.00 DRILL E 4 P RIH f/4600'-t1 5527'with no problems\wash down f/5462'-If 5527'5 Up wt.135K-Dn wt.90K. 01:00 04:00 3.00 4.00 DRILL E 7 P Circulate&condition mud for 9 5/8'csg.\Pump weighted sweep&CBU 4x,until clean\Rotate&reciprocate pipe with 900 gpm @ 1940 psi.\120 RPM @ 6-7K torque\Up wt.=135K.Dn wt.=95K,Rot wt.=115K.Monitor well 10 mins.-static. 04:00 08:00 4.00 8.00'.DRILL E 4 P POOH f/5527'-tl 540'(on elevators)-smooth with proper hole fill-pump dry job @ 4100'. 08:00 11:00 3.00 11.00 DRILL E 4 P Stand back three 5"HWDP stands\L/D BHA#4-from the ghost reamer to hole opener\stabilizer was worn from back reaming on the top 2"of the blades\clean floor up. 11:00 14:00 3.00 14.00 DRILL G 5 P Pull wear bushing&install test plug per Vetco Gray rep.\Change top rams f/4"x 7"-t/9 5/8"csg. 14:00 15:00 1.00 15.00 DRILL G 12 P Test 9 5/8"csg rams to 250/3500 for 10 mins.-chart record. 15:00 _16:00 1.00 16.00 DRILL IG 1 P R/U test equipment&perform hanger dummy run as per Vetco Gray rep.-good.L/D same. 16:00 17:30 1.50 17.50 DRILL G 1 P R/U GBR equipment&Frank's tool-Held PJSM for running 9 5/8"csg.with all personnel involved. 17:30 21:00 3.50 21.00'DRILL G 4 P P/U&run 9 5/8"csg.11710'\Check float equipment,average make-up torque,fill&top off every 10 joints,checking for returns-Install centralizers as per procedure. 21:00 00:00 3.00 24.00 DRILL G 25 U Nabors pipe stake down due to electrical problems\Rig electrician trouble shoot system-check proximity switch,found electrical line broke&repaired\Record as down time. i Daily Contacts Position I Contact Name Company Title E-mail Office Mobile Eni representative 'Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith ENI Sr.Drilling Spvr. 907-670-8623 907-632-3085 I Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Last Casing seat Cas.Type OD(In) I --- ID(in) Gtsde Top(trite) I . . (Bottom(ftKB) Run Date CASING 9 5/81 8.681 L-80 -0.81 5,510 0 7/26/2010 Last Leakoff Test Depth(ftKB) 1TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,421.0 1 2,174.18 �LSND __--- 8.90 283.0 11.41 L_--_ 1,288.2 1 I los, Eni E&P Division Well Name: OP12-01 Daily p Re ort ENI Petroleum Well Code: 23972 . Field Name: Nikaitchuq n CO. Inc. Date:7/27/2010 - Report#: 14 API/UWI: 500292342600 11(1 Wellbore name: OP12-01 page 1 of 1 Well Header PermIt/Concession N° Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM _J 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig Information Contractor Rig Name I 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) 0P12-01 DRILLING 7/16/2010 12,709.9 3,63.3.2 12,738.00 158.63 80.3 11.33 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB 'Temperature(°F) Weather Wind 5,527.0 3,618.8 _ 0.00 92.0 42.6 Fog.WC 41.2 96 E @ 3.5 mph Daily summary operation ,24h Summary Finished on Nabors Pipe skate electrical wire,(broken)1 P/U 9 5/8"csg.f/710'-U 2396'\Circulate bottoms-up\Continue P/U 9 5/8"csg.f/2396'-U 5510'\Circulate&condition mud for cement job- PJSM\Change out Frank's tool for SLB cement head\Schlumberger pumped 75 bbls Mudpush II©10.5 ppg followed by 110 bbls./(404 pks)Deep Crete cement 12.5 ppg.\Rig displaced w/398 bbls.of OBM I Bump plug 500 psi over FCP of 650 psi.(1150 psi)\check float equipment\Install 9 5/8"pack-off&test to 5000 psi for 10 mins.\Change rams&test 250/3500 psi\Freeze protect annulus\Install wear bushing\Clean active pit system for OBM\RIH w/HWDP. Operation at 07.00 RIH drill pipe worn hard band&UD same\P/U 5'drill pipe to replace. 24h Forecast UD drill pipe with worn hard band\P/U drill pipe to replace an amount to TD well\P/U BHA#5 as per Schlumberger DD\RIH. ` Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) V. i 9.35 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) ( Phase Opr. Mt. Plan --Opsr_Descr, r,,l .- -7? ar,;g,,,.; 00:00 00:30 ' 0.50 0.50 DRILL G 25 U Pipe stake broken wire was repaired by Nabors electrician-function test good. 00:30 03:00 2.50 3.00 DRILL E 4 P P/U 9 5/8"csg:L-80-47#I f/710'-U 2396'-Fill with Frank's tool,Checking for returns-Install centralizers as per t; procedure. 03:00 03:30 0.50 3.50 DRILL G 7 P Circulate bottoms-up @ 2396'(13 3/8"shoe)\stage rate up to 210 gpm @ 225 psi.Up wt.=135K-Dn wt.=112K. 03:30 10:00 6.50 10.00 DRILL G 4 P Continue P/U 9 5/8"csg.-L-80-47#\f/2396'-U 5510'-break circulate @ 3996'w/210 gpm @ 330 psi.\P/U landing Joint\ '. Up wt.=235K-Dn wt.=145K. 10:00 12:00 2.00 12.00 DRILL G 7 P Circulate&condition mud for cement job(18 yield point)-stage rate up to 208 gpm @ 290 psi\Up wt.=220K-Dn wt.= 145K.-Continuous pipe reciprocation 1 Held PJSM with Schlumberger cementers&rig personnel\UD GBR Franks tool and P/U cement head I Continue to circulate. 1( 12:00 16:00 4.00 16.00 DRILL H 7 P Pump 5 bbls.of water&test cement lines to 4000 psi.I SLB pump 75 bbls.Mud Push II @ 10.5 ppg.I Shut down and ` iA�`° drop bottom plug I SLB batched&pump 110 bbls.1404 sacks of Deep Crete cement,12.5 ppg.1.54 ft3/sk 1 5.133 gal/sk. @ 5 bpm.Drop the top plug&pumped 5 bbls.of water.Switched to rig pumps&displace with 398 bbls.of 8.9 ppg OBM /fit 1-;@ 5 bpm with 650psi.Slowing down to 3 bpm @ 600 psi.the last 15 bbls.I plug land on calculated strokes.Held 500 psi. (/ over FCP of 650 psi(1150 psi).\bleed off&check floats.I Good. CIP @ 1600 hrs. 16:00 18:00 2.00 18.00 DRILL G 5 P R/D Schlumberger cement head&lines\UD landing joint\R/D GBR casing equipment. 18:00 19:00 1.00 19.00 DRILL G 5 P M/U Vetco Gary 9 5/8"Pack-off\set in place&test to 5000 psi.for 10 minutes\L/D running tool. 19:00 20:30 1.50 20.50 DRILL E 5 P Change top rams from 9 5/8"to 4'x 7"variables. 20:30 22:00 1.50 22.00 DRILL E 12 P M/U&install test plug\test rams to 250/3500 psi.for 5 minutes each\pull test plug. 22:00 22:30 0.50 22.50 DRILL E 5 P Install wear bushing as per Vetco Gray rep.1 9 1/16 ID.\Freeze protect 9 5/8"x 13 3/8"annulus with 150 bbls.diesel\ ICP=1.04 bpm @ 350 psi.\FCP=1.34 bpm @ 1000 psi. 22:30 23:30 1.00 23.50 DRILL E 1 P Clean active mud system to change over to OBM(Versa-Pro)1 Clean/dear floor.I Completed freeze protection. 23:30 00:00 0.50 24.00 DRILL E 4 P P/U mule shoe&RIH with two stands of HWDP U 187'. Daily Contacts Position I- ---- Contact Name Company I Title -:,E4INM;; '' �;: s .,, .„ ...,".,Mobile Eni representative Jack Keener ENI 'Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith ENI 'Sr.Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Alvin Criswell ENI iExpediter Alvin.Criswell @enipetroleum.com 907-980-7545 Last Casing seat Cas.Type OD(in) - I ID(in) Grade Top(ftKB) Bottom(ft103) Run Date CASING -- ---- 5/81 8.681 L-80 __---- - -0.8 ---5,510.07/26/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,421.0 2,174.18 LSND 8.90 283.0 11.41 1,288.2 • ora Eni E&P Division Well Name: 0 1201 rjohil Dail t ENI Petroleum ' Y Re or p Well Code: 23972 • Field Name: Nikaitchuq nn Co. Inc. Date:7/28/2010 - Report#: 15 API/UWI: 500292342600 211 B II Wellbore name: OP12-01 page 1 of 1 Well Header Permit/Concession N° I Operator ENI Share(%) Well Configuration type 210069 IENI PETROLEUM _J 100.00 ,HORIZONTAL Rotary Table Elevation(ft) I Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 1 12.20 0.00 Rig Information Contractor I 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) OP12-01 DRILLING 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 12.33 Daily Information Depth End(ftKB) Depth End(TVD)(...I Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 5,527.0 3,618.8 1 0.00 91.0 49.6 Cloudy.WC 49.6° 88°E @ 2.2 mph Daily summary operation 24h Summary RIH w/HWDP&5"drill pipe to 1610'-remove LSND mud from pits.\POOH UD 1244'drill pipe with worn hard band-Vac out LSND mud from pits\P/U 9 joints 5"drill pipe w/good hard band,stand back in derrick\Remove&load 5"drill pipe in shed-clean pits\P/U 5"drill pipe U 2886'\Service rig(rough neck)\P/U 5"drill pipe f/2886'-t/5057'\Circulate to flush pipe&balance fluid\POOH f/ 5057'to surface\P/U BHA#5&load sources. Operation at 07.00 RIH\P/U 5"drill pipe to 2761' 24h Forecast P/U BHA#5\P/U 5"drill pipe to float equipment\Break circulation\R/U&test 9 5/8"csg.to 3000 psi for 30 mins.\Drill float equipment as per Weatherford procedure&20'+new hole\Perform LOT/FIT to 12 ppg minimum\Drill ahead as per well plan. Lithology _-- ..-_ Shows --- --- --- ---- MAASP Pressure(psi) Mud Weight(lb/gal) 8.40 Time Log Cum Start End Dur Out Time Time (hrs) (hrs) phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 14 U RIH with 5"HWDP&14 stands of drill pipe to 16107 Vac-truck LSND mud from rig pits. 02:00 04:30 2.50 4.50 DRILL E 4 U POOH\UD 1244'of 5"drill pipe with worn off hard band under spec.\Continue removing LSND mud from rig pits&start cleaning same. 04:30 05:30 1.00 5.50 DRILL E 4 U P/U 9 joints of drill pipe with good hard band after being sorted out&stand back in derrick. 05:30 08:00 2.50 8.00 DRILL E 1 U Remove 33 joints of 5"drill pipe from pipe shed/Load 163 joints in pipe shed&strap same\clean rig pits&transfer new (VersaPro)mud to same. 08:00 12:00 4.00 12.00 DRILL E 4 P P/U 5"drill pipe t/2886'. 12:00 12:30 0.50 12.50 DRILL E _ - 25 P Service rig\ dies on rough neck to better fit hard band on pin ends. 12:30 15:30 3.00 15.50 DRILL E 4 P P/U 5"drill pipe f/2886'-t/5057'. 15:30 17:30 ' 2.00 17.50'DRILL E 7 P Circulated to flush pipe and balance fluids(1 bottoms-up)600 gpm @ 800 psi.\Flush all mud pumps with OBM/8.6 ppg. 17:30 20:00 2.50 20.00 DRILL E 4 P POOH f/5057'to surface. 20:00 00:00 4.00 24.00 DRILL E 4 P _--- Held PJSM\P/U BHA#5 as per Schlumberger DD/MWD-load sources into tools. - Daily Contacts -. Position Contact Name Company Title E-mail Office Mobile Eni representative ,Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith ENI Sr.Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative ',Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com ''907-865-3323 907-947-4323 Last Casing seat Cas.Type OD(In) 1 ID(In) Grade Top(RKB) 1 Bottom(RKB) Run Date CAA SING - ---_-_- - 95/81 -_-_ 8.681 L-80 --- 081 5,510.07/26/2010 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 2,174.18 LSND 8.90 283.0 11.41 1,288.2 Eni E&P Division Well Name: 0P12-o1 - IP* Daily Report ENI Petroleum y p Well code. 23972 CO. Inc. Field Name: Nikaitchuq 2 ^ Date:7/29/2010 - Report#: 16 API/UWI: 500292342600 rnl Wellbore name: OP12-01 - page 1 of 1 Well Header Permit/Concession N° Operator IENI Share(%) Well Configuration type 210069 IENI PETROLEUM 1 100.00 HORIZONTAL Rotary Table Elevation(ft) I Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 1 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) i Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) 0P12-01 DRILLING 7/16/2010 12,709.9 3,633.2 12,738.00 1 158.63 80.3 13.33 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(CF) Weather Wind 6,050.0 3,639.8 523.00 5.10 102.5 89.0 42.3 Cloudy.Showers WC 49°NE @ 8.3 mph 1 37.4° Daily summary operation 24h Summary BHA#5-finished loading sources&RIH U 852'-surface test tools-OK\P/U 5"drill pipe f/852'-U 4683'-fill @ 3016'\RIH w/stands f/4683'-I/5353'\Circulate DP+volume\Test 9 5/8"csg.to 3000 psi.for 30 minutes.\Rotary drill cement-float equipment-clean out hole f/5510'-U 5527'\Rotary drill 55527'-U 5547'-(20/new hole)\POOH U 5445'&circulate mud to balance 8.8 ppg.mud wt.\ Perform LOT-12.11 ppg.EMW\Perform PWD baseline parameters for ECD\Drill rotary steerable f/5547'-U 6050'as per Geologist&Schlumberger DD. Operation at 07.00 Drill Rotary steerable V 6050'-U 6405'as per Geologist&Schlumberger\Prep 5"liner\stock mud products on OPP pad\Remove Schlumberger cement silo and spot Baker Centrilift spool unit @ OPP pad. 24h Forecast Drill rotary steerable f/6095'to TD as per Geologist&Schlunberger DD-prep for sealift arrival. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.90 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) 1 Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 4 P Finished loading sources in Schlumberger tools&RIH with 5"HWDP&drill pipe to 852'1 surface test Schlumberger tools 440 gpm @ 710 psi./BHA below jars 60K-BHA 65K total. 02:00 05:30 3.50 5.50-DRILL E 4 P P/U 5"drill pipe f/852'-U 4683'-fill pipe @ 3016' 05:30 06:00 0.50 6.00 DRILL E 4 P RIH f/4683'-t/5353'from derrick. 06:00 07:00 1.00 7.00 DRILL E ,7 P Circulate&condition-mud weight balance @ 8.7 ppg.\500 gpm @ 1620 psi.\Up wt.=125K Dn wt.=90K. 07:00 08:30 1.50 8.50 DRILL E 12 P R/U\Pressure tested 9 5/8"/L-80/47#to 3000 psi for 30 minutes,chart record same.\R/D 08:30 12:30 4.00 12.50 DRILL E 3 P Tag @ 5417'\Drill cement&float equipment f/5417'-t/5510'\500 gpm @ 1480 psi.\65 RPM @ 4-6K torque\WOB= 2-14K\Up wt.=130K-Dn wt.100K-Rot wt.110K. 12:30 14:00 1.50 14.001 DRILL E 3 P Drill rotary steerable f/5527'-U 5547'\500 gpm @ 1450 psi.\65 RPM @ 4.5-5.3k torque\WOB=12K I Up wt.=132K- I Dn wt.100K-Rot wt.110K. 14:00 15:30 1.50 15.50 DRILL E 17 P POOH U 5445'in 9 5/8"csg.\Circulate to balanced 8.9 mud wt.I 500 gpm @ 1700 psi. 15:30 16:30 1.00 16.50 DRILL E 12 P R/U I Perform LOT on 9 5/8"shoe @ 55101 test mud wt.8.8 ppg fluid away&622 psi.I EMW @ 12.11 ppg.I R/D. 16:30 17:00 0.50 17.00 DRILL E 1 _ P Perform PWD baseline parameters for ECD. 17:00 00:00 7.00 24.00 DRILL E 3 P Drill rotary steerable f/5547'-60501 652 gpm @ 2350 psi.\120 RPM @ 5-6K torque\W OB=55-12K\Up wt.=135K-Dn wt.95K-Rot wt.105K.I Mud wt.@ 8.9 ppg.\ECD @ 10.39 ppg. ADT=5.1 hrs. ART=5.1 hrs. 1 Drilling Jars=7.6 hrs Daily Contacts Position i Contact Name Company i Title - _ - E-mail , Office Mobile Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith ENI ',Sr.Drilling Spvr. 907-670-8623 907-632-3085 Ertl representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Pete Adams ENI HSE Peter.Adams @enlpetroleum.com 907-685-1227 Eni representative !Greg Parker ENI Expediter Greg.Parker @enipetroleum.com I 907-980-7545 Eni representative 'Joe Longo ENI Drilling Eng. _ Joe.Longo @enipetroleum.com ''907-865-3323 907-947-4323 Last Casing seat Cos.Type OD(In) ID(in) Grade Top(Ct(S) Bottom(ftKB) Run Data CASING 9 5/8 8.681 L-80 -0.8 5,510.0 7/26/2010 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) 5,510.0 3,616.57 OBMM(VersaPro) i 8.90 622.0 1 12.21 2,294.1 1 I Well Name: OP12-01- ',. • Daily Report od n► Division EN!Petroleum weu code: z3s7z • CO. Inc. Field Name: Nikaitchuq ^ Date:7/30/2010 - Report#: 17 API/UWI: 500292342600 a page 1 of 1 Wellbore name: OP12-01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) [Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 I 12.20 0.00 • Rig Information Contractor I Rig Name Rig Type NABORS ALASKA I 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) 0P12-01 DRILLING I 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 14.33 Daily Information Depth End(RKB) Depth End(TVD)(...I Depth Progress(ft)1 IDritling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind • 8,115.0 3,628.4 I 2,065.00 14.36 143.8 89.0 1 55.8 Cloudy.WC 55.8° 180°S @ 2.3 mph Daily summary operation 24h Summary Drilled 2065'f/6050'MD to 8115'MD(3639.5'TVD-3625'TVD). Crossed fault at 6712'MD/3642.5'TVD while attempting to build from 0A3 Sand to 0A1 Sand. Operation at 07.00 Currently drilling ahead @ 8,382'MD/3,628.4'TVD. 24h Forecast Continue to drill ahead f/8115'MD to-8500'MD in OA1 Sand then begin dropping back into 0A3 Sand.Planned TD 12709'MD) Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.90 Time Log Cum I Start End Dur Dur I Time Time (hrs) (hrs) I Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 DRILL E 3 P DRILLING-Drill f/6050'MD to 7080'MD(3640'TVD-3639.5'ND). Backreaming 6-10 min per stand. Crossed unmapped fault at 6712'MD/3642.5 while attempting to move from lower 0A3 Sand to 0A1 Sand. -650 gpm,140 RPM,2-6 WOB -2520/2540 psi OFF/ON • -5400/6000 TQ OFF/ON -140 PU/90 SO/103 ROB MW=8.8 ppg,ECD=10.7-10.9 EMW -ROP 150-200 fph 12:00 18:00 6.00 18.00 DRILL E 3 P DRILLING-Drill f/7080'MD to 7700'MD(3639.5'TVD-3625.5'ND). Backreaming 6-10 min per stand. . -652 gpm,140 RPM,2-10 WOB -2500/2520 psi OFF/ON -6000/7000 TQ OFF/ON ' -140 PU/88 S0/102 ROB • MW=8.8 ppg,ECD=10.7-10.9 EMW -ROP 140-180 fph 18:00 00:00 6.00 24.00 DRILL E 3 P DRILLING-Drill f/7700'MD to 8115'MD(3625.5'ND-3628'TVD). Backreaming 6-10 min per stand. -652 gpm,140 RPM,2-11 WOB -2530/2550 psi OFF/ON -6900/9300 TQ OFF/ON • ' -148 PU/80 SO/100 ROB MW=8.9 ppg,ECD=10.7-10.92 EMW -ROP 140-180 fph Daily Contacts Position j Contact Name Company l Title E•mail Office Mobile Eni representative Jack Keener [NI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative :David Smith ENI Sr.Drilling Spvr. 907-670-8623 907-632-3085 Eni representative •Bemie Leas ENI 'Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Greg Parker ENI IExpediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative Joe Longo ENI IDrilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Last Casing seat Cas.Type OD(In) 1 ID(In) Grade Top(ftKB) I Bottom(RKB) Run Date CASING 9 5/8 8.681 L-80 -0.8 5,510.0 7/26/2010 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 5,510.0 3,616.57 OBMM(VersaPro) , 8.90 622.0 12.21 2,294.1 • Eni E&P Division ENI Petroleum Well Name: OP12-01 --_- Daily Report L Well Code: 23972__--- • Field Name: Nikaitchuq If*� Co. Inc. Date:7/31/2010 - Report#: 18 API/UWI: 500292342600 21III page 1 of 1 Wellbore name: OP12-01 Well Header Permit/Concession N° 'Operator ENI Sham(%) Well Configuration type 210069 1ENI PETROLEUM i 100.00 'HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig Information Contractor ;Rig Name 1Rig Type NABORS ALASKA j NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) 0P12-01 DRILLING l 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 15.33 Daily Information Depth End(ftKB) Depth End(TVD)(..."Depth Progress(ft) Drilling Hours(hrs) lAverage ROP(ft/hr) POB Temperature(°F) Weather Wind 9,178.0 3,657.2 1,063.00 14.50 73.3 90.0 39.4 Partly Cloudy.WC 18°NNE©6.7 mph 34.5° Daily summary operation 24h Summary Drilled 1063'f/8115'MD to 8796'MD. BROOH to 5729'MD. TIH back to bottom on elevators,uneventful. CBU. Drilled from 8796'MD to 9178'MD. -ADT 14.5 hrs. Operation at 07.00 Currently drilling ahead©9412'MD/3659.4'TVD -656 gpm,140 rpm,2-14 WOB -ROP 150-180 fph -MW 8.8 ppg -ECD 10.91 EMW 24h Forecast _.-.---- - --- - Continue to drill ahead f/9178'MD towards planned TD 12709'MD Uthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) ( 8.85 Time Log Cum -- -�Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. 1', Act. Plan Oper.Desce. „,;„-,- 00:00 06:00 6.00 6.00 DRILL E 3 P Drill f/8115'MD to 8595'MD. Backreaming 6-10 min per stand. -653 gpm,140 rpm,2-10 WOB -2560/2550 psi ON/OFF -8-9/6-7 K ft-lbs TQ ON/OFF -MW=8.8+ppg -ECD=10.9 EWM 06:00 09:30 3.50 9.50 DRILL E 3 P Drill f/8595'MD to 8796'MD. Backreaming 6-10 min per stand. -656 gpm,140 rpm,2-15 WOB -2640/2600 psi ON/OFF -8-9.5/7-8 K ft-lbs TQ ON/OFF -150 PU/85 SO/102 ROB -MW=8.8+ppg '.. -ECD=10.9 EMW 09:30 16:30 7.00 16.50 DRILL E 4 P BROOH f/7450'MD to 5729'MD. Minor torque spikes at 6900'MD-7000'MD,most likely due to pulling stabilzer through 4 deg dogleg at 6822'MD -635 gpm,100 rpm,2300 psi -6-7K ft-lbs -105 ROB 16:30 19:00 2.50 19.00 DRILL E 4 P TIH on elevators f/5729'MD to 8795'MD,uneventful. CBU prior to resuming drilling. Initial ECD 11.08 EMW while circulating stabilized at 10.8/10.9 EMW 19:00 00:00 5.00 24.00 DRILL E 3 P Drill f/8796'MD to 9178'MD. Backreaming 6-10 min per stand. -652 gpm,140 rpm,2-6 WOB -2800/2790 psi ON/OFF -9.4/8.2 K ft-lbs TO ON/OFF -150 PU/80 SO/102 ROB -MW=8.8 ppg -ECD=11.01 EWM Daily Contacts Position I Contact Name Company ' Title Erroll ! Office Mobile Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 1,907-685-1227 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor 1907-865-3337 907-952-7880 Last Casing seat Gas.Type OD(in) I ID(In) Grade Top(ftKB) I Bottom(RKB) Run Date CASING 95/8ii 8.681 L-80 -0.8 5,510.0 7/26/2010 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) 5,510.0 3,616.57 OBMM(VersaPro) 8.90 622.0 12.21 2,294.1 liois Eni E&P Division Well Name: OP12-01 ENI Petroleum Daily Report Well Code: 23972 . Field Name: Nikaitchuq/� n Co. Inc. Date:8/1/2010 - Report#: 19 API/UWI: 500292342600 LC n U Wellbore name: OP12-01 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM I 100.00 HORIZONTAL Rotary Table Elevation(ft) -I Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 I 12.20 0.00 Rig information Contractor Rig Name (Rig Type NABORS ALASKA NABORS 245 E I 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) 0P12-01 DRILLING 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 16.33 Daily Information Depth End(ftKB) Depth End(ND)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB I Temperature(°F) Weather Wind 10,712.0 3,643.3 1 1,534.00 13.77 111.4 93.0 64.6 Partly Cloudy.WC 199°NNE @ 18.1 64.6° mph Daily summary operation 24h Summary Drilled f/9178'MD 10615'MD. Pump 9.8 ppg weighted sweep. Results were marginal. Continue drilling ahead f/10615'MD to 10712'MD Total Footage Drilled-1534' ADT-13.77 hrs Operation at 07.00 Currently drilling ahead @ 11,030'MD/3,634.2'TVD MW=8.8 ppg ECD=11.59 EMW 24h Forecast Continue to drill ahead f/10712'MD towards planned TD at 12709'MD Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 Time Log Cum I Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Open.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 I P Drill f/9178'MD to 9660'MD. Backreaming 6-10 min per stand. -650 gpm,140 rpm,2-10 WOB -2750/2730 psi ON/OFF ( -9-10/8-9 K ft-lbs TQ ON/OFF -150 PU/82 SO/100 ROB -MW=8.8 ppg -ECD=10.98 EWM 06:00 12:00 I 6.00 12.00 DRILL E 3 P Drill f/9660'MD to 10120'MD. Backreaming 6-10 min per stand. -650 gpm,140 rpm,2-15 WOB -2780/2730 psi ON/OFF -8-9/9-10 K ft-lbs TQ ON/OFF -152 PU/78 SO/100 ROB -MW=8.8 ppg -ECD=10.98-11.1 EMW 12:00 18:00 6.00 18.00(DRILL E 3 P Drill f/10120'MD to 10470'MD. Backreaming 6-10 min per stand. 7 -652 gpm,140 rpm,2-12 WOB -2900/2880 psi ON/OFF -10.3/9.8 K ft-lbs TQ ON/OFF -168 PU/68 SO/100 ROB -MW=8.8+ppg -ECD=11.26 EMW 18:00 20:30 2.50 20.50 DRILL E 3 P Drill f/10470'MD to 10615'MD. Backreaming 6-10 min per stand. -652 gpm,140 rpm,2-12 WOB -2990/3000 psi ON/OFF -10-11/9.8 K ft-lbs TQ ON/OFF -168 PU/65 SO/100 ROB . -MW=8.8 ppg -ECD=11.38 EMW 20:30 23:00 2.50 23.00 DRILL E 3 I P Circulate 9.8 ppg weighted sweep at 652 gpm. Results were marginal. 23:00 00:00 1.00 24.00 DRILL E 4 P Drill f/10615'MD to 10712'MD. Backreaming 6-10 min per stand. -656 gpm,140 rpm,2-5 WOB -2950/2930 psi ON/OFF -10-11/9.7 K ft-lbs TQ ON/OFF -165 PU/68 SO/100 ROB } -MW=8.8 ppg I -ECD=11.3 EMW Daily Contacts Position I Contact Name Company I Tide B- all 1 Office Mobile Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 1907-865-3323 907-947-4323 Eni representative 'Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 1907-670.8607 907-575-9427 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 1907-685-1227 Eni representative I Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor ',907-865-3337 907-952-7880 Last CaaCasing seat OD(in); ID(in) Grade T YPe op(ftKB) i Bottom(kK8) Run Date Last Leakoff Test 8.681IL-80 -0.8 5,510.0 7/26/2010 CASING 9 5/8, Depth(ftKB) ND(ftKB) Fluid Type 1 Fluid Density(lb/gal) 1T2(Surf)(psi) Eq.Mud Weight(lb/gal) (Leak Off Pressure(psi) 5,510.0 3,616.57 OBMM(VersaPro) I 8.90 I 622.0 12.21 I 2,294.1 too s, Eni E&P Division Well Name: OP12-01 ENI Petroleum Daily Report Well Code: 23972 • CO. Inc. Field Name: Nikaitchuq + Date:8/2/2010 - Report#: 20 API/GIN!: 500292342600 (n i Wellbore name: OP12-01 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM I 100.00 ,HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB•Base Flange(ft) RKB-Tubing Spool(ft) 54.58 ,, 12.20 0.00 Rig information Contractor Rig Name I 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) I Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) OP12-01 DRILLING 7/16/2010 12,709.9 3,633.2 12,738.00 j 158.63 80.3 17.33 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) ;Average ROP(ft/hr) POB Temperature(°F) Weather Wind 12,241.0 3,660.7 1,529.00 24.00 1 63.7 93.0 54.3 Mostly Clear WC 236°SSW @ 4.3 i 54.3° mph Daily summary operation 24h Summary Drilled from 10712'MD to 12241'MD. Thinned mud back to low end of rheology parameters,decreasing ECD significantly(-11.6-11.13 EMW) -Total Footage-1529' -ADT-16.76 hrs. Operation at 07.00 Currently drilling ahead at 12,462'MD/3,656.6 TVD' -652 gpm,140 rpm,150 fph -MW=8.8 ppg,ECD=11.36 EMW 24h Forecast Drill ahead TD at-12709'MD. CBU 3x min. Pump weighted sweep. BROOH to Intermediate casing shoe. CBU 3x min. TIH on elevators. CBU 4-5x while reciprocating and rotating at 140 rpm. Displace well to 9.0 CaCl2 w/1.5%Safe Lube. POOH on elevators. Lithology _.-_- Shows MAASP Pressure(psi) IMud Weight(lb/gal) 8.80 Time Log Cum Start End Dur Dur Time Time (hre) (twa) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 IP Drill f/10712'MD to 11190'MD. Back reaming 6-10 min per stand and reaming back to bottom -650 gpm,140 rpm,2-8 WOB,150 fph -3000/2950 psi ON/OFF -11-12/10 K ft-lbs TQ ON/OFF -163 PU/70 SO/98 ROB I1 -MW=8.8ppg -ECD=11.4 EMW 06:00 12:00 6.00 12.00 DRILL E 3 P Drill f/11190'MD to 11620'MD. Back reaming 6-10 min per stand and reaming back to bottom -650 gpm,140 rpm,2-8 WOB,150 fph -3090/3000 psi ON/OFF -11-12/9-10 K ft-lbs TQ ON/OFF -168 PU/68 SO/98 ROB -MW=8.8 ppg -ECD=11.3 EMW 12:00 18:00 6.00 18.00 DRILL E 3 P Drill f/11620'MD to 11900'MD. Back reaming 6-10 min per stand and reaming back to bottom.Thined mud back to low end of rheology parameters. ECD's dropped significantly(-11.6 to-11.13 EMW) -656 gpm,120/140 rpm,2-15 WOB,150 fph -3010/3000 psi ON/OFF -13-15/12.5 K ft-lbs TQ ON/OFF -175 PU/55 SO/98 ROB -MW=8.8 ppg -ECD=11.13 EMW 18:00 00:00 6.00 24.00 DRILL E 3 P Drill f/11900'MD to 12241'MD. Back reaming 6-10 min per stand and reaming back to bottom. -652 gpm,120/140 rpm,4-16 WOB,150 fph -3060/3050 psi ON/OFF -11.8-14/11.8 K ft-lbs TO ON/OFF -178 PU/50 SO/100 ROB -MW=8.8 ppg -ECD=11.18 EMW Daily Contacts Position Contact Name Company I Title E-mail I, Office Mobile Eni representative Jack Keener ENI Sr.I Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Greg Parker ENI Expediter Greg.Parker©enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI ,Project Advisor 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(in) I ID(In) Grade Top(ft)(B) I Bottom(ftICB) Run Date CASING 9 5/8 8.681 L-80 -0.8 5,510.0 7/26/2010 Last Leakoff Test Depth(ftKB) ITVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,510.0 3,616.57 OBMM(VersaPro) 8.90 622.0 12.21 2,294.1 I . a Eni E&P Division Well Name: OP12-01 ENI Petroleum Daily Report Well Code: 23972 • CO. Inc. Field Name: Nikaitchuq Date:8/3/2010 - Report#: 21 API/UWI: 500292342600 page 1ofl Wellbore name: OP12-01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 _ Rig Information Contractor I 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) 0P12-01 DRILLING 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 18.33 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 12,860.0 I' 619.00 10.50 59.0 94.0 47.8 Partly Cloudy.WC 40°NE @ 11.5 mph 43° Daily summary operation 24h Summary nrilled ahead to TD at 12.860'MD/3,621.57'TVD,Circulate and condition hole. Pumped sweep.650 GPM,155 SPM,120 RPM,10-12 TQ, 3190 PSI. Backream from 12,860'to 8,600'. 140 RPM, 652 GPM,154 SPM, Operation at 07.00 Backreaming at 7,470'. 24h Forecast -------- -- ----------- - _._.------Conrtinue to backream to 9-5/8-shoe at 5,510'. CBU 3-4 times. Run to bottom and circulate and condition hole. CBU 4-5 times. Change mud system to 9.0 ppg CaCl2 brine solution.POOH.UD BHA.Run BOPE test. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.90 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 10:30 10.50 10.50-DRILL E 3 P Drill f/11241'MD to 12860'MD. Back reaming 6-10 min per stand and reaming back to bottom. TD 8-1/2"OH Section at 12860'MD/'TVD -650 gpm,140 rpm,2-15 WOB,150 fph -3160/3100 psi ON/OFF -12-13/10-11 K ft-Ibs TO ON/OFF -180 PU/55 SO/98 ROB -MW=8.8 ppg - -ECD=11.1 EMW 10:30 12:00 1.50 12.00 DRILL E 7 P Circulate and condition hole. Pump 10.3 ppg weighted sweep. Recripocating pipe 3-5 min per stand. -650 gpm,120 rpm -3190 psi -10-12 K ft-Ibs TO 12:00 00:00 12.00 24.00 DRILL E 6 P BROOH f/12860'MD to 8600'MD. Increase in drag 9915'MD,PU 85K-102 K. -652 gpm,140 rpm -12860-3270PSI,TO 13.6K -12338 3170PSI,TQ 13.4K -11859 3100PSI,TQ 12.9K -11381 3000 PSI,TO 12.5K -10903 2982PSI,TQ 11.8K -10425 2934PSI,TQ 11.2K -9946 2820PSI,TQ 10.9K -9467 2700 PSI,TQ 10K -8988 2670PSI,TQ 9.7K Daily Contacts Position Contact Name Company I Title E-mail Office Mobile Eni representative Jack Keener ENI 'Sr.Drilling Spvr. Jack.Keener @enipetroleum.com .907-670-8623 907-715-6434 Eni representative Satoh Bowe ENI Drilling Spar. 907-670-8623 907-299-0531 Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Bemie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Eni representative 'Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Last Casing seat Cu.Type OD(In) I ID(in) ice'a le Top(RKB) 1 Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 -0.8 5,510.0 7/26/2010 ', 0.8 Last Leakoff Test Depth(ftKB) TVD(ftKB) _-- Fluid Type --- Fluid Density --------- ttY(Ib/gal) P(Surf)(psi) 'Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 5,510.0 3,616.57 OBMM(VersaPro) 8.90 622.0 12.21 1 2,294.1 of.py Eni E&P Division Well Name. OP12-01 Daily Report ENI Petroleum Well code: 23972 Field Name: Nikaitchuq nn•n Co. InC. Date:8/4/2010 - Report#: 22 API/UWI: 500292342600 CC g N I) Wellbore name: OP12-01 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) I Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA I 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) 0P12-01 DRILLING 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 19.33 Daily information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB ;Temperature("F) Weather Wind 12,860.0 0.00 94.0 50.2 Partly Cloudy.WC 93°E©10.5 mph I 50.2° Daily summary operation 24h Summary Circulate&condition hole.BROOH to shoe of 9-5/8"casing.Service rig.TIH.Circulate&condition hole. Displace to 9.0 PPG NaCL/3%KCI Brine. Operation at 07.00 POOH on elevators 24h Forecast Finish displacement to NaCI/3%Kcl Brine. POOH on elevators.Lay down BHA.Test BOPE. RU and run 5-1/2"liner. Lithology l 1 Shows MAASP Pressure(psi) Mud Weight(lb/gal) - - - Time Log Cum I Start End Dur Dur 1 Time Time (hrs) (hrs) I Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL E '.3 ;P Circulate and condition hole.CBU&BROOH to 8,475'Pump LVT sweep followed with a weighted sweep.140RPM 165SPM 2,800PSI 140RPM 8,200 TQ 02:30 06:30 4.00 6.50 DRILL E 6 P BROOH F/8,475'T/5,670'700GPM 165SPM 2,400PSI 140RPM 6.5-8.5 TO 06:30 09:00 2.50, 9.00 DRILL E i7 P CBU 3X Plus 3 weighted sweeps @ 700GPM 165SPM 2,400PSI 140RPM 5K TO Reciprocate Pipe 09:00 12:30 3.50 12.50':DRILL E 25 i P Service Rig 12:30 18:00 5.50 18.00 DRILL E 4 P TIH on elevators F/5,448'-12,785' 18:00 18:30 0.50 18.50 DRILL E 7 P Ream&Wash F/12,785'-12,860'120RPM 13,000TQ 600GPM 3,000PSI 18:30 22:30 4.00 22.50 DRILL E 7 P CBU 5X&condition hole to displace with brine 677GPM 160SPM 3,600PSI 22:30 00:00 1.50 24.00 DRILL E 7 P Displace to water base.PJSM W/all.Pump 20 BBL LVT/50 BBL sweep.Chase W/140BBLS 9#brine©6BBL per minute ! 254GPM 60SPM 745PS1/60RPM 100KROT.Slow pump rate to 4BBL per minute for remainder of displacement. Daily Contacts Position I Contact Name Company . Title t 4nall Office Mobile Eni representative Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative !Satoh Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 Eni representative IJoe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Last Casing seat Cas.Type OD(in) I ID(in) 1_ Grade Top(ftKB) I Bottom(ftKB) Run Dab CASING 9 5/8 8.6811L-80 -0.8 5,510.0 7/26/2010 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) 5,510.0 1 3,616.57 OBMM(VersaPro) 8.90 622.0 12.21 2,294.1 I Eni E&P Daily Report Well Code: 39k2cnu J • Co. Inc. q + Date:8/5/2010 - Report#: 23 API/UWI: 500292342600 page 1 of 1 Weilbore name: OP 12-01 _ Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM J 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 1 0.00 Rig Information Contractor Rig Name I 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) 0P12-01 DRILLING 7/16/2010 12,709.9 1, 3,633.2 12,738.00 I 158.63 80.3 20.33 Daily Information Depth End(ftOKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr)I1 POB Temperature(°F) Weather Wind 0.00 _ 95.0 42.1 Cloudy.WC 36.5° 5°N @ 9.3 mph Daily summary operation 24h Summary Displace wellbore with 9.0 PPG completion brine at 6 BPM 690 PSI for first 210 BBL Slow pump rate to 4 BBL 300 PSI per minute for remainder of displacement.11,000-12,000 TO;60 RPM; Reciprocate pipe.Brine to surface+25 bbls until clean as per M-I Swaco Engineer.Trip out of hole on elevators from 12,775'to 5,440'. No swab 6-8 bbl losses per hour.175 up wt.Circulate and condition hole and add steel lube pill at 5,460'.. POOH.Lay down BHA.Pull wear bushing.PU test joint.Set test plug. Began testing BOPE. Operation at 07.00 Testing BOPE. 24h Forecast -_-- - - -- ---_- - Complete testing BOPE. PU GBR liner running tools. PU and run 5-1/2"L-80 DWC and 5-1/2"L-80 Hydril 521 liner. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.00 Time Log Cum -- ---. -- -- ----_..------ Start End Dur Dur 1 Time Time (hrs) (hrs) 1 Phase Opr. Act. Plan Open.Descr. 00:00 03:30 3.50 3.50 DRILL E 9 P Displacing to completion fluid.9.OPPG brine.Slow pump rate to 4BBL per minute 300PSI.Reciprocate pipe&pump to surface till clean. 03:30 10:00 6.50 10.00,DRILL E 4 P POOH on elevators F/12,775'T/5,440'Fill hole every 5 STDS.No swabbing 8-10 BBI loss 10:00 11:00 1.00 11.00 DRILL E 7 P Circulate&condtion hole.Pump steel lube pill @ 5,460' 11:00 17:00 6.00 17.00 DRILL E 4_ - P POOH to BHA.LD 105 JTS DP-Worn hard band 17:00 21:00 4.00 21.00 DRILL E '4 P PJSM W/SLB MWD Pulling source to surface.Lay down remaining BHA 21:00 00:00 3.00 24.00 DRILL C 12 P Remove wear bushing.Test BOPE Daily Contacts Position I Contact Name Company , Title Email Office Mobile Eni representative 'Jack Keener ENI Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative Satch Bowe ENI Drilling Spvr. 1907-670-8623 907-299-0531 Eni representative Joe Longo ENI Drilling Eng. Joe.Longo@enipetroleum.com 907-865-3323 907-947-4323 Eni representative Bernie Leas ENI 1Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 ' Eni representative Greg Parker ENI Expediter Greg.Parker@enipetroleum.com 907-980-7545 Eni representative Michael Seward ENI Project Advisor 907-865-3337 907-952-7880 Eni representative ,Jack Potter ENI HSE Jack.Potter @enipetroleum.com ,907-685-1227 Last Casing seat Cas.Type OD(in) L-_ ID(in) Grade Top(RKB) Bottom(RKB) Run Date CASING 95/8 8.681 L-80 -0.8. 5,510.07/26/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) I P(Surf)(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 5,510.0 3,616.57 OBMM(VersaPro) 8.90 I 622.0 1 12.21 2,294.1 Eni E&P Division Well Name: OP12-01 ENI Petroleum Daily Report Well Code: 23972 • CO. Inc. Field Name: Nikaitchuq n Date:8/6/2010 - Report#: 24 API/UWI: 500292342600 E'�II Wellbore name: OP12-01 page 1 of 1 ` I xiY Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM I 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig Information Contractor Rig Name I 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) 0P12-01 DRILLING 7/16/2010 12,709.9 1 3,633.2 12,738.00 158.63 80.3 21.33 _ Daily information Depth End(ftKB) Depth End(TVD)(...IDepth Progress(ft) Drilling Hours(hrs) IAverage ROP(ft/hr) POB (Temperature(CF) Weather Wind 12,860.0 0.00 1 91.0 36.1 Cloudy,Light Fog, 21°NNE @ 19.1 WC 25.7° mph Daily summary operation 24h Summary Test BOPE,UD D/P,P/U 27 JTS HWDP&rack in derrick for liner run.R/U liner running equipment,PJSM&begin liner run. Operation at 07.00 Running liner 24h Forecast Complete running liner&set packer. Rig down running equipment,begin laying down drill pipe. Lithology Shows I MAASP Pressure(psi) Mud Weight(Ib/gal) 8.85 ■ Time Log Cum I Start End his Dur �9 Time Time (link) (lire) j Phase Opr. Act. Plan ;L, Oper.Dew. 00:00 07:30 7.50 7.50 DRILL E 12 P Test BOPE.Replace dart valve,test lines,body&install wear ring. ir- ------ - ip---- - --- _... _ 07:30 09:30 2.00 9.50 DRILL E 20 P L/D Drill pipe,P/U 27 JTS 5 HWDP drill pipe for liner run&rack in derrick. /e b 09:30 11:00 1.50 11.00 DRILL E 20 P R/U liner running equipment,GBR tongs slips&elevators. 11:00 11:30 0.50 11.50 DRILL E 1 P Hold PJSM for liner run W/all personnel 11:30 22:00 10.50 22.00 DRILL E 4 P M/U silver bullet shoe,run 5.5 slotted liner W/spiral gliders on every JT. 22:00 23:00 1.00 23.00 DRILL E 4 P P/U seal bore,hanger&packer.Add palmix. 23:00 00:00 1.00 24.00 DRILL E 4 P Run liner In on D/P to 8,600'up weight 140K down weight 50K ROT weight 85K TO 8K @ 15 RPM 2.5 BPM 50 PSI Daily Contacts Position Contact Name Company Title E•mall Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp©enipetroleum.com 907-670-8623 907-841-8759 Eni representative Satch Bowe ENI Drilling Spvr. '907-670-8623 907-299-0531 Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative Jack Potter ENI HSE Jack.Potter©enipetroleum.com '.907-685-1227 Last Casing seat Cas.Type OD(In) I ID(In) Grade Top(ftKB) I Bottom(M03) Run Date ∎LINER 51/2 4.892 L80 4,110.6 11,534.0 8/6/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) j P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,510.0 3,816.57 OBMM(VersaPro) 8.90 622.0 12.21 2,294.1 Eni E&P Division Well Name: OP12-01 Daily Report Well Code: 23972 ENI Petroleum Field Name: Nikaitchuq (� • Co. Inc. Date:8/7/2010 - Report#: 25 API/UWI: 500292342600 `?ml f page 1 of 1 Wellbore name: OP12-01 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM i 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig Information Contractor i Rig Name li 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) 0P12-01 DRILLING 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 22.33 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 12,860.0 0.00 91.0 37.9 Partly Cloudy,WC 61°ENE @ 25.9 26.1° mph Daily summary operation 24h Summary Make liner run to 11,534'M/D&set packer.Liner top @ 4112'M/D.Test-OK,bleed off pressure&release from packer POOH lavino down all nip&HW nP Operation at 07.00 Rigging up for completion run. 24h Forecast Continue to lay down drill pipe&HWDP.Rig up for running completion.Hold PJSM&run completion string. Llthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 Time Log i Cum Start End Dur ' Dur I Time Time (hrs) , Byre) I phase : Opr. Act Plan Oiler.Dew. — 00:00 06:00 I 6.00 6.00111 DRILL E 14 P RIH W/SLOTTED LINER F/8,913'-T/9,343'.ROTATE LINER DOWN F/9,343'-T/11,54T 30RPM 12K-18K-T/Q FILL EVERY 10 STDS,ENCOUNTERED BRIDGE @11,547'WORK LINER&CIRC.5 BPM 230 PSI 06:00 10:00 4.00 10.00 DRILL E 21 XPO4 WAITING ON DIRECTIVE ORDERS FROM TOWN-ENI.WORK LINER 11,547'M/D,PU WT-155K,S/O WT 45K,ROT WT-100K RPM-10 TQ12K-16.3K GPM 82 PSI 50 10:00 11:00 1.00 11.00 DRILL E 21 TP04 ATTEMPT TO POOH W/LINER RPM-33,TQ-15K-16.3K,P/U WT 225K,S/O WT 45K,ROT WT 110K.DECISION FROM TOWN TO SET LINER AS DEEP AS POSSIBLE. 11:00 13:00 2.00 13.00 DRILL E 4 P RUN LINER TO 11,534'M/D,DROP BALL&PUMP DOWN @ 2BPM &LAND OUT SAME,P/T 3,500 PSI,5/0 TO 45K, P/T 4,000 PSI,P/U TO 120K BLEED OFF,TEST PACKER TO 1,500 PSI FOR 15 MINUTES-OK.SHEAR&RELEASE TOOL.FINAL LINER DEPTH @ 11,534 M/D,TOP OF LINER @ 4,112 M/D 13:00 00:00 11.00 24.00 DRILL E 14 P PREP RIG FLOOR FOR LAYING DOWN D/P.POOH FROM 4,075'LAYING DOWN D/P&HWDP. Daily Contacts Position Contact Name Company I Title E-mail I Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative 'Satoh Bowe ENI Drilling Spvr. '907-670-8623 907-299-0531 Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Cos.Type —{ OD(in) ID(in) Grade Top(NCB) I Bottom(RKB) Run Date Last Casing seat LINER 51/2 4.89480 4,110.6 11,534.0 8/6/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(Ib/gal) I P(Surf)(psi) I Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 5,510.0 3,616.57 OBMM(VersaPro) 8.90 622.0 12.21 2,294.1 tipitiis Eni E&P Division Well Name: 0P12-01 EN!Petroleum Daily Report Well Code: 23972 • Field Name: Nikaitchuq �/�j�j nn Co. Inc. Date:8/8/2010 - Report#: 26 API/UWI: 500292342600 c?f1111 page 1 of I Wellbore name: OP12-01 Well Header Permit/Concession N Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM I 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig Information ---------- Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) 0P12-01 DRILLING 7/16/2010 12,709.9 3,633.2 12,738.00 158.63 80.3 23.33 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 12,860.0 0.00 86.0 37.9 Partly Cloudy,WC 61°ENE @ 25.9 26.1° mph Daily summary operation 24h Summary Finish laying down D/P&switch to completion mode. Operation at 07.00 Switched to completion AFE#4529 for remainder of well. 24h Forecast Begin rigging up Centrilift,GBR&Halliburton for completion run.Complete ESP installation rig down,freeze protect. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 Time Log Cum r Start End Dur Dur ' Time Time (hrs) (hrs) 1...Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 DRILL E 4 P CONTINUE TO LAY DOWN D/P&HWDP,LAY DOWN BAKER RUNNING TOOLS&PULL WEAR BUSHING.SWITCH TO COMPLETION AFE#4529 @ 05:00 Daily Contacts Position Contact Name Company I Title E-nall ( Office Mobile Eni representative Scott Beauchamp ENI 'Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative Satoh Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative 'Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative Greg Parker ENI 'Expediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative Jack Potter ENI iHSE Jack.Potter @enipetroleum.com ,907-685-1227 Last Casing seat Cas.Type OD(in) ID(in) Grade 60(RKB) Bottom(RKB) Run Data LINER 5 1/2 4.892 L80 4,110.6 11,534.0 8/6/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) I P(Surf)(psi) Eq.Mud Weight(1b/gal) Leak Off Pressure(psi) 5,510.0 3,616.57 OBMM(VersaPro) 8.90 622.0 12.21 2,294.1 ii Well Name: OP12-01 Eni E&P Division J Daily Report Well Code: 23972 ENI Petroleum Field Name: Nikaitchuq l'. i Co. Inc. Date:8/8/2010 - Report#: 1 API/UWI: 500292342600 ?l II Wellbore name: OP12-01 page l of l ,. _=-- Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210069 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA I NABORS 245 E 'LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB)ITarget Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) OP12-01 COMPLETION 1 24.00 Daily Information _ Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 86.0 36.1 Overcast,WC 24.8° 42°NE @ 22 mph Daily summary operation - 24h Summary SWITCH TO COMPLETION AFE#4529©05:00.RIG UP ALL CENTRILIFT EQUIPMENT,GBR TOOLS AND HALLIBURTON SLICK LINE UNIT.BEGIN RIH W/CENTRII IFT COMPLETION STRING AS PER ENI COMPLETION RUNNING PRO DURE Operation at 07.00 FINISHING COMPLETION RUN. 24h Forecast FINISH COMPLETION RUN,FREEZE PROTECT&BEGIN RIGGING DOWN CENTRILIFT,GBR&HALLIBURTON '.. Lithology Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) I 8.80 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act Plan Oper.Descr. 05:00 07:30 2.50 2.50 COMP K 5 P HOLD PJSM-RIG UP CENTRILIFT EUIPMENT&TOOLS,HANG SHEAVES IN DERRICK FOR ESP CABLE& I INJECTION LINE.PREP RIG FLOOR,STAGE GBR TOOLS FOR COMPLETION RUN. 07:30 10:00 2.50 5.00 COMP K 20 P PICK UP AND STAGE ALL CENTRILIFT EQUIPMENT&PUMP ASSEMBLY,PICK UP TTC CROSS-OVER SCREEN INTAKE,PUP JT.AND FULL TUBING JT.AND MAKE UP SAME IN HOLE,MAKE UP SEAL ASSEMBLIES,MOTOR, GAUGE HOUSING,AND SET IN MOUSE HOLE. 10:00 12:30 2.50 7.50 COMP K 20 -4P PJSM-RIG UP HALLIBURTON SLICK-LINE,RUN PACK-OFF INTO TTC RECEPTICLE,JAR DOWN ON SAME& SHEAR-OFF,POOH.MAKE UP TEST TOOL&RIH AND SET IN TTC RECEPTICLE,JAR DOWN&SHEAR-OFF OF SAME,POOH.RIG UP HEAD-PIN&TEST TO 1000/PSI WITH TEST PUMP,HOLD FOR 15 MINUTES ON CHART RECORDER-OK,BLEED OFF.RIH AND RETRIEVE TEST TOOL,POOH.RIH&RETRIEVE TEST TOOL,POOH,RIH WITH TUBING STOP&SET SAME,POOH&RIG DOWN HALLIBURTON.RELEASE HALLIBURTON SLICK-LINE.(ALL AS PER ENI COMPLETION PROCEDURE) 12:30 16:00 3.50 11.00 COMP K 20 P MAKE UP TTC,PUP JT,AND TUBING JT.TO SEAL SECTIONS&MOTOR ASSEMBLY,FILL WITH OIL&AIR-OUT SAME,CHECK PUMP ROTATION-OK,ETC.ALL AS PER ENI COMPLETION PROCEDURE. NOTE:HOLE FLUID LOSSES REMAIN AT 3.5 BPH. 16:00 19:00 3.00 14.00 COMP K 20 P PREP CENTRILIFT ESP CABLE&INJECTION LINE FOR INSTLLATION IN COMPLETION STRING. 19:00 21:30 2.50 16.50 COMP K 20 P ESP CABLE SPLICING,&INJECTION LINE SPLICE.TEST FOR CONDUCTIVITY-OK 21:30 00:00 2.50 19.00 COMP K 4 P RUN IN HOLE WITH ESP ASSEMBLY ON 4.5"L-80,#12.6 PPF.IBTM TUBING,MEGGER TESTING ESP CABLE EVERY 1000',RIH TO 1352'UP WT.55K DOWN WT.55K Daily Contacts Position r Contact Name Company Title E-mail Office Mobile Eni representative 1Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative ''Satoh Bowe ENI Drilling Spvr. 1907-670-8623 907-299-0531 Eni representative Joe Longo ENI iDrilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative Greg Parker ENI 'Expediter Greg.Parker©enipetroleum.com 907-980-7545 Eni representative Jack Potter ENI HSE Jack.Potter@enipetroleum.com Last Casing seat Cos.Type I OD(in) I ID(in) Grade Top(RKB) j B#1100-i(f ),; Run Date LINER 5 1/2, 4.892 L80 4,110.6 11,534.0 8/6/2010 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type /Fluid Density (Surf) ty P( rf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,510.0 3,616.57 OBMM(VersaPro) 1 8.90 j 622.0 12.21 j- - 2.294.1 If* Eni E&P Division Well Name: 0P12-01 Daily Report -- EN/Petroleum Well Code: 23972 Field Name: Nikaitchuq � • CO. Inc. Date:8/9/2010 - Report#: 2 API/UWI: 500292342600 °`11 11 fl page 1 of 1 Wellbore name: OP12-01 Well Header Permit/Concession N° Operator ENI Share(%) IWell Configuration type 210069 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 g Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date Target Depth(ftKB):'Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) OP12-01 COMPLETION I 25.00 Daily information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) 'Average ROP(ft/hr) POB Temperature(°F) Weather Wind 84.0 36.9 Overcast,Rain,Fog, 54°NE 2 22.9 mph WC 25.5° Daily summary operation 24h Summary FINISH COMPLETION RUN.PER ENI COMPLETION WELL PLAN.N/D BOPE.NU TREE&TREE VALVES.TEST TO 5,000PSI FOR 10 MIN.FREEZE PROTECT W/LITTLE RED SERVICES PER COMPLETION PROGRAM. Operation at 07.00 PREP FOR RIG MOVE 2411 Forecast FINISH FREEZE PROTECT.RIG DOWN PUMPING EQUIPMENT.PREP FOR RIG MOVE Lithology - — -_---- Shows -- ------_- MAASP Pressure(psi) Mud Weight(lb/gal) . 8.80 Time Log Cum Start End Dur Dur i Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00 COMP K 19 P RIH W/4.5"12.6#L-80 TBG.F/1,352'T/3,847'W/CANNON CLAMPS EVERY OTHER JT.CONTINUITY TEST EVERY I---. - 1,000'. 04:00 08:00 4.00 8.00 COMP K 19 P M/U 2 4.5"VIT JTS.&XO RIH TO 3,949'M/U HANGER INSTALL PENETRATOR,MAKE ESP SPLICE CUT&CAP CONTROL LINE INTO HANGER.LAND HANGER,85K UP WT.73K DN.WT.@ 08:00 08:00 15:30 7.50 15.50 COMP K 20 :P RUN IN LOCK DOWNS,TEST UPPER&LOWER HANGER SEALS,5,000 PSI.FOR 10 MIN.LAY DOWN LANDING JT. INSTALL TWC VALVE,N/D CHOKE,KILL LINE.N/D BELL NIPPLE,FLOW LINE&STACK. 15:30 19:30 4.00 19.50 COMP K 5 P CLEAN&PREP WELLHEAD FOR TREE.N/U TREE&TREE VALVES TEST HANGER VOID TO 5,000 PSI FOR 10 MIN.TEST TREE TO 5,000 PSI FOR 10 MIN.RECORD ON CHART.PULL TWC W/LUBRICATOR. 19:30 00:00 4.50 24.00 COMP K 9 P - - R/U TO FREEZE PROTECT WELL.PJSM W/ALL INVOLVED.LRS TEST LINES TO 2,000 PSI.PUMP 25 BBLS DIESEL TO FILL UP I.A.&TUBING.PUMP TOTAL OF 304 BBLS DIESEL DOWN I.A.TAKING RETURNS UP THROUGH TUBING @ 1-2 BPM MAX PUMP RATE&400 PSI MAX PRESSURE.DISPLACE BRINE OUT OF WELL DOWN TO BTM.OF PUMP INTAKE @3981'TOTAL OF 6 BBLS DIESEL RETURNED TO SURFACE THROUGH TUBING. Daily Contacts Position I Contact Name Company Title Smell 1 Office Mobile Eni representative :Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com ,907-670-8623 907-841-8759 Eni representative 'Satoh Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 Eni representative Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com :907-865-3323 907-947-4323 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Enl representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com Last Casing seat pas.Type OD(In) IF ID(In) Grade Top(RKB) F Bottom(ftKB) _ Run Data LINER 5 1/21 4.892 L80 4,110.6!- ,110 6 11 534.0 8/6/2010 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) 5,510.0 3,616.57 OBMM(VersaPro) 1 8.90 822.0 12.21 2,294.1 i Eni E&P Division Well Name: oP12-01 If* ENI Petroleum Daily Report Well Code: 23972 Field Name: Nikaitchuq �j •n Co. Inc. Date:8/10/2010 - Report#: 3 API/UWI: 500292342600 lC n fi Wellbore name: OP12-01 page 1 of 1 Well Header Permit/Concession N° Operator i ENI Share(%) Well Configuration type 210069 'I__ENI PETROLEUM i 100.00 ',HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 54.58 12.20 0.00 Rig Information Contractor I Rig Name !Rig Type NABORS ALASKA NABORS 245 E jLAND 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) OP12-01 COMPLETION 26.00 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(bra) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 84.0 36.9 Overcast,Rain,Fog, 54°NE 2 22.9 mph WC 25.5° Daily summary operation 24h Summary COMPLETE N/D OF BOP&N/U WELL HEAD.LUBRICATE IN BPV RELEASE RIG • Operation at 07.00 RIG RELEASED.SEE OP05-06 DDR 24h Forecast CLEANING PITS,RIG DOWN LINES&INTER CONNECTS FOR MOVE TO OP05-06. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 Time Log I Cum Start End Dur Dur Time Time (hrs) (hrs) I Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 I 3.00 3.001COMP K 9 P RIG DOWN LRS PUMP SERVICE&CHOKE LINES. LUBRICATE IN BPV&RELEASE RIG. Daily Contacts Position I Contact Name Company I Title Email I Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative ISatch Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 Eni representative 'Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Eni representative Tom Norvig ENI Rig Clerk Tom.Norvig @enipetroleum.com 907-670-8607 907-229-6100 Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907-980-7545 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com Last Casing seat Cas.Type OD(In) 1 ID(In) Grade Top(ftKB) 1 B ottom QtKB) Run Date LINER 51/2 4.892 L80 4,110.6 11,534.0 8/6/2010 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) 'Eq.Mud Weight(lb/gal) 1 Leak Off Pressure(psi) 5,510.0 3,616.57 OBMM(VersaPro) I 8.90 622.0 12.21 I 2,294.1 y8 8$4;;.1 N MN MNQ gy 8:2z;,2& ,7; 8 2 r m W V a3 24-8;2 OMO NOE 0 N° OM NNOQ �O O 6 N^EMO ON 0 DNM 0 NO 2EE,2 2222 2 28�°2 2822 M7328.7 QQQQQ 4'Q4MD W 7 IS, EEEEE OEEEE 2EEE2 EEEEE EEEEE EEEEE EEEEE O222 40040 04000) O>0440 000)04 04004 40404 44440 0)0700)0 u QQQQQ QQQQQ QQQQQ aQQQQ QQQQQ QQQQQ QQQQQ QQQQQ 40.2r0-,12z,3 °o,1 2 z 3 gO :: , 88:2'48:2'422 V 2 P.;A h' 1 0 0 ) 24828 0 0 r.2.7.212 C 0 p 0000 N N N M M'i O N t0 000 0 )O N) 0 W q 0 0 0 0 O O O 0 O O O N O O O O O 000O ,', ,N N M M M Q 00 0 0 0 J 00 Nt00 N NNNN 00000 N 00 N t0 00 t00h 100000 0)00)00) 00,000 00000 0 0 0 0 0 00000 O 0 0 O N 00000 N O O 0 0 00000 r r°r r 0 N^N r Q 0 o 7.".72g2 r,:24'018 M Q 0 N M0 2 0 0 2:2228 I�0 r M 0 0 OOr M0 0 W▪�EEEEE EEEEE EEEEE 00STS STEEE 2222E EEEE2 ETEEA 0.... .0.0. 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UMmm0 MOM,. NNnO, rUMON NmNm0 2mM m mdNMN 4N Nm E2200 88W E 18224' V da W N 2in2 ,P.922,12572 0000 °MNO '412 —woo mmmmm mmmmm mmmmm mmmmm 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 2 2 2 2 mmm00 mmmmm mmmmm mmmmm mmmmm mmmmm mmmmm 0 0 0 0 0 00000 00000 00000 44444 d d d d 4 44044 4 d 4 d d 44.140 d d 4 d 4 44440 Q 0 0 Q 8 04000' Q l e Q Q 44444 4 e 4 Q e '4' 2,84 9 J q O 8 84028 Q N m 2! U)N VN N Nd n 8824'2 d 2 5 O N N,1 r 8484'2 0 N m N d N 1 2 42822 M f0 p N M N d N c,°, 418,8 N N N N m 2 N p"N N N Y O N 2 O d 2NM m 8 8 2Un 0 2R W 28 N 8 24 N N O N M N M M N 2 m Q 8 2. 2 N N M N.n n m m N N 82N N 2 N 220 0 N N M 8 N n N n m m 2222. N N N N N N NN N N N NN N N N N N N N NNN N N NN N N N NNN N N NNN N N NNN N N NNN N N NNN N 00000 o v 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 C? 22'482 N8270 22rr7 24'1201 M 242Zr Man OCm002 i[V 282 7,4'221 81,2R.7 2MONr NntO v4' OrNMN N Q d d CN NONmr 820NCC 00N00 tli MO V Nm U)CC0 V N 01N 0MON V NN000 NNm O Oni MNC NN 0D NO 00 M r n C- N N m m M N r N m e N 2 2 N m 2 N 2,p O 0 n n 0 0 0 0 N N W V N e 1 d 1 M MNN ON,) N M O O m m m m m m r n r 2 2 2 N N N Q Q Q M M M N N ��N M M M M M M M M M M M M MNN N N NNN N N NNN N N NNN N N NNN N N N N N c9-400 NNNN N N NNN N .000. N NNN N 00.00 N NNN N 00... N NNN N 0.... N NNN N 0.... N NNN N Zrp a Nm Om r0 m N 0 m 7 0 m 8m 2m Mm N0 m 1 0 m O0 m O0 m MO 0 m 888P"' Nm Om Om dm;0 m V Vm 2<m 8 Q m mm O h m mm Mm Mm N0 m A 0 m 8tm Nm"m'Mm N m 22128 2128 ,1 2 8 '' N A.7,882 m 8 2 M N 2 8 R :ER 6.6666 W 0 N O m O O)N O N O m A N O O N N N M N 2.N D 10 0 8 8 2 N D m N N M M M O N N M N 21 2 0 8 88 888 88 8 0 8 y 0 8 80 0 8 8 8 8 O O O O O O O O N N N N NN N N 2.N Q2 N NNN N N NNN N m m m 0 0 N 0N 2 2 m m m m m .00.. N 8 r m 6 6 18822 m m N N N 2V:222 M M d d N M N N M M N N d d O O M M O O 22884 7 N N N N 22822 r r m N m D o 6,6666 G N N O O O O M M N NMM W 244'27, 828081 2:OO82 8728O8 22074' 4224'10 01:228N rN002 N W NN00 22N22 4'92ON2 2rm00 N N ON M N 2M" 1MM2 d m N'7'7 2m m 13 O r 4 nOan "g" ONON ON r M O‘r= 2 00 V ( 28 T . T7 PM m M n m m O O O N M M 44 d d m m m e m m m m v gNU)v1 v1 N 7'42.78 M M 7 2 8 '4888E, N NN2 P42°4-0 M 7,N 2 10 2 m n m N 8'8,=-8'4 2 1 M M M 'M m M Q .T824-'2 2 N N n N m4n Nm n O 0 O N MNN n N M n 0 N 0 W 2 N r N/0M ' N "1" M NN N m N O 001000 "1"°i N <9;442 28777, NN222 2.1122 0 N (0010 88822 220 60 00000 E y 42°4-24 M<2 0 M M d N 2 88:422 8 10 2 2 V 2 V d 2 N<N 2 44182:= 7 r 2.(1 478;22 N O N7O8 A2 8P; ,00O 000V00 N V N0 O N20U 02020 NV UM Q{ 0 M{ M2 M{ N ONO, NCtO ( N M2 W Wr 0 0 O NON. 3 N NNN V 3 0 N N N N NNN N 2. 882. 18220 QO 222 8 2 8 82 2 0 00 7.7-PPP P r r r r N N r r m m m m"Om 0 4 4 2 E 21881 1 0 0 0Q m 0n n N 2 ONi N n�2 N N Q 0 Q n Q m 2.7.7 NW 7 W N N 2 m e e M 2N O 2 N M m N m M Qm N O m MN N O O O 4 O t8 2.0 4m0 = N m N V N gmgc.ig NW ONOo uNiv 2AA 222R2 88R2R 2(008,12 22R2,1 A2222 88222 200077 Prnn.A. °nNNNN rrnn22 mOn18021 0 O EE mPNNO 821,18 NmNne P8218 2:2222 28822 V 2128 271 2.8 28?88 28n2e N.2722 822R; d 0 0 [ 0 m N m O m 2mNm m m m m O m g m d 8 8 2 2 0 2 0 m2 m 2 u N W g<g W Ng N N 12 2 2 2 i g y2 2 2 8 8 2 2 22882 2 2 0 2 2 aO 0 0 0 22 882 2 2 2 00 n n PN M N n N N N N n O O pp� 2 2 2 8,1 2:=7,88 88182 018,928 8N 2N 1M 0M 1 2 A 2 2 Q 87.R'42 2 8 1 1 7 8;2121 2 2 W N N :P I LT N 8,8282 d N N N m N NMM M M M M d N N NNN N N M M<O <V<V O m Lt N W W N N N N N N NNN N W N O V O e MMMMM MMMMM MMMMM 22222 MMMMM MMMMM 222M ,12222 MMMMM M2222 MMMMM gd m E 12228 O m N N N r n M m N 4'4822 M 2 1 2 n R27-27, 10 n pM M 2�2 M e m 88188 N O 2 n n 22728 g >“ 00202 2222°' CANOE nn�NN mWW28 wOgg§g g1t81gM mmmmm Finn mrn rnm0m 28828 MMMMM MN'lMM MMMMM MMNMN MMMMM MMMMM MMMMM 222(2.+12 222(202 212.+(222 MMMMM MMMMM 2` ~E 0C-CNN R8821, 2 N N2 2 N 4'4422 02 8 8 2 2 N 2 d 2 ?4:728 DN N m2 A'4428 2n O NN� 7,1,188 x-7,1,188 0N0n NNN N -02N 6NNNN roNvi V M t� �)thNN NNMMM Ndd dd 88MN M NNM M NNM M M 0 MMMM M M MMM M M MMM M M MMM M M MMM M M MMM M M M M M M M MMM M M MMM M M MMM M Q {L a 82228 100 21 821°4-2 8R8 4P 08208 8, 2R8 :828 '.28,7R2 O V 222 12287 8M V r0 82208 0 0 m N N 88222 m mmm m 22222 m m m r m 28882 m m m m m 22222 m mmm O 22228 N N mm Q 82228 O" 212:22 0 O N 0" 24'222 O tN p 8 0 O 8 0 0 N 22828 2 0 1 O 4 8 r 0 8 0 N 8 d 8)0 0 8 0 2 0 g'4888 O 8 2 0 m 88828 08000 00200 000 V O 20N0M OMONO NONO.- O.-OOO O0O p OOO20r OrO N r M e r N N 2 2 r r 2 m m r 0 0 0 0 N N M M d 0)2 0 2 2 8 8 2 2 2 2 00m m 822 0 1 0 0 0 2 2 2 8 8 2 2 8800 c ° d p E E O 0 -Sr V NNOn)T 4'8212 8, 24 Olp,mr E2 mOO 2EIOmO 4O mO N1N MmN NOO 2EmM —00m; N NNN 2 2,77.'z88 O N Q E N Q 2 rn O m C �Op AND��p t0 p r 2228 081800 0000 V ONNNN MCN'1M Ie")O V V O2N NNm10fN0 fOrrrN 1.88883 ;i82O O p 0 0 0 0> 88888 8 8 8 8; 00.00 0 0 0 0 0 00,0100 0 0 0,0 0 00)00(0) 00,000 00000) 0000)8 8 rn rn m rn aaaaa apaaa 4'4444' aaaaO aaaap aaaaa ,74'444- aaaaa aaaaa ppapa aaaaa QQaQQ eeQeQ eQQee Qeeee eeeQe eeQQQ QQQQQ QQQQe eQeeQ QQOQQ QQQQQ {p y� {p� app (p� (p� 44= ONQO2 288 W 1pmrON HH l7rn1(1 pip>n N1MO IOGONR° rO 2 O O N N <V I�p ODD 0 0 0 N N 2 N IO r T 4;2 2 M O N N N M iO Q 3 Q 2 8 8 2 2 O O O O O��'-�- N N N N N M MMM M NNN OOOIMO0 NON. 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N 2 2 N 2 ..... 2 2 N N N 2 2 2 2 2 N N 2 N 2 2 2 M 2 2 N N 2 2 N N N N N 2 2 NNN N N NNN N N 38, Y Z E O"y 432 rn 2 0 8 8 2 0.128 0 884 O M 0 M M 0 m:2882 2 2 2 2 N-2 23287 0 0 0 N0 0 0 7 2'288:2 o Q8 828'O o e rn 8288 8 08NO 0140ON 88 N, W N-M 20,N00 N N 0M M M 10 8882; 88222 gA N NN001 0OO NNMV MQ 2028N n M M M M M M M M M M CNM MMOMM QQ QQ00 00000 00° gQ Q 80880 mmmmm mmmmm 00000 mmmmm mmmmm 80088 mmmmm mmmom 80000 00000 0 N. 22233 8 2 2 2 2 28288, m M 2 e 8 822:::: 2 2 rn 8 N 22848 8 2 2 8 8 44828 2 2 2 8 8 33228 8 0. 000014 1414000 OOO8 M NN OO.- T-N-NNM O 84 232 88888 8288:7 58288 388;7; 88822 :22888 882142048 ;2287 88228 9 2 22"2 28'78 2000(0 C $0 mmNm 0NMM EN 00 �� 80 2Nmm N 2 NM �EEE0 ;?21D2 ? (9,944O 02 102031Im0 CO m 82242 O O m 2 N 828::8 CO r 2 Q 48882 2 M N M.- 8:222; .O 2 M 2 28283 N 2:2 M m 82888 N 0 n O V O C 28M 0 2 2Q M N N m N. 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N V V a V V V AP" M O M N 8 0 O ✓ ;8222 33 . 2.222 028 mmmmm 2 Qrn 888.0, 228 08820 . 888 88.88 0 4 4 0 O Q 88828 NN_Nrn N N 2 Q 14 N 28:288 8 8 8 2 rn 82822 N 8 N 8 2 28828 88882 N 2 M 8 Q 2 Q 28885 n 88;24 a O N 0 N 0 0-N a m r .‘,2o22 N m2 2 2 2 m m W O 8 2 2E 2 2 2 0A 0, 8 2 2 2 2 8 14 2 22 88e 88 0,0,8 8 8 00N 0M 3e 8 8 002 8 8 ° 0 3 SE 8,8228 M N 2 8 2838.9- 2,1'828 43287 2 2 rn2 N 82284 O m0O rn 3822; 8 N 2 Q O MO 0�2 2 8 :7:222; 8 M M O N O F2Tr.4V O V 0 a 8 N 8,4248N W 41, 2424,7 pis.* ; 2 0 8Q 8 2 8 mmmmm 21812 28228 02228 mmmmm mmmV 0 mm4 2 2p228 00020 Mp000 88880 0 2 0e 8 0Q 8 8M 8 8 383,, m 22888 0 8 8 8 82888 N 8 E 8 8 888:2r,: 2 8 2 2 2 8782.°2 88 8 8 8 88828 828,28 8 M8 OM mM MM NO22.o148042 N MM M M M 22222 2 2 2 2 2 M M M p mi goi M y 2 22222 2222 2 2 222 *H A 2 2222 M m E rn E 32:288 8 8 8 2 2 8,71:2:22 8 C8 8 2 2 2288:2 2 2 8 8 2 :248°.28 8 2 8 2 2 28242 88258 22',Z88 2 d 22822 8588 mmmmm mmmm °22222 mmm OEmm8 mmmmm 08888 22882 20,90 mmmmm 822or p rn 2 2 2 2 2 22222 (00)0)0(0 0(0(0(0(0 2 2 M m m 88802 0)0)0)0)0) 28228 2 8 M M M MMMMM MMMMM MMMMM MMMMM MMMMM MMMMM MMMMM MMMMM MMMMM MMMMM M d 2 e ,72828 3282; N M m 2 4 288:28 8 N N 2 8 8888:2 m 2 rn E O 288,38 O8 2 2 8 82822 0 8 2 8 2 2 a O U E N N N M '00)2 N CO NNNNN N N N 2 n O)O)N N N NNNN CO N N N N E 8 8 8 8 N NN M MMM M M MMM M M MMM M M MMM M M MMM M M MMM M M MMM M M MMM M 8 M M NMMM M N N N 8 8 8 r 0 MM;;;;;; CO O 0 Q 2 m 0 1".= 88828 :0::0:: 8 0O ::0:r: N r::0:: O :::r: ::::rN Q : 1: 8888 mmm 82 o m O rn O 88828 882000N8O V 482 8M 828 g 8N 8,0 8"88 0808088m 02 0202 0 , 828 R O N N M m Q Q 2 2 8 0 0 0 0 0 O O O O VV''' '''N' N NN N N NN O▪ ON pD p � E A O E F w a E m m E U . 0 O 0 0 2 N CD r k r Es 0 z |. !£ t \/\J ! 0000 � 2kVq (&: ° §!K§ !\k §£ ! �� _)• / )§} S. 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This is granted under 20 AAC 25.035 (h)(2)which grants a variance based on past drilling experience and a geological review of the area. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Quay Walter [mailto:Walter.Quay©enipetroleum.com] Sent: Tuesday, June 29, 2010 2:26 PM To: Schwartz, Guy L (DOA) Subject: OP12-01 and OP05-06 Clarifications Guy, As per our conversation, please clarify and confirm that the approved Diverter Waiver for Nabors Rig 245e drilling on Oliktok Point applies to the wells, OP12-01 and OP05-06. These permits were submitted before the approved diverter waiver was received at ENI, therefore reference is made to the diverter rig up. The reference diverter waiver letter, AOGCC to Maurizio Grandi, June 11, 2010 is attached. Walter Quay Drilling Superintendent Walter.Quay @enipetroleum.com Office: 907-865-3324 Cell: 907-230-3961 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. s7. 01E oT ARA / SE AN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMbIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Maurizo Grandi Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Undefined Oil Pool, OP12-01 ENI US Operating Co. Inc. Permit No: 210-069 Surface Location: 3182' FSL, 1604' FEL, S5, T13N, R9E, UM Bottomhole Location: 711'FSL, 3255'FEL, S30, T14N, R9E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. ENI US Operating Co. Inc. assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, a Daniel T. Seamount, Jr. Chair DATED this? day of June, 2010. cc: Department of Fish 8; Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ALA A OIL AND GSTATE OF AS CONSERVATION COMM. .ON RECEIVED PERMIT TO DRILL JUN 0 7010 20 AAC 25.005 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil 112 • Service- Winj ❑ Single Zone 11 � S e 'fy if well is proposed for: Drill 0• Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone kg Ll s � ►s n❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ AfCh rap hale Gas ❑ 2.Operator Name: 5. Bond: Blanket p Single Well ❑ 11.Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627 • OP12-01 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 12712' • TVD: 3668'• Nikaitchuq - 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3182'FSL,1604'FEL,S5 T13N R9E UM ADL 355024,373301,390616,391283 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 635'FSL, 3435'FEL,S32 T14N R9E UM ADL 417493 7/22/2010 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 711'FSL,3255'FEL,S30 T14N R9E UM • 1280 635'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 53.2 feet 15.Distance to Nearest Well Open Surface:x- 516676 • y- 6036536 . Zone- 4 GL Elevation above MSL: . 12 feet to Same Pool: 1291'West to OP-12 16.Deviated wells: Kickoff depth: 300 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90° degrees Downhole: 1614 psig - Surface: 1210 psig • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade _ Coupling Length MD ND MD ND (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 2430 • 2173 • 436 sx 10.7#ASL,222 sx 12.0#Deeperete 12.25" 9-5/8" 47 L-80 BTCM 8455 33 33 5330 • 3582• 329 sx 12.5#Deeperete 8.5" 5.5" 17 L-80 DWC 7582 5130 3567 12712 • 3669 • 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 ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD TVD - Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat 0 BOP Sketch El Drilling Program IN Time v.Depth Plot ❑ Shallow Hazard Analysis El Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Jason Brink @ 907-865-3321 Printed Name Maunzio�Grandi Title Well Operation Project Manager Signature /1 /} C l M't Phone Date �j (1 (to, �Y Commission Use Only I Permit to Drill - API Number: 7�y `L Permit Appro � i See cover letter for other Number: ,_/C'. ? 50-02-Y-. 23 T 4o -4,-66 Date: t Al ali ip )'� 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: B Other: 4 3500 ,O SG /'D e r e S f Samples req'd: Yes❑ No Mud log req'd: Yes ❑ No [v]' t^' / f 6%2.1 H2S measures: Yes❑ No[f Directional svy req'd: Yes El"No ❑ - 'Z,5D0 ,oSL AhrlwLA. ( -7 I / APPROVED BY THE COMMISSION _ �/ DATE: ,COMMISSIONER ORIGI-NA ,,, 6/6/0 Y vois • Enil _eat_ 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi @enipetroleum.com June 3,2010 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer OP12-01 Dear Commissioners, ENI US Operating Co.Inc.hereby applies for a Permit to Drill for the onshore production well OP12-01. The well will be drilled and completed using Nabors rig 245E. The planned spud date is 7/22/2010. 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, o 1 Maurizio Grandi Well Operation Project Manager root Oliktok Point Nikaitchuq Field•enn peVoleum OP12-01 (P3) Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle F X-65 0° 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res -'+ Surface Csa Dir v 13-3/8" Base Permafrost 1,900' 1,778' > 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor r- L-80,BTC 8.8-9.5 Lost Circulation Hole Cleaning KOP:300' DLS: 1.5-3.5 deg/100' Hole Angle 48 13-3/8"Casing Point 2,430' 2,173' 16" 50°F WBM GR/RES PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 47 lbs/ft MW(ppg) Hole Cleaning L-80,BTC-M 8.8-9.5 Torque&Drag Sail Angles: 51 degrees "N"Sand Top 4,625' 3,433' ta TOL 5,130' Hole Angle 88 9-5/8"Casing Point 5,330' 3,582' 12-1/4" 85"F LSND GR/RES Periscope/PWD Wellbore Stability Neutron/Density Lost Circulation Schrader Bluff Slotted Liner Hole Cleaning Lateral 5-1/2" Torque&Drag 17 lbs/ft MW(ppg) Xceed 675 L-80,DWC 8.8-9.0 (Geo-Steering) 5-1/2"Slotted Liner Hole Angle - 89 TD/5.1/2"Lnr 12,712' 3,669' 8-1/2" 85"F MOBM • Enii ,tiroHurn Application for Permit to Drill Well OP12-01 Saved:3-Jun-10 Application for Permit to Drill Document Producer Well OP12-01 Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Please see Attachment 7: Surface Platt 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 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 (Ml VersaPro LS Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 10.Seismic Analysis 6 Requirements of 20 AAC 25.005(c)(10) 6 11.Seabed Condition Analysis 6 OP12-01 PERMIT Document.doc Page 1 of 7 Printed:3-Jun-10 eau foot' Enli ' tir II iii Application for Permit to Drill Well OP12-01 Saved:3-Jun-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(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: OP12-01 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; Location at Surface 3182' FSL, 1604'FEL, S5 T13N R9E UM • ASP Zone 4 NAD 27 Coordinates RKB Elevation 53.2'AMSL Northings 6,036,535.64 Eastings: 516,675.72'. Pad Elevation 12'AMSL • Location at Top of Productive Interval 635' FSL, 3435'FEL, S32 T14N R9E UM ("OA"Sand) OP12-01 PERMIT Document.doc Page 2 of 7 Printed:3-Jun-10 f11•■■ ent Enil tiroIIeuiim Application for Permit to Drill Well OP12-01 Saved:3-Jun-10 ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 5,300' Northings: 6,039,262.85' Eastings:514,831.23' Total Vertical Depth, RKB: 3,580' Total Vertical Depth, 55: 3,528' Location at Total Depth 711' FSL, 3255'FEL, S30 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12712' Northings: 6,044,611.00' Eastings: 509,703.00' Total Vertical Depth, RKB: 3,668' Total Vertical Depth, 55: 3,616' Please see Attachment 7: Surface Platt and (D)other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 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 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 1,210 psi: MPSP = (3,668 ft TVD)(0.44 - 0.11 psi/ft) = 1,210 psi t (B)data on potential gas zones; OP12-01 PERMIT Document.doc Page 3 of 7 Printed:3-Jun-10 tot Enii 6) (1 roll um (7, 111 !. Application for Permit to Drill Well OP12-01 Saved:3-Jun-10 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( Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 178.89 X-65 Welded 120 36/ 36 1207 120' Cemented to surface Cemented to Surface with 436 sx 10.7#ASLite Lead • Yield 4.52 cu. Ft./sk, 13-3/8 16 68 L-80 BTC 2430' 35/ 35 2430'/ 2173' 222 sx 12.0#DeepCRETE Tail Yield 1.58 cu.ft./sk Cement Top planned @ 4125'MD Cemented w/329 sx 12.5# 9-5/8 12-1/4 47 L-80 BTCM 5330' 33/ 33 5330'/ 3582' Yield 1.54 C Cu.E ft./sk 8-1/2"OA 5-1/2 Sand 17 L-80 DWC 7582' 5130'/ 3567' 127127 3669' 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 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please see Attachment 3: BOP and Diverter Configuration OP12-01 PERMIT Document.doc Page 4 of 7 Printed:3-Jun-10 ft*kni Enii I° 1tiroHeur Application for Permit to Drill Well OP12-01 Saved:3-Jun-10 V 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 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program(extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) 8.8 9.2 9.2 9.5 • Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/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 (CP) (seconds) 45 - 60 Yield Point Plastic Viscostiy (lb/100 sf) 15-20 (CP) 12 - 18 HTHP Fluid loss Yield Point 18-24 (ml/30 min @ <5.0 (lb/100 sf) 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 MC 25.0330; OP12-01 PERMIT Document.doc Page 5 of 7 Printed:3-Jun-10 eniEnhi E_ ni trolleum Application for Permit to Drill Well OP12-01 Saved:3-Jun-10 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 MC 25.061(b); Not applicable: Application is not for an offshore well. 12.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 MC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 13.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Dull 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. 9. Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 10. Install 9-5/8"casing rams in the BOP and test to 3500 PSI. I 11. Run and cement 9-5/8", 47# L80, BTC Mod casing. Pump cement and displace with mud, land casing I hanger and bump plug. OP12-01 PERMIT Document.doc Page 6 of 7 Printed:3-Jun-10 • Enil Application for Permit to Drill Well OP12-01 Saved:3-Jun-10 • 12. Install 9-5/8"packoff and test to 5000 psi. 13. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 14. Pressure test casing to 3000 psi per AOGCC regulations. Record results. . • 15. PU 8-1/2"bit and directional drilling assembly including MWD, LWD; PWD and rotary steerable tool. RIH,• clean out cement to top of float equipment. 16. 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. 17. Directionally drill 8-1/2" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 18. PU and run 5-1/2"slotted liner to TD. . '�-r--� Pik ,+ 4 sr( Li) ac,f' 19. Land liner, set liner hanger with 200'Liner lap inside the 9-5/8" intermediate casing. POOH laying down DP as required. 20. PU ESP completion as required and RIH to depth. Land tubing. Set BPV 21. Nipple down BOP, nipple up tree and test. Pull BPV. 22. Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 23. 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 OP12-01 PERMIT Document.doc Page 7 of 7 Printed:3-Jun-10 m 0 O^ r N NA NA N m z7,1°,222 nn m0 pp 2n^N.- Z,)22:12 Q SRb,z O N n O n 2W N i M ZC n nrAn b 2 b b b n ffO N A M N^m r N N N m m<N T 6 8 N N N y 8 R22;;2 N b O W N b b 222 b 2 22 2 2 2 2 2 2 N 2 116'22 D M fN N 0 b b 2 b 22 2 d ..„,0,0. 2 2 2 2 2 2,0 2 2 2 ,00000 2 2 2 2 2 400404010 100401010 .000 2 Q Oly d dd O X00 b r dR b m;f7m f7d Add ONNO W 2,04.'4 C= b b 2 b r 2:271:18 d�O f'1 N b 2 N d d d m fr1 0 r OJ N o r O O�.2 m Y S "" "ERE N1NDn NOn r NlN�O ililm PPM N2y�N ENO O 2 y 2 y 2 2 2 40 2 b 2 2 r A n t 0 t 0 t 0 m m m 0 0 0�� N N 2 f 7 ^N f h O b b b b fD 1p f0 b 2 ;IEEE b 2 fbp 2 2 b f0 f0 f0 2 b 2 r n A A r r r A r r b W z f+l 2 fh y M 2 2 t7 M N y y(7 fh f7 2 2 2 2 2 2�f7�M f'1 N y 2 M m M 2 p Op O O O O O O N O O O O O O O O O O O O O O O O O O O O O 8 0 0 b fO b b b b 2 2 b b b 2 2 2 b b b b 2 b b b b m 2 b b b b b b l N W N E t Egd mm m NaU 80282 rnomoo mg$�m P-2 8D hnm S Q c'mm 0�0 -,o0 m N'd' mN N N N N N N N Nfpry2 °,7828 2;7.17:1'4 p Q 0 O b t u N W O N ii N l o1 d N m_T m Q Q Q Q Q Q 0 0 0 C Q W 74 : 88882 m O.7 p f n c‘= 222'42 A m m 2 d 'm N b. b n ' h N 286V,12 b N 2 «C o 0 00 0 -NNN N 7 N M 7 h 7 e h on d d d a d n n.g p d d d p d d 8 2 2. mi o o E O J Y a Z p 0 8 N N NNN N N p NN N N NNN N N Np p N N N p N p p p N N pp 8 E 08 0 0 0 N N N N N t M f.j M W f 7 f.j M f 7 O O 00000 O O f.j M MM,MM QOM CID r FM �� 2222 22222 22222 22222 ND.'o:�2 LL'LL'D;D:2 yJJ 2 y 2 y 2 2 2=2 2=2 2 2 =2 2 2 2 2 2 2=2 2 b 2 b N b bbd 2 =o N - M NNN N O f A b m N d f")2yt+f M ::: N O O n iflnO'm N2b c7, bNhN N fNO2Omm pp pp Lp C p p 40 2 0 0 40 0 7 f.� t 7 t 7 O CAD f• O N S S O m OOOOR RR��N fmI ypjN�Om11 �NNaN b0 m� 0N0104 2d m�NO N � U:- L pt N N G N N N NM M fl Pl d n 4?2f`" 8m N Em°'-=-° 8> a ° m a E m O A N N b N N 0 m p G 2 Q i M dN" N m V e O r 0 ON i c 88p p 0 O ]NN N mh O,N a n mom 222;T:= N8.1 OO uN28 ,02 Y OGOf' 2NHN2 2N°o- oP� $ 88224 vo;BN ur.`omo ',2:=P m oN N N 2 M M d d 2 y 2 2 r A r m o n d O C O • p ~O y C d ...h 21 2 4 m Y O E T o r t 0 C W v i c m 0 o Z Z • O e e m c ;1 : o O oK U� oo 8 8',2222 m N m o d l:n m mo yn A m 2n h o N y Mme p 7, N« 2 , m =t fEyo0 N�Nfryd 226-FE! amNM O V aO d E82PN N-2 m° Nm 7 .N • • m 0 O m y 20 m e tp L C -E LL . p V m a m m w w z • s c 2 0- O R ZCCOG • r g esrt93 g 1 N O21-2O2 Z9F J Z M m 0 e O pp O pp m N d N R 01 N N m N fo m 0 N D N M N m O O 1 N M N b N m n O b N I■ O , 0p 0p0 v O y0A,>"n -1m 0' '826 272p0 , M ^amO N N d 2 b A y O 220 N h7 d 2 O b On N m m N N N N y N N 0. ry N 0 5 r Csii th y E N N N N A r ,75 N M p A g822,2 8 2 2 0 8 2 0/2 m o 0.- 82,18V e b O b n N 822 .- a O N:-nd 44N;'4 2^0N q7 NN hN b 2222 6V p2 .988Tz N p N O 2 , N N O O 2 p p A W m 0 .- N N N y d 2 b b r r m m m N N d N M ll N Ma ,9=':-‘1 J2 8 ;):1:4 m o 2" "�� B 2= 8$888 88888 88888 88888 88888 88.Q- 0,-,,,,,-- ( V ....g3 N en en en 0 M um q NN:-r E °NNfNN M M M N M M f�M M M N M M M M M M M fN M M M M N M n n n o o 2 fo w fb0 . b Ft a ° �a3N 2 30 o 41.' 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E M .. .a 0,3 o yr 1 1 ti 1 1 I i i i o V Uu !' !� �1! m 9 t l 1 1 1 111 1 v•rg FbF !� O m V I 1 1 I 1 1 111 1 C i- W _ 1 iN Y n R_ Ids 1> 1 i i 1 11 1 11 1 1 1� 1 1 1 1 1 11 1 U N • ii i - 0 !d' ! ! �• 1 bbl..t... o u) • 1 1: 1 1 1 1 1 iii , TO O 0 U M c 0 0 0 0 °' O O O .- N CO (4)000L:(u!)l =eleoS and (u)000 v(u!)l=epos and Ft Eni (Petroleum Schlumberger WELL I FIELD I STRUCTURE OP12-01 (P3) Nikaitchuq Oliktok Point Magnet PaMmeters Sun(ace Locown 818027 Alaska Stare Plane,Zone 04,US Feet Miscellaneous Model 6GGM7009 P0 60.956' Dale: July 25 2010 Let N 70 30 39 615 No0* 60365356/MI5 00000m 0.12863956' I S. °P12 tVD Re( Rotary Tabb(522Il above 61SL) Ma9 Dec. 21617' FS 57578300 Lon: W 149 51 48 752 144336 516675 72 Scab Fact.099390032 Plan. OP12-01(P3) Noy Date Juty 25,2010 -7500 -6000 -4500 -3000 -1500 0 ENI Lease Line(678)18 9000 9000 • N OP12-01(P3) TD A '' End Cry � OP12-01 T15 ♦` '. cry 3(100 7500 -°.End Cry 7500 End Cry OP12-01 T13 Cry 3/100 DP12-01 114 Cry 3/100 • End Cry End Cry OP12-01 T1 OP12-01 T12 Cry 3/100 Cry 3'/100 End Cry End ry 6000 .••0P13-01.4.9 6000 OP12-01 T10 Cry 3/100 Cry 3/100 Er d Cry A OP12-01 17 A End Cry ' ^ry 3/100 A OP12-01 T8 ' Z Cry 3/100 End Cry 0 4500 End Cry CQP12-01 15 4500 OP12-01 16 :Cry 3/100 in Cry 3/100 -C End Cry El d Cry DP12-01 13 Cry 3/100 li OP12-01 14 N (0 Cry 3/100 End CN U End Cry (n OP12 41 T1 OP13-01 T2 Cry 1/100 (/) 3000 Cry 3/100 •-5/8•Csg 3000 v V End Cry IP0l Heel V End Cry • Cry 3/100 ENI e'ase L)ne(577)18 _—� ENI Lease Lirie(577)18 Cry 3.5/100 tNI Lease Line(615)1 End Cry: 1500 Cry 3$/10q 1500 End Cry 13-3/8'Csg Cry 3.5/100 RTE 0 .CrxA.5/100 0 Civ 3.5/100 Bid 2.5/100 KOP Bid 1.5/100 -1500 -1500 -7500 -6000 -4500 -3000 -1500 0 <<< W Scale=1(in):1500(ft) E >» Schlumierger OP12-01 (P3) Anti-Collision Summary Report Analysis Date-24hr Time: May 18.2010-12:09 Analysis Method: Normal Plane Client: ENI Reference Trajectory: OP12-01(P3)(Def Plan) Field: Nikaitchuq Depth Interval: Every 10.00 Measured Depth(ft) Structure: Oliktok Point Rule Set: O&M AntiCollison Standard Slot: OP12 Min Pts: All local minima indicated. Well: OP12-01 Borehole: OP12-01 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Restricted within 40000 ft Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Del Surveys when no Del-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft)_ Alert I Minor I Major 0111-01(P3)(Del Plan) Warning Alert 8.00 6.78 4.76 N/A 0.00 0.00 Surface 8.00 537 466 4.81 290.00 290.00 OSF<5.00 MinPt-0-ADP I 8.001 5.31 4.57 4.60 300.00 300.00 MinPt-CICt 8.11 5.101 4.21 3.87 369.97 369.97 MinP1-0-EOU 8.20 5.13 4.2 3.77 389.96 389.95 MinPt-O-ADP 8.44 528 4.31 3.721 419.92 419.90 MinPt-O-SF 25.17 19.13 16.73 4.98 856.74 852.30 OSF>5.00 Exit Alert 96.8• ut g' 71.51 5.94 1930.49 1792.99 MinPI-0-EOU 98.75 79.98. 5.56 1978.99 1832.80 MinPI-0-ADP 112.04 89.09 78.l �'/I 2135.15 1958.50 MinPI-0-SF 476.22 404.19 368.6 pp ! 4566.62 3410.80 MinP1-0-SF 1430.78 1317.25 12609 6272.01 3599.50 MinPI-O-SF IE 4_ 993 58 MIME EIC 10111.91 3611.23 MinPts OP13-t03(P1)(Del Plan) Warning Alert 23.98 22.06 20.74 N/A 0.00 0.00 Surface MEM 19.87 18.84 10.68 410.06 410.04 MinPt-CICt 23.9 Nom 18.67 9.88 450.05 450.00 MinPt-0-EOU 23.98 19.79 9.72 460.04 459.98 MinPI-0-ADP 29.19 24.06 22.4 I ', 649.39 648.44 MinPI-0-SF 32.59 27.09 25.3.1.1.1111321 708.94 707.35 Minn-0-6F 62.03 53.64 50.44 1013.09 1002.38 MinP1-0-SF 94.37 81.38 75.8 BMX 1283.43 1249.66 MinP1-0-SF 148.07 127.96 1188. 1849.47 1726.24 MinPt-0-SF 1326.50 1285.77 1266.2:�I'cl 4450.22 3366.72 MinPt-0-SF II 828.64 661.60 578.88 5.00 10685.36 3614.31 OSF<5.00 MinPt-0-ADP Lam.. 703.11)j 4626 343.2311 2.941 12712.22 3667.81 MinPts Oliktok Point 1-2(Def Survey) Warning Alert 88.50 86.59 85.26 N/A 0.00 0.00 Surface 86. : -.11130 N/A 40.00 40.00 MinPts 33.13 7.03 1100.63 1084.36 MinPts 44.04 36.12 1113'. 1110.66 1093.66 MinPts 615.27 586.72 573.3 I1111111M 2614.63 2289.53 MinPt-0-SF 695.22 663.13 647.'=ME13 2770.78 2386.96 MinPt-0-SF 751.09 716.60 700.2'MR:3 2881.05 2455.76 MinPt-0-SF 792.53 756.25 738.•• Elgj 2960.83 2505.54 MinPt-0-SF 1360.6•, P 1232.52 16.11 5256.60 3578.28 MinPt-0-EOU 1362.50 1274.9:'))))))))) 15.84 5300.81 3580.47 MinPt-O-ADP L 1387.22 1160.76 1048.33 6.16 1090725 3619.59 MinPl-CtCI 1388.1 115993 1046.62 6.12 10977.24 3623.37 MinPt-0-EOU 1390.52 1160.581 1046 411 6.08 11047.06 3627.15 MinP1-0-ADP 1305.38 1042.70 912.16 4.99 12412.79 3661.99 OSF<5.00 MinPt-O-ADP II 1294 191 1024.16 889.9 I 4.821 12712.22 3667.81 MinPts OP09-S03(P1)(Del Plan) Pass 2199 22.08 20.75 N/A 0.00 0.00 Surface MIME 20.60 19.87 14.97 300.00 300.00 MinPt-CtCt 24.10=EMI 19.68 13.26 339.97 339.97 MinPI-0-EOU 24.24 20.55 M1? 12.60 359.95 359.95 MinPt-O-ADP 27.91 23.51 22.26 MIMI 509.71 509.55 MinPt-0-SF 653.37 624.02 610.2 MEEY15' 2516.35 2228.19 MinP1-0-SF 2158.29 2069.46 2025.8 ME* 5656.47 3587.80 MinPt-0-SF 2609.73 2500.88 2447.2 MIIIIMEEI 6435.02 3600.49 MinPt-O-SF 2723.30 260984 2553.91. 6617.82 3601.47 MinPt-0-SF 4152.73 3984.52 3901.2 '•d 8954.24 3625.44 MinPt-0-SF 4228.94 4057.22 3972.1 MEM 9142.30 3619.06 MinPI-O-SF -17L9 12712.22 3667.81 MinPts OP07-104(P2)(Del Plan) Pass 40.00 38.08 36.75 N/A 0.00 0.00 Surface 40.00 36.61 35.87 25.82 300.00 300.00 MinPt-CtCt 40.18.11111EM516l 19.57 399.85 399.84 MinPts 46.55 41.98 40.65 568.73 568.34 MinPt-O-SF 1720.48 1691.57 1678.00111 2770.39 2386.71 MinPt-0-SF 2477.18 2421.77 2394.9 3977.44 3136.04 MinPt-0-SF 3752.62 3682.24 36476 MEER 4756.87 3481.06 MinPt-0-SF milli...,(ff.-.7(3(10 1 71R n Nik aitrhnn\(llikink Pnint\()Pi 9-M\fP19111\f1P19.f11(P9\ 5/1A/9MO 19.1n PM Pan.1 nf4 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-0t(ft)J EOU(t�_Dev.(ft Fact. MD(ft) I TVD(ft) Alert I Minor I Major _ 4478.48 4393.13 4351.2 53.44 5535.16 3585.44 Min Pt-O-SF 4596.42 4509.26 4466.4 53.71 5658.54 3587.84 MinPt-O-SF 5200.18 5099.52 5049.99 52 4 6262.60 3599.44 MinPt-O-SF 5518.41 5410.76 5357.731 52.021 6593.13 3601.45 MinPt-O-SF 6217.98 6093.99 6032.801 50.791 7330.73 3608.63 MinPt-O-SF 7041.95 6898.19 6827.121 49.53) 817689 3620.19 MinP1-3-SF OP08-04(P3)(Del Plan) Pass ®:E 29.10 28.36 20.71 300.00 300.00 MinPt-CtCt 31.87 mirs 28.21 18.85 32967 329.97 MinP1-0-EOU 31.99 29.04 1763 349.95 349.95 MinPt-O-ADP 57.61 51.86 49.5•IMEM 787.78 784.93 MinPt-O-SF 67.55 60.94 58.24® 868.57 861.85 MinPI-O-SF 442.40 421.17 411.0•, sl 2234.40 2034.22 MinPt-O-SF 1064.90 1012.43 986.6:j1..4 4013.33 3156.44 MinP1-0-SF 2478.68 2398.15 2358.3'1111.110E 5339.01 3581.61 MinPt-O-SF imi08g90 9312.25 3611.59 MinPts OP19-ENI#1(P1)(Non-Def Plan) Paw mum 69.94 68.37 23.20 667.91 666.78 MinPt-CtC1 75.. MIIMIMMEE 22.83 677.58 676.35 MinPts 80.66 74.92 73.01 MEE 782.23 779.49 MinP1-0-6F 84.34 78.42 76.4• 8 '•� 810.05 806.76 Min Pt-O-SF 3451.19 3411.84 3393.0 �, 3818.35 3040.58 MinPt-O-SF 7376.42 7333.20 7312.46 177.84 4328.21 3315.48 TD OPOSP06(P3)(Def Plan) Pass 64.04 62.12 60.80 N/A 0.00 0.00 Surface Min 60.65 5691 42.12 300.00 300.00 MinP1-CtCI 64.11 3560 359.87 MinPts 75.15 70.83 69.6 .�J 577.33 576.90 MinP1-0-SF 82.44 77.88 76.56 IlE 625.61 624.87 MinPt-O-SF 6760.31 6696.75 6665.8 3969.73 3131.60 MinPI-0-6F• 7039.33 6969.74 6935.8. 4065.26 3185.17 MinP1-0-SF 8481.19 8385.76 8338.9.- 4438.22 3361.95 MinPt-O-SF 8898.62 8796.77 8746.7. 888• 4623.24 3432.01 MinPt-O-SF 9838.07 9712.87 9651.0: 5666.99 3588.02 MinPt-O-SF 10788.37 10640.05 10566.7.- 6609.56 3601.50 MinPt-O-SF OP06.105(P31(Def Plan) Pass 55.99 54.08 52.75 N/A 0.00 0.00 Surface imgE 52.60 51.86 36.66 300.00 300.00 MinPt-CtCI 56.10® 51.46 29.80 369.87 369.86 MinPt-O-EOU 56.16 52.38 Milligal 29.05 379.85 379.84 MinP1-0-ADP 94.62 87.47 84.85 883.73 878.50 MinPt-O-SF 98.21 90.86 88.14 MEM 903.02 897.15 MinPt-O-SF 5097.92 5045.65 5020.3.1 100.8• 3849.93 3060.16 MinPI-O-SF 5942.53 5880.55 5850.44i~ 986.) 4200.78 3255.59 MinPI-O-SF 7800.84 7706.48 7660.1:W EE 5161.71 3570.80 MinPt-O-SF 7804.84 7707.66 76598:!_,: .4� 5354.51 3581.92 MinPt-O-SF 8112.41 8008.52 7957.3 NEM 5667.39 3588.03 MinPt-O-SF 8234.57 8128.17 8075. MEIN 5771.45 3590.37 MinPt-O-SF 9313.38 9180.42 9114.7. 1 6873.16 3600.43 MinPt-O-SF OP20-ENI#9(PI)(Non-Def Plan) Pass 80.85 79.53 31.62 619.16 618.47 MinPt-CICI 85.4 79.47 31.09 628.93 628.16 MinPt-O-EOU 85.47 80.82 M' '. 3069 638.67 637.82 MinP1-O-ADP 94.57 89.18 87.. 781.54 778.81 MinPt-O-SF 100.69 95.05 9319 511o.l 818.23 814.76 MinPt-O-SF 5787.34 5757.56 5743.5 Mr 3654.18 2938.15 MinP1-0-SF 7545.45 7514.38 7499.73 25742 3935.25 3111.51 TI) OP03-P05(Def Survey) Pass EWE 77.' T4:11M 108689 68.00 68.00 MinPts • 77. • 93.68 243.37 243.37 MinPts 80.11 M513M 76.65 76.16 289.00 289.00 MlnP1-3-EOU 80.15 77.17 mom 73.18 299.00 299.00 MinPt-O-ADP 10316 98.33 96.::man 671.07 669.92 MinIN-0-6F • • 3703.99 3653.22 3628.7.MOZ. 3840.71 3054.48 MinPt-O-SF • 3796.80 3744.84 3719.74 3907.38 3094.99 Min%-0-SF 4029.61 3974.35 3947.5•jm1EE1 4067.08 318616 MinPt-O-SF 5990.37 5912.84 5874.••11111111111 5180.12 3572.51 MinPt-O-SF 6301.73 6216.61 6174.:r min 5661.73 3587.91 MinPt-O-SF 7224.85 7122.17 7071.6 MIKEI 6598.80 3601.48 MinPt-O-SF 750830 7377.51 7312.7211ME4 6888.76 3600.37 MinP1-0-SF OP03-P05PB2(Del Survey) Pass MI E: 77.• 11111111.43M 1086.69 68.00 68.00 MinPts 3I. 77. •Mffilla 93.68 243.37 243.37 MinPts 80.11 ER= 76.65 76.16 289.00 289.00 MinPt-O-EOU 80.15 77.17=mg 73.18 299.00 299.00 MinPt-O-ADP 103.16 98.33 96.88 671.07 669.92 MinP1-0-SF 3703.99 3653.22 3628.72 3840.71 3054.48 MinPt-O-SF 3796.80 3744.84 3719.74 3907.38 3094.99 MinPl-O-SF 4029.61 3974.35 3947.5 4067.08 3186.16 Min%-0-SF 5893.60 5786.74:WS=111.1310.4 5102.04 3563.74 MinPts Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status _Ct-Ct SftJj EOU(ft) Dev.IN Fact. MD(ft) I TVD(ft) Alert •I Minor I Major OP14-108(P1)(Del Pian( pass 31.97 30.06 28.73 NIA 0.00 0.00 Surface Man 27.81 26.77 14.35 420.10 420.07 MinPt-CIC1 31.87 11111Effj 26.64 13.57 450.10 450.05 MinP1-0-EOU 31.96 27.76 13.14 470.09 470.02 MinPt-O-ADP 50.34 43.69 41.3 AmEEE, 857.30 852.85 MinPt-O-SF 59.62 52.04 49.21 945.34 937.86 MinP1-0-SF 68.16 59.78 56.5 � 1013.42 1002.69 MinPt-O-SF 111.84 98.63 92.98 iiiimigg 1282.19 1248.57 MinPt-O-SF 3098.10 2852,49 2730.4:L.... 11757.61 3648.64 MinPt-O-SF 3458.78 3189.52 3055.69 12.92 12712.22 3667.81 TD OP22-ENI#1(P2)(Def Plan) Pass 103.97 102.05 100.73 N/A 0.00 0.00 Surface 96. 91.54 89.84 27.95 715.32 713.64 MinPt-CtC1 96.91 91.531 89.80 27.43 724.88 723.07 MinPts 106.59 100.30 98.12 23.93 854.87 850.48 MinP1-0-SF 3446.32 3406.90 3388.0 91.461 3818.52 3040.69 MinP1-0-SF 7380.56 7337.18 7316.37 17729 4327.88 3315.33 TD OPO4-07(P10)(Del Plan) Pass 71.99 70.76 68.74 N/A 0.00 0.00 Surface 69.29 68.56 48.14 299.00 299.00 MinPf-CtCt 72.05 MIME 68.40 43.70 328.93 328.93 MinPt-O-EOU 72.18 89.23 4124 348.89 348.88 MinPt-fa-ADP 122.68 115.16 112.01 EWE 893.90 888.34 MinP1-0-SF• 728.05 696.52 681. 9 t, 2612.77 2288.36 MinPt-O-SF 2782.18 2698.55 2704.3 ass 5345.37 3573.56 MinPt-O-SF 2834.63 2747.44 2704.3 / 5345.37 3581.74 Min%-0-SF 6676.12 6513.01 6431.9 M'1 9403.24 3608.63 MinPt-O-SF 6724.25 6560.21 6478.69 41.23 9463.67 3608.63 TD OP21-ENI#10(P1)(Non-Def Plan) pass 95.99 94.07 92.74 N/A 0.00 0.00 Surface 95.661 92.00 91.14 53.98 47024 47017 MinPl-CtC1 95 66 92.001 91.16301 53.83 480.20 480.11 MinPts 123.30 118.13 116. 37291 846.20 842.05 MinPt-O-SF 6068.75 6043.27 6031.42 255.81 4298.28 3301.99 ID Oliktok Point 1-1(Del Survey) Pass 9654 94.62 93.30 N/A 0.00 0.00 Surface 96.54 94.62 93.30 298063.03 40.10 40.10 MinPts 96.62 94.53 93.38 550.63 7920 79.20 MinPt-O-EOU 149.44 144.50 142.••MEM 650.72 649.76 MinPt-O-SF 184.70 178.96 177.05 780.42 777.71 MinP1-0-SF 7360.6,�• R=RIZ 3069.79 2573.52 MinPts Oliktok Point 1-1A-106(P3)(Def Plan) Pass 96.54 94.62 93.30 N/A 0.00 0.00 Surface 96.54 94.62 93.30 298063.03 40.10 40.10 MinPts 96.62 94.53 93.38 550.63 79.20 79.20 MinPt-O-EOU 149.44 144.50 142.99 48.85] 650.72 649.76 MinPt-O-SF 184.70 178.96 177.05 47.81 780.42 777.71 MinPt-O-SF 7188.70 7154.80 7138.73 223.63 2596.94 2278.49 MinPt-O-SF 8016.39 7944.19 7908.97 113.78 3931.44 3109.27 MinPt-O-SF ' 8149.55 807424 8037.4 110.78 3974.29 3134.23 MinPt-O-SF • 8449.05 8366.06 8325.4 10399 4062.69 3183.77 MinPt-O-SF 9312.90 9210.32 9159.91 92.3 4276.23 3291.82 MinPt-O-SF 10953.86 10821.40 10756.05 83.80 4919.48 3528.80 MinP1-0-SF 11501.51 11355.32 11283.03 79.54 5668.07 3588.04 MinP1.0-SF 11830.65 11677.10 11601.13 I:,, 5981.99 3595.10 MinP1-0-SF OP24-ENI#4(P2)(Del Plan) Pass 119.91 117.99 116.67 N/A 0.00 0.00 Surface mum 115.70 114.65 56.34 429.53 429.50 MinPt-CtCt 119.76 MEM 114.50 52.89 469.71 469.64 MinPt-O-EOU 119.84 115.64=nal 51.44 489.79 489.68 MinPt-O-ADP 199.42 186.50 180.,r mum 1337.27 1296.57 MinPt-O-SF 385.88 362.69 352.0' 2151.97 1971.58 MinP1-0-SF 1388.88 1325.11 1294.1. � 4500.40 3385.99 MinPt-O-SF 5474.41 5393.43 5353.75 68.95 8111.89 3619.69 TD OP15-P08(P2)(Del Plan) Pass 40.02 38.10 36.77 N/A 0.00 0.00 Surface 36.28 35.40 21.50 360.07 360.07 MinPt-CICt 40.02 EINEM 35.27 20.19 390.11 390.10 MinPt-O-EOU 40.06 36.22 MMIIM 19.84 400.11 400.10 MinPt-O-ADP 230.73 207.18 196.36 MEIE. 1570.24 1493.73 MinPt-O-SF 3526.10 3307.73 3199.341E11W 10640.61 3614.07 MinPt-O-SF 3585.61 3363.56 3253.34[MEW 10775.41 3614.80 MinP1-0-SF 3657.84 3432.05 3319.9 IF®t 10931.12 3620.88 MinPI-O-SF 3818.17 3582.79 3465.91 ICI 11289.99 3640.15 MinP1-0-SF 4467.15 4210.70 4083.28 17.52 12712.22 3667.81 TD OP18-107(P2)(Del Plan) Pass 64.00 6208 6015 N/A 0.00 0.00 Surface frillir,n(lffiro 9nn0 1 71R n Nikaifrhun\flliktnk PnintlOP19-Div-IP191111f1P19111/P31 cilia/In-In 19.1n P14 Don.3 nfA , Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) 1 TVD(ft) Alert I Minor I Major 64.00 60.93 60.35 53.80 250.00 250.00 MinP1-CtCt 6404 60.87 60.24 49.55 270.00 270.00 MinPI.O-EOU 64.09 60.88 60.23 47.80 280.00 280.00 MinPt-O-ADP 240.53 227.40 221.79 21.27 1184.35 1161.14 MinP1-0-SF 3388.20 3270.50 3212.44 29.171 7079.98 3599.62 MinP1-0-SF 4362.64 4193.37 4109.54 26.011 9123.23 3619.89 MinP1-0-SF 6429.07 621922 6115.1 30 861 1134224 3641.64 MinP1-0-SF 6601.21 6383.76 6275.84) 30.581 11765.60 3648.77 MinP1-0-SF 6800.72 6565.42 6448 58 29 09 12712.22 3667.81 TD L.2.82730.601 2689.0[I 33.89 5668.41 3588.05 MinPts OP16-P03(P2)(Del Plan) Pass 48.01 46.09 44.76 N/A 0.00 0.00 Surface 48.011 44.61 43.88 31.26 300.00 300.1)0 MinP1-CtCt 48.07 44.561 43.76 28.99 330.05 330.05 MinPt-O-EOU 48.12 4457 43.76 28.35 340.06 340.06 MinP1-0-ADP 253.82 231.56 221.39 12.38 1566.32 1490.43 MinPt-O-5F 353094 3349.93 3260.2 19.6 9208.09 3616.16 MinPt-O-SF • 3747.72 3556.79 3462.12 19.7 9602.91 3609.09 MinPt-O-SF 5429.13 518641 5065.85 22.51 12712.22 3667.81 TD OP26-DSPO2(Def Survey) Pass Mid=213[11..E, N/A 0.00 0.00 MinPts IMMO 240.23 235.82 2821 1491.78 1427.72 MinPl-CICI 251.04,11111MEMZEM 28.15 1501.32 1435.76 MinPts Erci:i----190.48 184.03 15.76 2343.29 2113.01 MinPt-C1Ct 205. .=IMO 183.93 15.64 2351.95 2119.08 MinP1-0-EOU 205.48 190.45 183.89 15.52 2360.62 2125.12 MinP1.0-ADP 365.73 327.17 308.7 [MIZE. 3516.87 2852.48 MinPt-O-SF 417.59 373.02 351.62 MOM 3821.66 3042.65 MinPt-O-SF 3376.55 3330.47 3308.2.simirfi 5697.83 3588.71 MinPt-O-SF OP25-DSP01(P1)(Def Plan) Pass 344.641 341.14 340.35 216.44 300.00 300.00 MinPl-CICI 344.80 341.001 340.06 182.08 358.19 358.18 Min14.1-0-EOU 344.99 341.04 340.03 168.63 387.27 387.26 MinP1-0-ADP 485.28 475.55 471.64 61.851 126320 1231.80 M1nPI-O-SF 3993.56 3965.73 3952.69 153.09 4002.95 3150.59 TD OP23-WW02(Def Survey) Pass ,.' 108.7. t.(I0; 109.35 267.98 267.98 MinPts 108.4:. 90.06 339.14 339.14 MinPts 110.92 MEM 107.67 89.31 349.18 349.18 MinPt-O-EOU 108.17 107.48 79.66 429.50 429.47 MinPt-CtCt 109.94 106.96 106.09 62.04 599.46 598.90 MinPt-CtCt 110.01 106.92 105.99 58.43 629.20 628.43 MinP1-0-EOU 110.05 106.93=lc 57.31 63910 638.24 MinPt-O-ADP 147.23 142.00 140..■ 1038.73 1024.67 MinPt-O-SF 46120 450.94 446.4.map 2026.26 1871.48 MinP1-0-SF 1065.27 1027.67 1009.41 OMB 3820.74 3042.07 MinPt-O-SF 7271.05 7213.84 7185.72 12929 6472.80 3600.72 TD OP1O-P09(P1)(Def Plan) Pass 16.00 14.09 12.76 N/A 0.00 0.00 Surface 16.00 1293 12.36 12.20 250.00 250.00 MinPl-CtCt 16.20 11.78 8.55 339.98 339.98 MinPt-O-EOU 16,40 12.66 MEM 7.93 369.97 369.97 M1nP1-0-ADP 22.03 16.96 15. •■ 1 580.00 579.56 MinPt-O-SF 25.09 19.51 17.6 640.07 639.21 MinPI-O-SF 72.84 60.80 55 741 1133.24 1114.47 Min171-0-SF 1959.96 1843.29 1785 7.M1113 7069.45 3599.63 Min%-0-SF 2322.01 2179.92 2109.6 mum 8003.31 3618.91 MinPt-O-SF 2568.60 2411.31 2333 4 millEzE 8582.56 3623.20 Mi8P1-0-SF ' IjE --__ 12712.22 3667.81 MinPts OP17-P02(P3)(Def Plan) Pass 55.99 54.07 52.75 N/A 0.00 0.00 Surface IIIIMME 52.61 51.87 36.79 299.00 299.00 MinPt-CICI 56.0 51.79 34.98 319.03 319.03 MinP1-0-EOU 56.07 52.57 MIK 34.21 329.05 329.05 MinPt-O-ADP 224.82 208.88 2018 •'4 1366.93 1322.04 MinPt-O-SF �lIIMIM 10.80 12712.22 3667.81 MinPts OP03-P05P81(Del Survey) Pass 79.90 77.921=IM 1086.69 68.00 68.00 MinPts 77.2.tilwaz 93.68 243.37 243.37 MinPts 80.11 76.65 76.16 289.00 289.00 MinP1-0-EOU 80.15 77.17 IIII1WE 73.18 299.00 299.00 MinPt-O-ADP 103.16 98.33�y 9�6y.: 671.07 669.92 MinP1-O-SF 3737.6.1 360347,:WIRE MEM 3810.72 3035.82 MinPts Schlumberger j 'IRAVE ING CYLINDER PLOT 'Client: ETU NoGo Region EOU's based on: Well: 0P12-01 Oriented EOU Dimension 'Field: Nikaitchuq N NoGo Region Anti-Collision rule used: 'Structure: Oliktok Point ,Minor Risk-Separation Factor ji!= 'Date: July 25,2010 1• J North 350 0 10 340 20 330 30 14 0 0-P09(P1) 320 .. ` 40 120 IP*�WO i��;' ,•" 11-01 (P3)0 310 i�,��111�c'09-S03 P1 �/ 7�r�1/,�4 ;��i'�►P06407(P10) 300 80 ,./ it �.�.� fir."4, A 4 ♦��A 290 ' �.��`�t%~*,14 I• ,i∎V 70 it.,......,,-;,-..,,,:.,:e1„,,,,40,,,:7-4, ..., ,,,,,, ..... ..*;;;-.:14.4.....„. ...,,,44�� '�"i�I`?Ems' � •� ;/ ��r!� _. ; .. :�;.� .- �. ��: . 280 _��'`,' 4 r� ( i A , . , ^. , :a t � . �eeppo33pp��oS5nppg- - 6(P' 2',0. ! i r.... `;.y may. 270 , � « ��► .. ..i so 2,1 kt Li �.y.. _a'��'�� • � ` ' �:.�� i�_ 1�� P07-104(P2)• 260, • ', \ ••kV 4r .•W:= II e �s. i;'' 'k.h �/4�.., f1 �� 100 �� .• bi'' i� i ' R r; i � i� f•P05-P06(P3) 250 :i `i 1!Aplt.:40, .. 4,Slitlk�► "�`• ‘ , �' ,li.,-!i,./j ' I N�rz �I� 110 240 �� ►..,:� '�:��711%01°1 �f� o��•�'�.� 120 '� ,:::i/, y 1- :`51`/230.: �) / l i.? Toi,„ ►�; t`\ � 130 "�• v i' `_4, e.221•..a)f ..<1• ' , ! �` ' 140 • 21171'. �- 11■�``� ��.Ob ENI#1 (P1) 200 190 �• y..:,,.,., I#1 )�U- 1 F9(P11)(P2) 180 Well Ticks Type: MD on OP12-01(133) Calculation Method: !Normal Plane Ring Interval: 120.00 It 'Azimuth Interval: 110.0 deg Scale: I IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: ENI No Region EOU's based on: Well: OP 12-01 Oriented EOU Dimension Field: Nikaitchuq NoGo Region Anti-Collision rule Structure: Oliktok Point Minor Risk-Separation Factor= Date: __ July 25,2010 �� in°� North 350 0 10 340 Fi 20 330 •f ` i-'0�09�P1) 320 . �.�, ,, �ver 40 310 illIW ei, e 50 .� P09-S03(P1) 300 ►�� 1� r �� 4pe . �+ 60 •liktok •int'I-2 �f O /' direow,AIV,ti' 290 � e�-'I 70 (�) k*,. thlirkVi i i At krA 280 41FICO•''' I 0"' , W tri— ,80 •P07-104(P2) 270 iiiums, r/,01'41 90 o ,,!�!`. e ,.. 100 260 j_'\ �1; '` `c; _._ ‘. -- (:•-7-.7•,,,,,,,,r*IYA...""414 250 /414,I��►1,, o)'� .',-, .� \ 110 240 :rt �fti� �� Vp,�` 120 230 R�f Irie 130 220 i�, 4 10 111-01 (P3)4411111111111„�•' � ll� �• ,� 210 _z,. 150 200e. 14” • 160 190 180 170 !Well Ticks Type: MD on OP12-01(P3) j Calculation Method: Normal Plane 1Ring Interval: — 1 10.00 ft Azimuth Interval: 10.00 deg IScale: !1 INCH=20.00 ft Drilling Hazards Sumi1 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 I •_I Pi % _J I!1!11 4 1 'q' w P o s _ ca glill-1 >u, W - ii t 1 Ii 1.2 I cr El W ouJ i u 0 1 ii. IL tti I I N n I' ® I iII::: II�s o1I ^...I v° �� i7 �,' _� � • IN _ ` as Pig z `'z §3 0gW 36t C E =�� = ... 11,d 1, Ig 1 4111 h i1` h x �_ > Uf _ . Z T v I Z ._ _ _- Z _—:_ _ _ ___________. 1 _ ;2-Y ry W m A a u �I\ o < "Ii ii it .11 t. 45 1,. .ti/,>,-.e k N | §� &�/ | �& | | =f / ie # ° Cr) / \ z R/ / 2 ■ \ \3 »@// §o/ AE2 14, 1 ©==\2 2 zZ O C. r GG\ k § ~2| / %»®®u %<®_ ®-az % ®< �3�/� �cn// ®E2� �53- in\\R� �\,� ��// \\\� | \� ! \®%® � \ � }coy` % � at | ■ r \� Y� 0I- ��Sc`N \�\rn % / % ® %» % § |. IN _ )I & % h i5 4,A iy ƒ» � ..■ 7q k§E ' \ - » %§ ■ In{¢ �\ j� &° &G In 6« NI 1. A ' — � — W g O �� \ 3 A∎ Cs1 « �� 2 � E- 0 C .+ ƒ in Fl � _ __ _2 I 2_ Z �- -- / » V 5 •1 ° A « 0 V , I cc A c U & - 0 »§ / ik CO -2 > I 032 9 c o \� 0 8 ` 3 �§� 1Z - �)\ -» *« I In - • O i20 m ; gy at uviti ,�\ .,, lir Ili � \J A ,! . d f4 —4 _ T .:.✓ 3' ® W .1Tif 1 (dh•\* A F ti° �1V ilit- � ' > > � T r �� i � PI` , i ,, 'cis ro r = c _c Z c5 c� c� U 7 C N c c a)cts U) ` c c c CO �'_ � O 2 2 '.v +N. a) Q) a) co ' '' ' J ro ro ro 3 �7 1. �; :• 0 0 0 w , .�. a o 0 0 0 w a) V r .- r r- (d -U N \ - \ \ a Q) r T r C Cl N d- C) ,L;7 aa_ O T ' ‘E' O -Ty (-5 C > To m 76 CC 1 J E _a E 0,— E `n co 00 _ U , „■ r Q Z Z 7 = r CO...rig E-[- 631 ip• I [...,,,,,,,,$.,:miiiiiiiiff D D Schlumberger C e m CA D E*well cementing recommendation for 13.375"" Surface Casing Operator : Eni Petroleum Well : OP12-01 Country USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Jason Brink Location : North Slope-Alaska Proposal No. : Draft vi Service Point : Prudhoe Bay,Alaska Date Prepared : 6-2-2010 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Tony Stafford Phone : 907-273-1700 E-Mail Address : tstafford@slb.com 7 C FL GATE . 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 : OP12-01 S hiumberger String : 13.375 District : Prudhoe Bay,Alaska „t �j {� Country : USA Loadcase : Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2430.0 ft BHST : 50 degF Bit Size : 16 in ft (x 1000) psi J 0 1 1 .0 1 .5 Frac Pore Permafrost • • • t o _ _ . . . . . . Well Lithology Formation Press. Page 2 OP12-01.cfw;D6-03.2010: LoadCase Surface Casing.Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 Schiffilleger 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 : 2350.0 ft Casing/liner Shoe MD : 2430.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2430.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 123.1 % Mean OH Equivalent Diameter: 18.734 in Total OH Volume : 773.9 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 1900.0 16.000 150.0 19.279 2430.0 16.000 35.0 16.822 Page 3 OP12-01.dw 06-03-2010; LoadCase Surface Casing;Version wcs-cem460_14 it Client : Eni Petroleum Well : OP12-01 SchImubrger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 55 deg Max. DLS : 4.510 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 0.000 100.0 100.0 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 1427.9 1353.2 37.5 359.7 3.506 1500.0 1410.2 37.8 359.7 0.500 1600.0 1488.9 38.3 359.7 0.500 1700.0 1567.1 38.8 359.7 0.500 1800.0 1644.7 39.3 359.7 0.500 1900.0 1721.8 39.8 359.7 0.500 2000.0 1798.3 40.3 359.7 0.500 2072.2 1853.2 40.7 359.7 0.498 2100.0 1874.0 42.0 359.8 4.510 2200.0 1945.7 46.4 0.2 4.497 2300.0 2011.7 50.9 0.5 4.497 2400.0 2071.6 55.4 0.8 4.506 2430.0 2088.7 55.4 0.8 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 120.0 11.00 8.43 Permafrost Sandstone 1900.0 12.00 8.43 Permafrost Sandstone 2430.0 13.00 9.20 Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (deg F) (degF/100ft) 0.0 0.0 20 0.0 1900.0 1721.8 32 0.7 2430.0 2088.7 50 1.4 Page 4 OP12-01.cfw,06-03-2010: LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 Schlimbe ger String : 13.375 District : Prudhoe Bay,Alaska YYii1i N,t'YY Y Country : USA Loadcase : Surface Casing ft degF (x 1000)ft 0 I 40 60 I U 1.6 0.9 1.2 —Geoth.Profile —Hori. Depart. • N O (0 o O - co 2 O O • • O 7j: o ti c-.4 tO [10 N O N O Cy - Temperature Hori. Departure Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost Original fluid Mud 9.50 lb/gal Pc: 12.000 cP Ty:7.00 lbf/100ft2 Displacement Volume 351.9 bbl Total Volume 864.9 bbl TOC 19.7 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 19.7 10.10 Pv:16.000 cP Ty:12.00 lbf/100ft2 Lead Slurry 350.5 1910.3 19.7 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 1930.0 12.00 k:7.50E-2 Ibf.s^n/ft2 n:0.372 Ty:4.15 lbf/100ft2 DeepCRETE Mud 351.9 0.0 9.50 Pv:12.000 cP Ty:7.00 lbf/100ft2 Page 5 OP12-01.cfw 06-03-2010: loadCase Surface Casing;Version wcs-cem460._14 Client : Eni Petroleum Well : OP12-01 SGhlherger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Static Security Checks: Frac 5 psi at 160.0 ft Pore 18 psi at 160.0 ft Collapse 2051 psi at 2350.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 51 ton ft (x 1000) psi o_ 0 I 0 1.5 Hydrostatic —Frac —Pore , • o� I f i t 1 � – Fluid Sequence Static Well Security Page 6 OP12-01.cfw;06-03-2010: LoadCase Surface Casing;Version wcscem460_14 Client : Eni Petroleum Well : 0P12-01 Sehlinkrger 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 6.0 100.0 16.7 100.0 80 7-Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4-Drop Bottom Plug Lead Slurry 5.0 350.5 70.1 350.5 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 8.5 330.0 38.8 330.0 80 19-Start Displacement Mud 3.0 21.9 7.3 351.9 80 21-Bump Top Plug Total 02:35 864.9 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 4 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2051 psi at 2350.0 ft Burst 4842 psi at 0.0 ft Temperature Results BHCT 65 degF Simulated Max HCT 71 degF Simulated BHCT 71 degF Max HCT Depth 2430.0 ft CT at TOC 60 degF Max HCT Time 02:35:23 hr:mn:sc Static temperatures : At Time (hr:mn) 1 (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 20 degF Bottom Hole (degF) (degF) 50 degF Page 7 OP12-01.cfw:06-03-2010. LoadCase Surface Casing:Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 S hlugigrger String : 13.375 District : Prudhoe Bay,Alaska 'll t� U Country : USA Loadcase : Surface Casing O ° --- Acquired Pressure [V Calc.WHP A. Fn 7 Q. r 0 25 50 75 100 125 150 175 Time (min) Fluids at 2430 ft - —Acquired U Out -- -Acquired 0 In O Out T 13 _w Clis i, - ___ ___ _, I ii ra i . T. o• I l 0 25 50 75 100 125 150 175 Time (min) Page 8 OP12-01.cfw;06-03-2010; loadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 Sc leberger 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= 2430 ft ,�, Depth= 160 ft cf5 -Frac I N Egli -Pore O -Hydrostatic -Hydrostatic - • name o -Dynanic in Lo HI p N TO co fi O 0 E N N 9 N N 3 CO :12 `r a i a� I of o, Q1n Q O- I o O_1 i O O m O - ki B 0. a0 t 1 I $ O � � i 0 100 200 0 50 100 150 200 Time(min) Time(min) a `O - Total Depth = 2430.0 ft Top of Cement= 19.7 ft 'Mark of Schlumberger YIh'1IPpP Page 9 OP12-01.cfw;06-03-2010; LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 SGhinmbergef* String : 13.375 District : Prudhoe Bay,Alaska (r a t Country : USA Loadcase : Surface Casing Section 4: centralizer placement Top of centralization :100.0 ft Bottom Cent. MD :2410.0 ft Casing Shoe :2430.0 ft NB of Cent. Used :36 NB of Floating Cent. :36 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 1910.0 23 1/2 NW-TR-13 3/8-8-TR 3 W304 9.5 490.0 2430.0 13 1/1 NW-TR-13 3/8-8-TR 3 W304 40.7 1910.0 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) (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 Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer/Formation :0.3 Total Drag Force :9 ton Hook load Down Stroke :85 ton Hook load Up Stroke :103 ton ft o_ 0 I '0 60 80 100 Between Cent. +A[ Cent. 0 o- } • t O C''i- Pipe Standoff • Page 10 OP12-01_c(w;06-03-2010, LoadCase Surface Casing:Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 Sthi� I l u"(berge String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 5: WELLCLEAN II Simulator ft v. 0 `-I 40 60 80 100 Std Betw. Cent. -Cement Coverage ... 0 o "%"..Li''‘''"a...m„... ‘H H . - o- 0 0 o- r,' 0 0 0 m- Cement Coverage Fluids Concentrations Risk Mud on the Wall z° z 200- 200 200- -200 400- _ -400 400- -400 800- -COO 600- ':-- - 600- -800 800- -800 v 1000- -1000 y 1000- _ -1000 z 1200- -1200 r +200- -1200 1400- -1400 1 r 1 -1400 0• ° 1600- -1600 ° ° 1600- - -1600 4' 1800- -1500 1600- - -1900 2000—` -2000 2000- -7000 2200 -2200 2200- -2200 2400-i -2400 2400-1 -2400 1 1 d 3 O N 3 ;O N O N N a } Ili Mud 0 High III Low = 12.0 ppg DeepCRETE I I Mediurn 0 None I I Lead Slurry I I MUDPUSH II Page 11 OP12-01.cfw.06-03-2010; LoadCase Surface Casing;Version wcs-cern4604 Client : Eni Petroleum Well : OP12-01 SchIWrger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 6: fluid description Mud DESIGN Fluid No: 1 Density :9.50 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 :351.9 bbl Water Type :Fresh VOLUME FRACTION Solids :4.0 Oil :96.0% Water :0.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model :BINGHAM Pv : 16.000 cP At temp. :80 degF Ty : 12.00 lbf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No:3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k :4.06E-2 Ibf.s^n/ft2 At temp. :80 degF n :0.345 Ty :0.03 lbf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name :B809 Mix Fluid :20.852 gal/sk Job volume :350.5 bbl Dry Density : 1.74 SG Yield :4.52 ft3/sk Quantity :435.77 sk Sack Weight : 188 lb Solid Fraction :38.3% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :20.852 gal/sk Page 12 OP12-01.cfw;06-03-2010; LoadCase Surface Casing;Version wcs-cem460_f4 Client : Eni Petroleum Well : OP12-01 Sehlmoberger 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 lbf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.0 PPG Lit Mix Fluid :5.043 gal/sk Job volume :62.5 bbl Dry Density : 1.77 SG Yield : 1.58 ft3/sk Quantity :222.01 sk Sack Weight : 100 lb Solid Fraction :57.4% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :4.973 gal/sk Additives Code Conc. Function D047 0.020 gal/sk blend Antifoam D185 0.050 gal/sk blend Dispers.LT TOTAL MATERIAL REQUIREMENTS Mix Water Requirements : Fresh water 335 bbl MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 92.485 bbl D182 554.912 lb 6.000 lb/bbl of base fluid D046 20.000 lb 0.200 lb/bbl of spacer D031 9526.843 lb 95.27 lb/bbl of spacer Lead Slurry Volume:350.5 bbl Density : 10.70 lb/gal Yield :4.52 ft3/sk Dry Phase Liquid Phase Blend: 81924 lb Design Mix Water 216.3 bbl 10.0 bbl LAS Design B809 81924.367 lb Fresh water 216.348 bbl 10.001 bbl Page 13 OP12-01.cfw;06-03-2010; LoadCase Surface Casing;Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 Scid be gel String : 13.375 District : Prudhoe Bay,Alaska �"I Country : USA Loadcase : Surface Casing 12.0 ppg DeepCRETE Volume:62.5 bbl Density : 12.00 lb/gal Yield : 1.58 ft3/sk Dry Phase Liquid Phase Blend: 22201 lb Design Mix Water 26.7 bbl 10.0 bbl LAS Design 12.0 PPG Lit 22200.832 lb Fresh water 26.288 bbl 9.862 bbl D047 4.440 gal 1.666 gal 0.020 gal/sk blend D185 11.100 gal 4.164 gal 0.050 gal/sk blend Page 14 OP12-01 cfw;06-03-2010; loadCase Surface Casing:Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 IllrtlliMbergell String : 13.375 District : Prudhoe Bay,Alaska "!YY{{1I 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 v MJDPUSHN —Mud .s°"`"- — Tail Slurry 0 Lead Slurry �,' ~ e CO CO O a in - o_ a E CO N N g N D_ j C ,:t _ v Li. S N r'n w A Vi 1 CO r .b i 1 r 3 I ■ i 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 Flow Rate (bbl/min) E.-. O ■Mud Bingham:PV=12.000 cP Ty=7.00 Ibf/100ft2 " MIAJRJSH II Bingham:R/=16.000 cP Ty=12.00lbf/100ft2 3 Lead Slurry Herschel:k =4.06E-2 bf.s^nlf12 n =0.345 Ty=0.03 Ibf/100112 IIITail Slurry Bingham R/=81.518 cP Ty=10.51 Ibf/100ft2 'Mark of Schlumberger YY■IInillePP Page 15 OP12-01.cfw:06-03-2010; loadCase Surface Casing;Version wcs-cem460_14 Schlumberger Ce m CA D E*well cementing recommendation for 9-5/8" Intermediate Casing Operator : Eni Petroleum Well : OP12-01 Country : USA Field : Oliktok Point State : Alaska Prepared for : Mr.Jason Brink Location : Nabors 245E Proposal No. : Draftvl Service Point : Prudhoe Bay,Alaska Date Prepared : 6-2-2010 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Tony Stafford Phone : 907-273-1700 E-Mail Address : tstafford©slb.com O t?�GN t� ) C FL GATE 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 : OP12-01 S 1E111211E) String : 9-5/8 District : Prudhoe Bay,Alaska �j! 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 : 5330.0 ft BHST : 85 degF Bit Size : 12 1/4 in ft (x 1000) psi 0 F1ac 25 Pore Permafrost CD . . . . . . A • `Shale-- e. — — Well Lithology Formation Press. Page 2 OP12-01.cfw;06-03-2010: LoadCase 9-5/9Intennediate Casing(a);Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 SIlinkerger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a1 Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2430.0 13 3/8 68.0 12.415 Landing Collar MD : 5250.0 ft Casing/liner Shoe MD : 5330.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 5330.0 9 5/8 40.0 47.0 8.681 L-80 4760 6870 BTCM Page 3 OP12-01.ciw;06-03-2010: LoadCase 9-5/0 Intermediate Casing(a);Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 Schieiberger String : 9-5/8 District : Prudhoe Bay,Alaska 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 : 463.2 bbl (including excess) Max. Deviation Angle : 73 deg Max. DLS :4.510 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 0.000 100.0 100.0 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 1427.9 1353.2 37.5 359.7 3.506 1500.0 1410.2 37.8 359.7 0.500 1600.0 1488.9 38.3 359.7 0.500 1700.0 1567.1 38.8 359.7 0.500 1800.0 16441 39.3 359.7 0.500 1900.0 1721.8 39.8 359.7 0.500 2000.0 1798.3 40.3 359.7 0.500 2072.2 1853.2 40.7 359.7 0.498 2100.0 1874.0 42.0 359.8 4.510 2200.0 1945.7 46.4 0.2 4.497 2300.0 2011.7 50.9 0.5 4.497 2400.0 2071.6 55.4 0.8 4.506 2500.0 2125.1 59.9 1.1 4.495 2600.0 2171.8 64.4 1.3 4.505 2700.0 2211.4 68.9 1.5 4.495 2797.8 2243.0 73.3 1.7 4.502 2800.0 2243.7 73.3 1.7 0.000 2900.0 2272.4 73.3 1.7 0.000 3000.0 2301.1 73.3 1.7 0.000 3100.0 2329.8 73.3 1.7 0.000 3200.0 2358.5 73.3 1.7 0.000 3300.0 2387.3 73.3 1.7 0.000 3400.0 2416.0 73.3 1.7 0.000 3500.0 2444.7 73.3 1.7 0.000 3600.0 2473.4 73.3 1.7 0.000 3700.0 2502.1 73.3 1.7 0.000 3800.0 2530.9 73.3 1.7 0.000 3900.0 2559.6 73.3 1.7 0.000 4000.0 2588.3 73.3 1.7 0.000 4100.0 2617.0 73.3 1.7 0.000 4200.0 2645.7 73.3 1.7 0.000 4300.0 2674.5 73.3 1.7 0.000 4400.0 2703.2 73.3 1.7 0.000 Page 4 OP12-01.cfw,06-03-2010 LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 Schlinkrier 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) 4500.0 2731.9 73.3 1.7 0.000 4600.0 2760.6 73.3 1.7 0.000 4700.0 2789.3 73.3 1.7 0.000 4800.0 2818.0 73.3 1.7 0.000 4900.0 2846.8 73.3 1.7 0.000 5000.0 2875.5 73.3 1.7 0.000 5100.0 2904.2 73.3 1.7 0.000 5200.0 2932.9 73.3 1.7 0.000 5300.0 2961.6 73.3 1.7 0.000 5330.0 2970.3 73.3 1.7 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 120.0 11.50 8.30 Permafrost Sandstone 1900.0 12.00 8.30 Permafrost Sandstone 2430.0 12.40 8.30 Shale 5330.0 14.00 8.30 Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (deg F) (degF/100ft) 0.0 0.0 20 0.0 1900.0 1721.8 32 0.7 2430.0 2088.4 50 1.4 5330.0 2970.3 85 2.2 Page 5 OP12-01.cfw;06-03-2010; LoadCase 9-5/8 Intermediate Casing lal;Version wcs-cem460_14 Client : Eni Petroleum Well : 0P12-01 Sehlim�rger String : 9-5/8 District : Prudhoe Bay,Alaska 1 Country : USA Loadcase : 9-5/8 Intermediate Casing(a) ft degF (x 1000)ft 0 1 60 90 I 2 3 4 Geoth.Profile —Hori.Depart. _ 1 0 C (N C y t CD • 0 O x o o ,1 CV o v CV CO 0 N o pj - Temperature Hori. Departure Section 2: fluid sequence Job Objectives: Zonal Isolation,TOC @ 4,125 Original fluid Mud 9.50 lb/gal Pv:20.038 cP Ty:20.59 Ibf/100ft2 Displacement Volume 384.3 bbl Total Volume 544.2 bbl TOC 4125.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 1003.9 3121.1 10.50 Pv:36.000 cP Ty:20.00 Ibf/100ft2 DeepCRETE 89.9 1205.0 4125.0 12.50 k:3.90E-3 lbf.s^n/ft2 n:0.911 Ty:11.77)bf/100ft2 Mud 384.3 0.0 9.50 Pv:20.038 cP Ty:20.59 lbf/100ft2 Page 6 OP12-01.cfw;06-03-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460-_14 Client : Eni Petroleum Well : OP12-01 Schlu 111borge1 String : 9-5/8 District : Prudhoe Bay,Alaska y Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Static Security Checks: Frac 315 psi at 2430.0 ft Pore 130 psi at 2430.0 ft Collapse 4552 psi at 5250.0 ft Burst 6870 psi at 0.0 ft Csg.Pump out 57 ton ft (x 1000) psi 0 2.5 I- Hydrostatic -I Frac Pore CD \\ '\\ cti � ~ q t t1 - 0 o- 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 II 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 89.9 18.0 89.9 80 9-Start Cement Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.5 360.0 42.4 360.0 80 19-Start Displacement Mud 3.0 24.3 8.1 384.3 80 21-Bump Top Plug Total 01:32 544.2 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 222 psi at 2430.0 ft Pore 130 psi at 2430.0 ft Collapse 4552 psi at 5250.0 ft Burst 6590 psi at 0.0 ft Page 7 OP12-01.cfw:06-03-2010: LoadCase 9-5/8 Intermediate Casing ial:Version wcs-cem460_1 4 Client : Eni Petroleum Well : OP12-01 SchIimberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing la) Temperature Results BHCT 83 degF Simulated Max HCT 85 degF Simulated BHCT 61 degF Max HCT Depth 5330.0 ft CT at TOC 60 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures: At Time 1 (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 71 degF Bottom Hole (degF) (degF) 85 degF o Acquired Pressure c, r/ Calc.WHP 0 20 40 60 80 100 Time (min) Fluids at 5330 ft ▪ 0 CD -Acquired 0 Out -- -----_ ----- ▪ —Acquired 0 In -0 0 Out — -t--— -1 (,, • CC 1 i • 0 0 20 40 60 80 100 Time (min) Page 8 OP12-01.cfw;06-03-2010: LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 SChliffIkrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) * CemCADE Client : Eni Petroleum Well :OP12-01 String :9-5/8"Intermediate Casing District : Prudhoe Bay,Alaska Country : USA Depth= 5330 ft _ ,�, Depth= 2430 ft Li, -Frac !� -Fbre I 1. .Fore --°•— Hydrostatic O —Hydrostatic Csi st • --- Dynanic I �—Dynamic LoI CO 0 _co.—] 8 To tT t71 3 > 7 w to I � �.�j O a ao � r Q LJ J I _ j Quo r. 1 o_ i oil co R 0 0 --4 i ad =r— r--T—T A 0 25 50 75 100 0 20 40 60 80 100 3 Time(min) lime(min) o Total Depth = 5330.0 ft Top of Cement= 4125.0 ft *Mark of Schlumberger Seldliliktilill Page 9 OP12-01.cfw;06-03-2010; LoadCase 9-5/8 Intermediate Casing la);Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 Sthillnibliger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 4: centralizer placement Top of centralization :4125.0 ft Bottom Cent. MD :5310.0 ft Casing Shoe :5330.0 ft NB of Cent. Used :30 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 5330.0 30 1/1 NW-TR-9 5/8-6-TR 3A W090 61.5 4150.0 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-9 5/8-6-TR W090 9 5/8 12.850 11.591 No Hannover 11.625 775.59 5626.97 3A (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 1 OD specifications ft 0 it A 0 60 80 100 Between Cent. t 1 1 -4-Pt Cent. 0 cv - O (0_ Pipe Standoff Page 10 0P12-01.ccfw;06-03-2010; loadCase 9-5/8 Intermediate Casing lal,Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 Schinlberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) * CemCADE Client : Eni Petroleum Well :OP12-01 String :9-5/8"Intermediate Casing District : Prudhoe Bay,Alaska Country : USA ft ton 0 0 10 20 30 ` 40 50 60 70 80 90 100 110 I—Hooldoad Up may, I- t' 1 — — Hooldoad Down - 1 -- - - Weight 1 — Rag Force \ 1 - \ I \ I �\ •1_ 1 -i I \ I \ I \ 3 1 I \ > 1 \ 1 \ rn \ I 1 g- \\ € \ \ \ . ,2',, O o O "25 Running Forces s it o Friction Factor=0.3 Total Depth = 5330.0 ft Top of Cement= 4125.0 ft 'Mark of Schlumberger SCh'' IlPr Page 11 OP12-01.cfw:06-03-2010, LoadCase 9-5/8 Intermediate Casing(a):Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 Schlumhurgur String : 9-5/8 District Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 5: WELLCLEAN II Simulator ft O, 71 90 100 Std Betty. Cent, - --- Cement Coverage O 0 0-- CV O O O- I O - O O CD- Cement Coverage Risk Mud on the Wall Fluids Concentrations 4 2 4200 4200 4200 4300 x300 4300 ' 4300 4400 4400 4400 4400 x500- 4500 4500 4500 -- 4600 4600 4600- 4600 -- ti. 4700- 4 700 — 4700 :x 4700 -' n 4800 4800 a • 4800- 4800 • 0 4900 4900 ° 4900 4900 ° 5000 5000 5000- 5000 5100 1 5100 5100- 5100 5700 5200 5200- 5200 5300 5500 5300- 5500 • 3 • • 3 • Tv o- 9 O t 2 2 Mud 0 High ® Low 11 DeepCRETE I I Medium I I None I I MUDPUSH II Page 12 0P12-01.ctw;06-03.2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 Schlifiteger 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 :9.50 lb/gal Rheo. Model : BINGHAM Pv :20.038 cP At temp. : 80 degF Ty :20.59 Ibf/100ft2 Gel Strength :(lbf/100ft2) MUD Mud Type :WBM Job volume :384.3 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 :36.000 cP At temp. :80 degF Ty :20.00 Ibf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :70.0 bbl DeepCRETE DESIGN Fluid No:7 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k :3.90E-3 lbf.s^n/ft2 At temp. :80 degF n :0.911 Ty : 11.77 lbf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.5 ppg Lit Mix Fluid :5.175 gal/sk Job volume :89.9 bbl Dry Density : 1.91 SG Yield : 1.54 ft3/sk Quantity :328.74 sk Sack Weight : 100 lb Solid Fraction :54.9% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.105 gal/sk Additives Code Conc. Function D167 0.250%BWOB Fluid loss D046 0.200%BWOB Antifoam D185 0.060 gal/sk blend Dispers. LT D110 0.010 gal/sk blend Retarder Page 13 OP12-01.c(w;06-03-2010; loadCase 9-5/8 Intermediate Casing(a),Version wcs-cem460_14 Client : Eni Petroleum Well : OP12-01 Seklimberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 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 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 89.9 18.0 89.9 9-Start Cement Slurry Pause 0.0 0.0 5.0 0.0 18-Drop Top Plug Mud 8.5 360.0 42.4 360.0 19-Start Displacement Mud 3.0 24.3 8.1 384.3 21-Bump Top Plug Total Pumping Time : 01:32 hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats TOTAL MATERIAL REQUIREMENTS Dead Volumes Mix Water Requirements : Fresh water 104 bbl MIXING PREPARATION MUDPUSH II Volume :70.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 63.747 bbl D182 382.481 lb 6.000 lb/bbl of base fluid D046 12.749 lb 0.200 lb/bbl of base fluid D031 8198.954 lb 117.13 lb/bbl of spacer DeepCRETE Volume:89.9 bbl Density : 12.50 lb/gal Yield : 1.54 ft3/sk Dry Phase Liquid Phase Blend: (lb) Design Mix Water 40.5 bbl 10.0 bbl LAS Design 12.5 ppg Lit 32873.578 lb Fresh water 39.956 bbl 9.866 bbl D167 82.184 lb 0.250%BWOB D185 19.724 gal 4.870 gal 0.060 gal/sk blend D046 65.747 lb 0.200%BWOB D110 3.287 gal 0.812 gal 0.010 gal/sk blend Page 14 OP12-01.cfw,06-03-2010; LoadCase 9-518 Intermediate Casing(a);Version wcscem460_14 Client : Eni Petroleum Well : OP12-01 Schimberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) * CemCADE Client : Eni Petroleum Well :OP12-01 String : 9-5/8"Intermediate Casing District : Prudhoe Bay,Alaska Country : USA Annulus ID:9.625 in-OD: 12.250 in co co IVIJDPUSH II —Mid to _—Dp CRETE " - f",. CD O O a O NI.— V to Vs a m to o � y N o — ) C E -4- d, M U co o M • i I I 1 1 3.9 4.2 4.5 4.8 5.1 5.4 5.7 6.0 6.3 6.6 6.9 7.2 7.5 7.8 8.1 Flow Rate (bbl/min) s iz o III Mud Bingham R/=20.038 cP Ty=20.59 Ibf/100ft2 2 MJDRJSH II Bingham Pt./=36.000 cP Ty=20.00 Ibf/100ft2 IIIDeept BETE Herschel:k =3.90E-31bf.s^n/ft2 n =0.911 Ty=11.77 Ibf/100ft2 "Mark of Schlumberger SikIuePpr Page 15 OP12-01.cfw;06-03-2010; loadCase 9-5/B Intermediate Casing(a):Version wcs-cem460_14 S P E O IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. Eni EUP Division REVISION STAP-P-1-M-6140 0 (1 1 ! I I 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Metric units EMW = P x 10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight(kg/I). S P E O IDENTIFICATION CODE PAG 207 OF 338 ENI S.p.A. Eni E&P Division REVISION STAP-P-1-M-6140 0 11 1 1 1 1 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance,the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT)or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. S P E O IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. En E&P Division REVISION STAP-P-1-M-6140 0 11 1 [ 1 1 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of 'Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also,the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. ENI S.p.A. S P E O IDENTIFICATION CODE PAG 209 OF 338 En6 E&P Division REVISION STAP-P-1-M-6140 0 1 LEAK-OFF TEST REPORT Report N° Date: WELL NAME: WELL CODE- f CONTRACTOR: RIG NAME: RIG CODE Open hole depth(m): 825 Mud TWe: FWGELS Rigt}pe: J.UPs Hole Dameter(in). 12'14 Weight(KgA): 1.3 R.K.P.elevation(m): 26 Last Cog.Shoe(m): 797 Marsh Uscosity(sec/Ot) 44 Water Depth(m) 24 Cog.diameter(in): 13"318 P.V.(eps): 19 Pumps: 12-P.160 Grade: J-55 '1.P.(1bl100 ite): 5 Liners(in). 6.5" Weight Obi) 61 Gels0b/100 t': 2t8 flow Rate(bpl): 0.25 Max.Burst pres(psi): 3103 W.L(cc/30 min): 10.5 Litholog y Shale Expected EMW 1.68 Ka/cm2I10 m Time Volume Pressure Time Volume Pressure Time Vdume Pressure (min) (bbl) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 050 100 95 2 480 3 0.75 200 10 2 470 4 100 300 10.5 2 463 5 125 400 11 2 465 6 150 500 11.5 2 460 7 1.75 570 12 2 446 8 20D 600 13 2 440 8 200 550 14 2 437 8.5 200 505 _ 15 2 435 _ Not e: Pumped with a consmnt low rate of(bbl) Volume pumped(bbl): Volume retumed(bbl): (psi) 1000 900 800 - sop pump F 700 _• . - 1 ` e 600 • • shut in curve — S 500 ' \* shut S U 400 ( - 18 minutes e 300 200 100 0 0,25 0,5 0,75 1 1,25 1,5 1,75 Z 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbp • I Time mins RESULTS (Press.,, +Press.,-o.)x101Depth=[(1.3 x 797/10)+(430 x 0.07)]x10/797=1.68(Kg/cm2fl0 m) Note: I Company Representatise Figure 15-1 - Leak-Off Test Report REV DATE BY CK APP DESCRIPTION REV DATE BY ...K APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 Oliktok OLIKTOK NA C414 Point 5 INTAKE DOCK \ ppP IN THIS S5 I MODULE Pig I. (5 SURVEY N c,-6.- - .ft� DS-3R O DEW LINE LIN– %,_— ,MODULES I G AREA', Ti 3N, R9E r DS-3Q _I 18 ):I 1 1�'' O f 5 SCALE: r �- 1" = 150' ` + r DS-30 19 eL-.) , 2,-)\ 2 S TP PAD VICINITY MAP 0 0 \ SCALE: 1" 1 Mile O °000 O-0 O.O\i O°-0� NO c\:,,,\\ \ 00-.0 crA x-D Qa�° OO�.p G \ � � 000°-0 0- N \ O°0 Oi9� \� ^ �0 s / O \ 2 OLIKTOK POINT PAD 0 ) CI% \ / \ \ SEE SHEET 3 FOR NOTES / \ / Existing Conductor ---' LOUNSBURY • Conductor Asbuilt this survey SURVEYORS � INC. R9 / AREA: MODULE: UNIT: ilZa - E n Pei roIIGtuons-ii OLIKTOK POINT PAD CONDUCTOR Bro. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 _ 1 __ NSK 6.80—d1 ( 1 OF 3 I 2 REV DATE BY CK APP DESCRIPTION REV DATE BY -X APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN AK STATE PLANE (NAD83) LA11TUDE(N) LONGITUDE(W) SEC. LINE PAD 0.G. WELL NO. 'y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP-11 6,036,332.70 1,656,791.89 70°30'39.015" 149° 51'57.587" 2,052 1,519 12.1 4.0 OP-12 6,036,328.85 1,656,784.83 70°30'38.977" 149° 51'57.795" 2,056 1,526 12.2 4.0 OP03-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°52'01.645" 2,123 1,654 12.2 3.2 OP18 6,036,257.62 1,656,650.62 70°30'38.279" 149°52'01.753" 2,127 1,681 12.2 3.1 OP19 6,036,250.09 1,656,636.50 70°30'38.205" 149°52'02.170" 2,134 1,675 12.2 2.5 OP20 6,036,246,31 1,656,629.41 70°30'38.168" 149°52'02.379" 2,138 1,682 12.2 2.2 OP21 6,036,242.57 1,656,622.39 70°30'38.132" 149°52'02.586" 2,141 1,689 12.2 1.9 OP22 6,036,238.82 1,656,615.39 70°30'38.095" 149°52'02.793" 2,145 1,696 12.2 1.7 OP23 6,036,235.05 1,656,608.27 70°30'38.058" 149°52'03.003" 2,149 1,703 12.2 1.5 OP24 6,036,231.36 1,656,601.27 70°30'38.022" 149°52'03.209" 2,153 1,710 12.2 1.3 • DISPOSAL WELLS • AK STATE PLANE (NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD 0.G. WELL NO. 'y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP25 6,036,004.35 1,656,510.91 70°30'35.791" 149°52'05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70°30'35.867" 149°52'05.456" 2,372 1,787 12.2 -2.7 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: Eza Cno '� eZ��D�Ie��r WELL CONDUCTOR D In ASBUILT LOCATIONS CAD LK680D1 10/9f 08 DRAWING NO: NSK 6.80-d1 PART: REV: 2 OF 3 2 REV DATE BY CK APP DESCRIPTION REV DATE BY .:K APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductos 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. SEE LOUNSBURY DOCUMENT L-2539 FOR NAD27 INFORMATION. • SURVEYOR'S CERTIFICATE h •; �♦♦♦ I HEREBY CER77FY THAT I AM PROPERLY • I REGISTERED AND LICENSED TO PRAC77CE •,.. ... LAND SURVEYING IN THE STATE OF 0 7G ALASKA AND THAT THIS PLAT REPRESENTS ♦ A SURVEY DONE BY ME OR UNDER MY ♦♦sr�':,... LS-803 i DIRECT SUPERVISION AND 7HAT ALL ♦ CFO ''11413 LS-813/5 pc'i CORRECT T ASAOFO DECEMBER 23, 2008. '',44 MIND-.44 • LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: tza P nu &tIroO IIkvJII nR WELL CONDUCTOR PAD Broil ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80—di 3 OF 3 2 3800 Centerpoint Drive.Suite 300 / l Anchorage,Alaska 99503 petroleum (907)865-3300 , Cr t JUN 222010 Mutt, Oft&Cu Carfg. G rrmission Anottrave June 22, 2010 Stephen Davies Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Request for Well Spacing Exception Nikaitchuq Unit —Well OP12-01 Dear Steve: Eni US Operating Co. ("Eni") has previously applied for a Permit to Drill the subject well and as of today's date, submitted its Well Spacing Exception request for the same well. As we discussed, Eni's latest well has drilled (progressed) much quicker than anticipated and we will be ready to commence the drilling our next well, OP12-01 within the next two weeks. In order to avoid any rig stand-by charges or working on another well out of sequence waiting for the Well Spacing Exception to be granted, Eni respectfully request from the AOGCC permission to drill (not produce) the OP12-01 well prior to receiving the spacing exception. At your earliest convenience, please let me know if it will be possible for Eni to commence drilling operations on Well OP12-01. Your consideration of this request is greatly appreciated. Sincerely, Robert A. Province Land Manager-Alaska - 1 - Ico o T.CO .1■11111•11•11I 1 tl a 1-... IFFer I _ 1----_i ..... , .. .„, \ N I --. \ \,..,.. Par) ce‘ Ian I—cp cs,,, '4 ("41) 7.I I ........... . . .. C1---.........._,_ ',„..• ,e.• . :':- \:::',‘,:i.:."■.•••\\. \\,..‘■"\-;,\,\,'',.,\•:\•,..,•\;.\;\V-,\.<,...NN,.\ . •-,:',,\,'\\.,,. .., '''..\l':"\Y\.\\,' \''..-\\V:\■\\\\\\.\\-\\"■'\'`\t`:\:\\\\ ''''.- u) .,, __._______________ r- •• .71= . . ..., •• • • :-...■..s.\.\.,,,,\\:,:\3:\:\•,\\,, .. , ..,....,.\:,. coiik% \ sNIAs , .\*01 , ..7) 4:7:?'3 \\\\\, .,\S..\\\N\\\\ 1:11..C2' \S ..\'\ \-‘‘\ \\\ \':' t".1 :': C‘at gt an , /..•, ,,''\' \\\$'.\. \\ - \\\ \--- . 1 7 It... '''''''' . '.' ''' ' ' - -.-\\,, \\\.',':' ' _,--4- CD CL 7.; 0''gi CNI \\.'..‘' . '' '.. ? '‘‘'. lan \ 0-------‘-- •■1.....i ..s. 0 0 c::. -- --.-' ______ _ •:',:,:: . 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E o CD c O X c4 O W O L O o N— LO M Cr Q N. , • Q a O O W o • O O o O o 0 o O o O o v' ° 0 ° 0 0 O 0 O o ° o rn co o co CD LO LO LO TRANSMITTAL/LETTER CHECKLIST WELL NAME A.`,✓ -t C L - UP7Z PTD# %6 VDevelopment Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: /Lett lc"C t A _Id . a 6l- / POOL: Ci 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 &_•5.pliance with 20 AAC EXCEPTION 25.055. Approval to perforate a sroduc= / in'ect is contingent upon issuance of a conservatio approving a spacing exception. assumes 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 u'[J 73 c N N C: as a. c a co TD- c c aa) , , , , , , , , , , , , , , , , , , 3 0 as • c O. w -; , , • 7 , , ; ; ; . ; a ; , UI E O E. 0 � $ CO' c N• M c M ..: , L O CN m. _ : .. _ N y N. N °, o; , , �'; 3, Not 0 V CO m N 0_ °' ; ; , D; �, , , , t? , , 3 O, �� o! �; , w-• m aai t in, �i .0' '. LWLI,. .L.' 0 , D, , „O_,,, N' N� ' m' C O c O ,. Z o, _ a o: a: O' oy , , , c N 0 II c �' 4 0 in 10 Y 0D M: O F C' �' p y' C ty/) 3 ° L W °:p c Z-I J, N' ° U, U 3, co. O' H' °, Z' z LLI Tr r U C Q , 0' W, 3. ' X. OL C. -O ta, �� p. 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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. RECEIVED Au G 2 7 2010 1/11101k Alaska MI&Gas Cam Com ission ena it it rP°etlr©lletuill l Anchorage FINAL WELL REPORT MUDLOGGING DATA NIKAITCHUQ OP12-01 OLIKTOK POINT, ALASKA Tit Provided by: CANRIG Approved by: Andrew Buchanan Compiled by: John Lundy Tollef Winslow Ralph Winkelman Distribution:August 23, 2010 Date: August 3, 2010 0( V SC)lo9 NIKAITCHUQ OP12-01 _esti_ 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 8 3.4 Lithostratigraphy 9 3.5 Mudlog Summary 10 3.6 Connection Gases 30 3.7 Trip (Wiper) Gases 30 3.8 Sampling Program/Sample Dispatch 31 3.9 Approved Sample Plan OP12-01 32 4 PRESSURE/FORMATION STRENGTH DATA 33 4.1 Pore Pressure Gradient Evaluation 33 4.2 Quantitative Methods 33 5 DRILLING DATA 34 5.1 Survey Data 34 5.2 Bit Record 40 5.3 Mud Record 41 6 DAILY REPORTS 43 Enclosures 2"/100' Formation Log (MD/TVD) 2"/100' LWD Combo Log (MD/TVD) 2"/100'Gas Ratio Log (MD/TVD) 2"/100' Drilling Dynamics Log (MD&TVD) Show Reports Final Data CD 1 CANRIG NIKAITCHUQ OP12-01 eni _ r 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Downtime Parameter Equipment Type/Position Comments (hours) Casing Pressure Cable to 1502 transducer for BOP tests only. 0 Computer—Drill Floor Monitor Azonics 0 Computer—Pit Monitor Azonics 0 Computer for Company Man, Rigwatch Remote(HP Compaq) 0 camp Computer for Company Man/ Rigwatch Remote (HP Compaq) Toolpusher, office (wireless) 0 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 Rigwatch Remote(all HP Compaq) 0 QGM Agitator Clean/repair/ Ditch gas 2(Mounted in possum belly) adjust gas trap Flame Ionization Detector(FID)Total and Gas and Chromatography. chromatorgraph. 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 0 Pump stroke counters(3) 2 proximity sensors 0 Rate of penetration Crown Fast Sheave proximity sensors 0 RPM PLC feed 0 Torque PLC feed 0 Wits In (LWD Data) LWD Computer to Rigwatch Master Computer 0 2 CANRIG NIKAITCHUQ OP1 2-01 eni 1.2 Crew Unit Type Arctic Unit Number : ML059 Years Days Mudloggers „1 *2 Sample Catchers Years Days Technician Days John Lundy 18 10 Dean Kekuaulua 2 9 Allen Williams 2 Tollef Winslow 2 23 Doug Acker 1 5 Howard Lamp 2 Ralph Winkelman 19 14 Zach Mester 1 14 Omar Hinostroza 2 19 `1 Years experience as Mudlogger *2 Days at wellsite between spud and completion at a total depth of 12,860 feet. Two loggers remained at the rig until completion. 3 CANRIG Iiiit NIKAITCHUQ OP12-01 eni 2 WELL DETAILS 2.1 Well Summary I Well: Nikaitchuq OP08-04 API Index#: 50-029-23426-00-00 3,182.4 FSL 1,604.3 FEL Field: Nikaitchuq Surface Co-Ordinates: S5 T13N R9E UM Borough: North Slope Primary Targets: Schrader Bluff; OA Sand State: Alaska Primary Target Depth: 12710' MD, -3528'TVDSS Rig Name/Type: Nabors 245E/Arctic Triple TD Depth: 12860'MD/-3561.4'TVDSS Spud Date: July 16, 2010 Ground Elevation: 12.2' MSL TD Date: August 3, 2010 RT Elevation: 54.58' RTE Days Drilling: 19 TD Formation: Schrader Bluff OA Sand Classification: , Producer 2.2 Hole Data The Borehole extends from the surface to a TD at 12860'MD/-35614.4' TVDSS and has three sections designated by hole diameter: the 16" Surface Borehole; the 12W Intermediate Borehole; and the 8'/" Production Lateral Borehole(Lateral Borehole). The well was designed as a production well. FIT Hole Maximum Depth Mud Shoe Depth LOT Section TD Dev. Casing/ Weight (PPM Formation g (°inc) Liner MD TVD (ppg) MD TVD (ft) (ft) (ft) (ft) Conductor 120 120 Recent 9.3 0 20" casing 120 120 N/A 16"Surface Borehole 2430 2178.3 Ugnu 9.3 48.7 13%"casing 2421 2175 13.7 12W 5527 3619.9 OA Sand 9.3 , 84.15 9%"casing 5510' 3618.2 12.11 8%" 12860 OA Sand 8.8 , 94.94 4 1/2" liner 4 CANRIG NIKAITCHUQ OP12-01 eni 3 GEOLOGICAL INFORMATION 3.1 Hole Information Additional Comments: The well was spudded on the 16th of July 2010, entering a pre set conductor pipe at a depth of 120', and 16" hole was drilled to a depth of 2430'. 13 3/8"surface casing was set at 2420.99' MD/2174.76'ND.. The float equipment and shoe were drilled out and new hole was drilled to 2370'.A Leak Off Test(LOT) was performed to 13.7 ppg The intermediate section was drilled with a hole diameter of 12.25"to 5527'. 9 5/8" Casing was run into the hole without difficulty and set at 5510'.After drilling out to 5547'a Leak Off Test(LOT) result was 12.11 ppg equivalent mud weight. The hole was completed drilling 8.5" hole to a depth of 12860"MD. For additional detail, see daily summary below. 5 CANRIG NIKAITCHUQ OP1 2-01 eni 3.2 Daily Activity Summary 7/15/2010; Rig up Canrig unit 59. 7/16/2010; Make up spud mud, drill out conductor with dumb iron, circulate clean, make up BHA, drill out. 7/17/2010; Drill ahead while building angle. 7/18/2010; Drill ahead. 7/19/2010; Drill to 2414', ream/wash from 2381'-2331, drill to 2340'td, circulate and condition mud, pump high vis sweep,circulate bottoms up 4x,short trip to 691, Run into hole to 2430,circulate and condition mud, pump high vis sweep,circulate bottoms up 4x,trip out of hole, lay down BHA, rig up to run 13 3/8"casing, run 13 3/8"casing 7/20/2010; Run 13 3/8"casing to 2420',circulate and condition, cbu, pump cement, rig down cement/casing tools, clean mud system, nipple down riser, install wellheads, nipple up bops. 7/21/2010;Nipple up bops, rig up test plug,test bops,bops leak, lay down test tool,nipple down bops change out leaking seal ring, nipple up bops, rig up test tool, test bops, lay down test tool, pick up bha, circulate/ condition/fill pipe, trip in hole, pressure test casing/shoe to 2500 psi for 30 min. 7/22/2010; Drill out plug, drill out cement, displace drilling fluid with Isnd, fit emw 13.7, drill ahead. 7/23/2010; Rotary drill from 2930'to 4345', 2 -20k wob 7/24/2010; Rotary drill from 4345'to 5520'with 12k wob 7/25/2010; Rotary drill from 5520'to 5527',circulate and condition mud,trip out of hole, lay down bha,pick up bha with bull nose hole opener,trip in hole to 2400',circulate and condition/bottoms up,cut and slip drill lone, trip in hole. 7/26/2010;Trip in hole to 4600',circulate and condition four bottoms up,trip out of hole,lay down bha,change rams, test bops rig up to run casing, run case to 700', fix skate. 7/27/2010; Run 9 5/8" casing to 5510', circulate and condition mud; pump cement; rig down casing tools; change rams; test bops; clean mud system/displace mud, trip in hole with hwdp. 7/28/2010;Rih w/5"dp,pooh 5"dp and stand back in derrick,circulate and condition mud to 8.5 ppg, p/u m/u bh#5. 7/29/2010; Rick up bha, load nukes, pick up drill pipe,trip in hole, circulate and condition mud, pressure test casing/shoe @ 3000 psi for 30 minutes,test good, drill cement/plugs, drill from 5527'to 5547',fit/lot test= 12.11 emw, drill from 5527'to 6110. 7/30/2010; Rotary drill from 6050'to 7080'w/2k-6k wob, rotary drill from 7080'-7700'w/1k-10k wob, rotary drill from 7700'to 8115'w/2k- 11k wob. 6 CANRIG NIKAITCHUQ OP1 2-01 enl 7/31/2010; Rotary drill to 8796'; back ream from 8795'to 5729'; trip in hole to 8795' rotary drill from 8796'to 9178'with 2k-6k wob. 8/01/2010; Rotary drill from 9178'to 10615', 2k- 12k wob, circulate and condition, pump weighted sweep; rotary drill from 10615'to 10712'2k-5k wob. 8/02/2010; Rotary drill from 10712'to 11190'2k-8k wob, rotary drill from 11190'to 11620'2k-8 wob, rotary drill from 11620'to 11900'2k- 15k wob, rotary drill from 11190'to12242'4k- 16k wob. 8/03/2010; Rotary drill from 11241'to 12860'td, 2k-15k wob, circulate and condition drilling fluid, circulate bottoms up, pump sweep, back ream from 12860'to 8600'. 8/04/2010; Circulate and condition mud,circulate bottoms up twice @ 8475'; back ream while washing from 8475'to 5670'; circulate and condition mud; bottoms up thrice, pump weighted sweep; service top drive/cut slip drill line/service blocks;trip in hole from 5488'to 12785'; ream/wash down from 12785'to 12860';circulate and condition hole; displace to water base. 8/05/2010; Finish displacement of naf drilling fluid with brine; trip out of hole, to 5460'; circulate and condition mud; trip out of hole; lay down bha; remove/install wear bushing; rig up bop test plug; test bops. 8/06/2010; Test bops; remove/install wear bushing;pull test plug; lay down test tools/lay down drill pipe; p/u 27 joints heavy weight drill pipe; pick up/rig up liner running equipment; run 5 1/2"slotted liner. 7 CANRIG NIKAITCHUQ OP12-01 ell 3.3 Target and Reference Well Correlation Points Surface OP12-01 Prognosis P03-P03PB1 OP-11 1 OP-12-PB01 OP26-DSPO2 MD TVDSS TVDSS TVDSS TVDSS TVDSS SV-4 717.7 -663.79 -657.7 -659.1 SV-3 970.2 -909.43 -907.6 -902.8 SV-2 1254.4 -1171.8 -1174.0 -1169.0 -1163.2 SV-1 1809.8 -1641.3 -1671.1 -1671.2 -1647.0 -1648.1 Permafrost Base 1900.0 -1725.0 -1722.1 -1726.8 -1724.3 Ugnu Top (UG4) 2210.6 -1964.2 -1984.8 -1984.8 -1931.5 -1957.2 13 3/8" SCP 2430.0 -2120.0 UG-2 Coal Bed Marker 2918.8 -2423.0 -2512.7 -2488.2 -2422.0 -2428.2 L Ugnu 4044.8 -3112.0 -3140.3 -3274.3 -3060.0 -3122.5 Schrader Bluff 4505.1 -3333.6 -3387.3 -3511.3 -3341.9 -3325.0 N Sand Top 4629.1 -3380.4 N Sand Bottom 4738.5 -3421.4 -3523.5 -3640.5 -3424.4 -3423.3 OA Sand Top 5101.0 -3520.2 -3789.6 -3518.2 -3536.4 0A2 5194.3 -3533.0 9 7/8" ICP 5244.3 -3537.7 Total Depth 12709.9 -3615.6 Final Top Picks: LWD tops and bases refer to provisional picks by the wellsite geologist. 8 CANRIG Iiiit NIKAITCHUQ OP12-01 en' s 3.4 Lithostratiaraphy ENI PROGNOSED LWD PICK FORMATION MD TVD/TVDSS MD TVD/TVDSS (ft) (ft) (ft) (ft) SV-4 717.7 -663.79 714.0 712.5/-657.87 SV-3 970.2 -909.43 973.0 964.7/-10.15 SV-2 1254.4 -1171.8 1251.5 1222.6/-1167.99 SV-1 1809.8 -1641.3 1794.0 1696.3/-1641.70 Permafrost Base 1900.0 -1725.0 1896.0 1784.2/-1729.66 Ugnu Top(UG4) 2210.6 -1964.2 2204.0 2026.8/-1972.24 13 3/8" SCP 2430.0 -2120.0 2421.0 2175.0/-2120.46 UG-2 Coal Bed Marker 2918.8 -2423.0 2939.0 2486.8/-2432.2 L Ugnu 4044.8 -3112.0 4041.0 3151.5/-3096.9 Schrader Bluff 4505.1 -3333.6 4446.5 3362.1/-3307.5 N Sand Top 4629.1 -3380.4 4663.5 3445.1/-3390.5 N Sand Bottom 4738.5 -3421.4 4781.0 3487.4/-3432.8 OA Sand Top 5101.0 -3520.2 5403.0 3607.1/-3552.5 0A2 5194.3 -3533.0 5566.0 3623.1/-3568.8 9 7/8" ICP 5244.3 -3537.7 5510 3618.0/-3563.4 Total Depth 12709.9 -3615.6 12860.0 3616/-3516.4 9 CANRIG NIKAITCHUQ OP12-01 eni r 3.5 Mudloq Summary The Permafrost section of the OP12-01 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. Permafrost Section; Recent/Quaternary Deposits-Surface to 1896.0' MD/-1729.66 TVDSS Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 1701.3 3.7 127.1 403 0 43.5 This interval extends from surface down to the top of the Ugnu at 2204.0' 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. SV=4-714.0' MD/-657.87 TVDSS SV=3-973.0' MD/-910.15 TVDSS Conglomerate Sand/Sand(1000'-1100')=grayish black to medium gray;sand is trimodal, pebble clasts, gravel and lower medium to upper medium;gravel/pebble exhibits sub-prismoidal to sub-discoidal sphericity while sand is spherical to sub-discoidal; all grains are sub-rounded to well rounded; sand is overall poorly sorted; unconsolidated sand; cement unknown; matrix unknown; grain supported; texturally sub-mature to mature;quartz is predominate grain;pyrite overgrowth visible on some conglomerate clasts,pyrite grains also present; porosity and permeability visually good; no oil indicators. Claystone(1050' -1140')= medium gray to light gray; soft; lumpy to clumpy consistency; clay is cohesive, adhesive and pliable;tenacity is flexible to elastic;fracture is earthy;cuttings habit is massive; luster is dull to waxy; texture is smooth to clayey; structure is massive; very fine black no oil indicators. Claystone(1140'-1170')=dark gray to medium dark gray in color; soft hardness;tenacity is stiff to elastic; fracture is earthy;massive cuttings habit;dull to waxy luster;texture is smooth to clayey structure massive;no oil indicators. Claystone(1170'-1200')=dark gray to medium dark gray in color;soft hardness;tenacity is stiff to elastic; fracture is earthy; massive cuttings habit;dull to waxy luster;texture is smooth to clayey structure massive;no oil indicators. SV=2—1251.5.0' MD/-1167.99 TVDSS Claystone(1200'-1260')=dark gray to medium dark gray in color; soft hardness;tenacity is stiff to elastic; fracture is earthy;massive cuttings habit;dull to waxy luster;texture is smooth to clayey structure massive; no oil indicators. Sand/Conglomeratic Sand(1260-1350)=medium dark to medium gray; moderately to poorly sorted;fine upper to fine lower and very fine upper predominate; locally abundant to very abundant medium and coarse with trace small pebble;finer material is angular to sub-angular clear to translucent white quartz;medium and 10 CANRIG NIKAITCHUQ OP12-01 eni coarse is slightly rounded medium gray to black lithic/mineral fragments; trace brown and light gray lithics; locally common pyrite; matrix supported in light to medium light gray clay; matrix is moderately cohesive/adhesive;tenacious;sticky;occurs as moderate to thin interbeds in the associated claystone;non to very slight trace calcareous. Conglomerate/Conglomeratic Sand(1350-1500)=medium to medium light gray; soft to dis-aggregated; poorly sorted; 3 to 6 mm pebbles and pebble fragments to coarse, medium,fine and very fine sand; coarser material consists of slightly rounded to occasionally well rounded medium to dark and light gray and brownish gray chert with occasional apparent obsidian and very dusky purple mottled andesite with common to abundant white to translucent white and clear quartz; finer material is almost exclusively angular to sub- angular translucent white to clear quartz; trace grayish blue, orange, brown and greenish gray grains; abundant pyrite as free masses and as overgrowth on pebbles and larger sand grains; trace pyritic white quartz;all in a matrix o light to medium light gray clay;interbedded with thin to moderate clays and occasional thin grain supported sands; non to trace calcareous; no oil indicators. Sand/Conglomeratic Sand (1500-1590) = medium dark to medium gray; soft to dis-aggregated; friable; sample collected as loose sand with minor grave occasionally with clay matrix; sub-angular to angular; fine lower to medium upper in the top of the zone,grading to medium lower with scattered 3 to 5 mm pebbles and occasional larger pebble;vertically sorted overall;salt and pepper appearance;locally pepper in salt;dark gray to gray brown lithic/mineral grains predominate in the upper zone;becomes more dominantly translucent white quartz with depth;trace brown,brownish gray and greenish gray liths;occasional pyrite;interbedded with this, clean light gray clays; very slightly calcareous; no oil indicators. Sand/Conglomeratic Sand (1590 - 1680) = medium dark to medium gray; soft to dis-aggregated; friable; sample collected as loose sand with minor grave occasionally with clay matrix; sub-angular to angular; medium lower in the top of the zone, grading to medium lower and coarse with scattered 3 to 5mm pebbles and occasional larger pebble; basal portion very conglomeratic; vertically sorted overall; salt and pepper appearance;locally pepper in salt;dark gray to gray brown lithic/mineral grains predominate in the upper zone; becomes more dominantly translucent white quartz with depth;trace brown,brownish gray and greenish gray lithics;occasional pyrite;interbedded with this,clean light gray clays;very slightly calcareous; no oil indicators. SV=1 —1794.0' MD/-1641.70 TVDSS Sand(1680-1800)=medium to medium dark gray;soft to dis-aggregated;friable in part;well to moderately well sorted; vertically sorted coarsening gradually with increasing depth; fine lower to very fine upper in the upper zone;grading to medium upper and coarse lower with scattered to abundant small pebbles in the base; translucent white to very light gray and clear quartz dominate the upper portion with common medium to dark gray lithics becoming dominant with depth; trace brown, brownish gray, light to medium olive, bluish gray, black and yellow lithic/mineral grains;trace pyrite and fine muscovite mica;apparently matrix supported with local zones of grain support; interbedded with thin light to medium light gray clay; clay masses impregnated with loose sand due to circulation/shaker action; very slightly calcareous; no oil indicators. Sand (1800 - 1920) = medium to medium dark gray; soft to dis-aggregated; friable in part; well to moderately well sorted; vertically sorted coarsening gradually with increasing depth; fine lower to very fine upper in the upper zone;grading to medium upper with scattered medium upper and coarse lower at the base; scattered pebbles; translucent white to very light gray and clear quartz dominate the upper portion with common medium to dark gray lithics becoming dominant with depth; trace brown, brownish gray, light to medium olive, bluish gray, black and yellow lithic/mineral grains; trace pyrite and fine muscovite mica; apparently matrix supported with local zones of grain support; interbedded with thin light to medium light gray clay;clay masses impregnated with loose sand due to circulation/shaker action;very slightly calcareous; no oil indicators. Claystone(1920' - 1980') = medium gray to medium light gray; hardness is soft; poorly indurated; clay is cohesive, adhesive and pliable; clumpy to lumpy consistency; tenacity is elastic to stiff; fracture is irregular; cuttings habit is massive; luster is dull to earthy; texture is silty to gritty; structure is unknown; sand grains 11 CANRIG NIKAITCHUQ OP12-01 eni entrained within clay; no oil indicators. Sand (1980' -2010')= olive gray to olive black with a salt and pepper appearance, heavier on the pepper; lower fine to upper very fine grains; spherical to sub-discoidal sphericity; sub-angular to sub-rounded roundness; moderately well to well sorted; unconsolidated sand; grain supported; texturally immature; compositionally mature;quartz is the predominate mineral with some chert;porosity and permeability visually good; no oil indicators. Clay (2010' - 2130') = medium gray to medium light gray; soft hardness; clay is cohesive and plasticy; consistency is lumpy to clumpy;elastic to flexible teancity; unknown fracture; massive cuttings habit; dull to earthy luster;silty to clayey texture;structure is indeterminate;quartz sand grains entrained with in clay, upper very fine to lower fine grained,some chert and amber colored grains;no other accessories;no oil indicators. Carbonaceous Shale (2130' -2190') = dark gray to black; hardness is firm friable to friable; moderately indurated; dense to brittle tenacity; hackly fractures; massive cuttings habit; luster is resinous to greasy; texture is smooth or matte; laminae bedding structure; laminae beds grade between dark carbonaceous material and lighter brown carbonaceous material;very slight outgassing observed in a new fracture; no oil. PEAKS Depth TG C1 C2 C3 C41 C4N C51 C5N 1273 29 5944 — 1430 80 16354 1482 178 34782 1568 239 49144 1710 155 29676 1831 403 80021 2018 75 15038 2136 99 17442 2174 106 15677 2350 _ 62 11998 Uqnu Top(UG4): 2204.0 MD/-1972.24' TVDSS Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 478.5 2.2 151.3 83 0 19.6 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. Sand/Sandstone(2430-2550)=medium t medium light gray;slight brownish secondary hue in part;soft to dis-consolidated;friable;well sorted;medium upper to medium lower and fine upper grain;sub-angular to very slightly rounded;translucent white to clear quartz predominates;common light to medium gray lithics;common slightly smokey quartz;trace bluish gray,greenish gray;orange and buff lithics/mineral grains; upper portion is matrix supported in light gray clay; below 2450 material is primarily grain supported some local matrix support by very light brownish clay;trace to 50%slight brown stain with slow greenish yellow cut fluorescence; residual cut is a grayish white. Carbonaceous Shale/Carbonaceous Clay(2550'-2610')=black to grayish black;carbonaceous shale RIG 12 CAN NIKAITCHUQ OP12-01 eni is firm friable,carbonaceous clay is soft;shale is poorly indurated,clay is non-indurated;shale brittle to dense tenacity,clay elastic to flexible;shale irregular fracture,clay no fracture;cuttings habit massive;luster resinous to dull; texture shale mottled, clay smooth to clayey; structure shale laminae, clay massive; carbonaceous material entrained within clay in laminations; no oil indicators. Sand (2610' -2730') = olive gray to medium dark gray; grains trend from lower coarse/lower medium to upper medium to upper fine as the interval increases; spherical to sub-discoidal; angular to sub-angular; unconsolidated sand; well to moderately well sorted; grain supported; texturally immature; compositionally sub-mature; grains are translucent and milky white quartz in equant amounts; also present is green lithics, chert and pyrite; pyrite at times can be very coarse grained, easily fracturable; porosity and permeability visually good. no oil indicators. Sand(2730'-2790')=olive gray to medium dark gray; lower medium to upper fine grained;sub-prismoidal to sub-discoidal sphericity;angular to sub-rounded rounding;well sorted;unconsolidated sand;grain supported; texturally immature; compositionally sub-mature; grains are translucent and milky white quartz in equant amounts; green lithics, chert, amber colored quartz and pyrite are also abundant; porosity and permeability visually good. no oil indicators. Sand(2790'-2920')=olive gray to medium dark gray; lower medium to upper fine grained;sub-prismoidal to sub-discoidal sphericity;angular to sub-rounded rounding;well sorted;unconsolidated sand;grain supported; texturally immature; compositionally sub-mature; grains are translucent and milky white quartz in equant amounts;green lithics,chert,amber colored quartz and pyrite are also abundant;many shell fragments visible around 2850'; porosity and permeability visually good; no oil indicators. Carbonaceous Shale(2920'-2940')=grayish black to black;firm friable hardness;poorly to poorly moderate induration; tenacity is brittle to dense; planar and irregular fracture; cuttings habit is massive; waxy to dull luster; texture is gritty; structure is composed of alternating black and reddish brown laminations of carbonaceous material; no outgassing observed; no oil indicators. Sand (2940' - 3030') = medium gray to medium light gray; upper medium to lower medium grained with occasional upper fine grains;sub-prismoidal to sub-discoidal sphericity;angular to sub-angular rounding;well sorted; unconsolidated sand; grain supported; texturally immature; compositionally sub-mature; translucent and milky white quartz with some smokey quartz; chert, green lithics and black carbonaceous material also present; porosity and permeability visually good; no oil indicators. Sand(3030' -3120')= light olive gray to olive gray to medium gray; lower fine to upper fine grading to upper fine to lower medium as the interval increases; spherical to sub-discoidal; angular to sub-angular rounding; well sorted; unconsolidated sand; grain supported; texturally immature; compositionally sub-mature; translucent and milky white quartz with a few amber quartz grains;-50%of quartz grains are pitted/impacted; green lithics, chert and pyrite present; pyrite is loose or as an overgrowth on quartz grains; porosity and permeability visually good; no oil indicators. Sand/Sandstone(3120'-3180')=olive gray to dark gray; lower medium to upper fine grained;spherical to sub-discoidal; angular t0 sub-rounded; well sorted; unconsolidated sand; sand grain supported; sandstone matrix supported; texturally immature; compositionally mature; translucent and milky white quartz grains; matrix siliceous; pyrite, chert, and green lithics present; pyrite growths join sand grains at times, also loose; porosity and permeability visually good; no oil indicators. Sand/Sandstone(3180-3360)= medium light to medium gray; sample collected as dis-aggregated loose sand with occasional hard angular well indurated siliceous sandstone flakes;friable in part; moderately well sorted; medium upper to medium lower and fine upper grain predominates; trace coarse; basal portion dominated by medium upper to coarse lower and occasional small chert pebbles/pebble fragments; sub angular to angular and sub spheroidal; 70 to 80% translucent white to clear colorless quartz and slightly smokey quartz; trace medium gray chert and light to medium gray lithics; trace bluish gray and olive lithic/mineral grains;scattered brick red grains;trace to common green stained quartz and small well rounded 13 CANRIG NIKAITCHUQ OP12-01 eni T glauconite;trace to common microcrystalline pyrite nodules;pyrite common as secondary cementing agent in lithics and inter grain cementation; trace carbonaceous shale/coal and claystone interbeds; moderately calcareous; trace dull gold mineral fluorescence; no oil indicators. Sand/Sandstone(3360-3480)=medium to medium light gray with a slight brownish secondary hue;sample recovered as soft clay matrix sandstone masses and loose dis-aggregated sand;common to abundant small, loosely consolidated fine grain sandstone fragments; friable in part;well sorted; fine upper to medium lower grain predominates;common very fine upper;trace medium upper;primarily matrix supported in light brownish gray, moderately tenacious clay; angular to sub-angular and sub-spheroidal; clear to translucent white and slightly smokey quartz pre-dominate; common to abundant light to medium gray lithics trace bluish gray and olive lithics; trace to scattered brick red angular jasper fragments; trace glauconite and glauconite stained quartz grains;common to locally abundant medium grain size microcrystalline pyrite masses;trace pyrite as a secondary cementing agent; interbedded with thin slightly sandy clays and silty/coaly carbonaceous shales; slightly calcareous primarily from point source effervescence; common dull to medium yellow mineral fluorescence; no odor, cut or stain. Siltstone/Claystone(3480-3540) = medium light to light brownish gray secondary hue; soft; clayey to silty slightly sandy texture;dull earthy to silky luster;moderately tenacious;moderately cohesive;slightly adhesive; slightly hydrophilic; contains trace to common very fine grain sand; occurs as thin interbeds within the associated sandstone; non to very slightly calcareous. Sand/Sandstone(3540-3720)=medium to medium light gray with a slight brownish secondary hue;sample recovered as loose sand in the top of the zone, becoming silty with depth; trace small hard well indurated sandstone flakes;friable; silty/clayey in part; moderately well sorted;fine upper to medium lower grain in the upper zone becoming uniformly medium upper with increasing depth; trace light brownish gray clay matrix supported sandstone; angular to sub-angular and sub-spheroidal; clear to translucent white and slightly smokey quartz predominate;abundant light to medium and dark gray lithics trace bluish gray and olive lithics; trace to scattered brick red angular jasper fragments;trace bark gray to black lithics/mafic mineral grains and coal fines; trace glauconite and glauconite stained quartz grains; common medium to coarse grain size microcrystalline pyrite masses; trace pyrite crystals on larger grain surfaces; interbedded with thin slightly sandy clays; slightly calcareous primarily from point source effervescence; trace coarse grain size off white very fine grain calcareous sandstone flakes;trace dull to medium yellow mineral fluorescence; no stain odor or cut. Sand/Sandstone(3720-3870)=medium to medium light gray with a slight brownish secondary hue;sample recovered as loose sand and soft sticky masses of silty sandstone siltstone and clay; friable in part; moderately well sorted medium lower to fine upper grain;common to locally abundant very fine lower to upper included in sandy siltstone interbeds; common to abundant light brownish gray silt/clay matrix sandstone; angular to sub-angular and sub-spheroidal;clear to translucent white and slightly smokey quartz predominate; abundant light to medium and dark gray lithics trace bluish gray and olive lithics;trace to scattered brick red angular jasper fragments;trace bark gray to black lithics/mafic mineral grains and coal fines;trace glauconite and glauconite stained quartz grains; common medium to coarse grain size microcrystalline pyrite masses; trace pyrite crystals on larger grain surfaces; interbedded with thin slightly sandy clays/siltstone and thin lignitic coal/carbonaceous shales; very slightly calcareous primarily from point source effervescence; trace dull to medium yellow mineral fluorescence; no stain odor or cut. Carbonaceous Shale(3900-3960)=very dark gray brown to black;very firm to firm; blocky to tabular large fragments;smaller fragments are angular to irregular to blocky;hackly in part;poorly developed lignitic to sub- bituminous coal;silty throughout; interbedded with thin carbonaceous shale and associated lithologies;trace included very fine mica; trace remnant wood characteristics; no conchoidal fracture or other hard coal characteristics noted;weak visible outgassing after 5 minutes. Sand (3960' -4020') = olive gray to light olive gray; lower fine to lower medium grained; spherical to sub- discoidal; angular to sub-rounded; well sorted; unconsolidated sand, sandstone poorly consolidated; grain supported; texturally immature; compositionally sub-mature; translucent and milky white quartz dominate; RIG 14 CAN NIKAITCHUQ OP12-01 eni chert, black lithics and pyrite also present; pyrite is loose or at times encrusts sand grains; porosity and permeability visually good; no oil indicators. Sand (4020' -4110') = grayish black to black with some olive gray; interval grades from upper fine/lower medium to lower medium/lower coarse with occasional very coarse grains;spherical to sub-discoidal;angular to sub-angular rounding; well sorted; unconsolidated sand; grain supported; texturally immature; compositionally immature; sand grains composed of translucent quartz, very hard siltstone, chert, black carbonaceous material and pyrite; loose pyrite and sand grain encrusted pyrite; porosity and permeability visually good; no oil indicators. Sand (4110' -4170') = grayish black to dark gray; upper fine to lower medium with occasional very coarse grains; sub-discoidal to sub-prismoidal sphericity; angular to sub-rounded; moderately well sorted; unconsolidated sand; grain supported;texturally immature;compositionally immature;translucent and milky white quartz 50% with remainder dark lithics, chert, and green lithics; sand grains are impacted/frosted; porosity and permeability visually good;white fluorescence on well rounded grains at 4170',very slow,faint white cut; no residual cut. Sand(4170'-4200')=very light gray to pinkish gray;very fine grained;spherical to sub-discoidal;rounded to well rounded; very well sorted; unconsolidated; grain supported; texturally mature; compositionally mature; 10% milky white calcite grains all have gold fluorescence and slow streaming cut; no residual cut; porosity and permeability visually good; Sand(4170'-4290')=medium dark gray to dark gray; lower medium to upper fine grained;spherical to sub- discoidal; angular to sub-angular rounding; well sorted; unconsolidated sand; grain supported; texturally immature; compositionally sub-mature; translucent quartz grains with chert green lithics and black lithics; porosity and permeability visually good; no oil indicators. Sand (4290' -4380') = medium dark gray or pinkish gray; upper fine to lower medium; spherical to sub- discoidal; angular to sub-angular;well sorted; unconsolidated sand;grain supported;translucent/milky white quartz grains;4340'-4360'white sideritic calcite;lower very fine; rounded,spherical,hcl reactant;fluoresces greenish white; porosity/permeability good; no oil indicators. Siltstone(4380-4500)=light to medium light gray with a slight brownish secondary hue; soft; recovered as irregular masses coated with adherent sand; silty to sandy texture; dull earthy to gritty luster; slightly to non cohesive; slightly adhesive; hydrophilic; easily washes away in sample preparation; non to very slightly calcareous; interbedded with thin to moderate sand/silty sand stringers; 5%medium blue to greenish yellow fluorescence;slow crush cut to yellow white;trace straw residue has trace cut to bluish white;no odor or stain. PEAKS Depth TG C1 C2 C3 C41 C4N C51 C5N 2349 71 13620 2588 56 11999 2926 83 16151 2934 _ 76 14818 _ 3050 54 10794 3605 47 9351 Schrader Bluff: 4446.5MD/-3307.5' TVDSS Drill Rate(ft/hr Total Gas(units) Maximum Minimum Average Maximum Minimum Average 573.2 0.7 165.0 1262 0 188.6 15 CANRIG NIKAITCHUQ OP12-01 ena r 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.This well encountered significant oil shows in the"OA"sands. 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/Sandstone(4500-4590)=medium light to light gray;soft to dis-aggregated;friable; moderately well to well sorted;medium lower to medium upper grain predominates;trace to common medium upper;scattered coarse lower 60 to 70%clear to translucent white quartz; common to abundant medium to light gray lithics; common dark gray to black lithic/mafic mineral grains;trace coal fines;trace bluish gray;trace medium grain size microcrystalline pyrite masses;scattered brick red jasper;appears primarily grain supported;occasional soft silt supported masses; interbedded with associated siltstone;trace very fine grain; hard brownish gray silty sandstone;5%to trace dull blue to yellow white fluorescence;slow crush cut to blueish white;very slight straw residue, no ring; residue has a very slight cut to blue-white; slightly calcareous. Siltstone (4590 - 4650) = light to medium light brownish gray; recovered as soft irregular masses with adherent sand; silty to sandy; dull earthy to gritty luster; moderately cohesive; slightly adhesive; hydrophilic easily washes away in sample preparation scattered medium to coarse sand and 3 to 5 mm pebbles; trace banded light brown pyritic claystone; slightly calcareous;trace shell fragments;thin to moderate sand/sandy siltstones interbeds;trace hard sandstone flakes;5 to 20%dull greenish yellow fluorescence;slow crush cut to blue white; very slight brownish residue with trace cut to yellow white; no odor or visible stain; slightly calcareous. Sand/sandstone (4660 - 4780) = light brownish gray; dis-aggregated loose sand with occasional hard sandstone flakes;friable;appears primarily grain supported;some silty matrix support;moderately well to well sorted; medium lower to fine upper and fine lower grain predominate; trace medium upper and very fine; angular to sub-angular and sub sph eroidal; predominantly translucent white to clear quartz;common light to medium and dark gray lithics;trace black mafic mineral and lithics;trace bluish gray and dark greenish gray lithics; when present, matrix is light to very light gray silt/clay; trace white ash flakes; common oil stain on sand grains; trace visible oil blebs in matrix supported material; fair oil sheen on wash water; 70 to 100% medium yellow fluorescence; moderate streaming cut to yellow white; slight straw residue ring with an immediate cut to yellow white; no oil odor; slightly calcareous. Siltstone(4780-4890)=light to medium light gray to brownish gray;recovered as soft irregular masses with adherent sand; silty to sandy; dull earthy to gritty luster; moderately cohesive; slightly adhesive; hydrophilic easily washes away in sample preparation trace to abundant finely ground tan shell fragments;common thin to micro-thin carbonaceous lamina; interbedded with thin to moderate silty sand stone; very slightly to slightly calcareous;trace to abundant free oil blebs in sample;good oil sheen on wash water;no visible oil at shakers; 40 to 60% medium yellow to golden yellow fluorescence; moderate streaming cut to milky blue-white; slight straw residue ring fluoresces dull yellow, cuts immediately to yellow white; very slight oil odor. Siltstone(4920-5040)=light to medium light gray to brownish gray;recovered as soft irregular masses with adherent sand; silty to sandy; dull earthy to gritty luster; moderately cohesive; slightly adhesive; hydrophilic easily washes away in sample preparation trace to abundant finely ground tan shell fragments;common thin to micro-thin carbonaceous lamina; interbedded with thin to moderate silty sandstone; sandstone is compositionally similar to adjacent sands and contains scattered medium to coarse and small pebbles; common medium to coarse pyrite masses;very slightly to slightly calcareous;trace free oil blebs in samples; trace oil sheen in wash water;general overall dull yellow to golden yellow fluorescence; moderate streaming cut to milky blue-white;fair straw residue ring fluoresces dull yellow, cuts immediately to yellow white; no oil odor no visible stain. Siltstone(5040-5160)=light to medium light gray to brownish gray;recovered as soft irregular masses with adherent sand; silty to sandy; dull earthy to gritty luster; moderately cohesive; slightly adhesive; hydrophilic can wash away in sample preparation; trace to common finely ground tan shell fragments; common thin to 16 CANRIG NIKAITCHUQ OP12-01 eni micro-thin carbonaceous lamina; interbedded with thin to silty sandstones; sand stone is compositionally similar to upper sands and contains scattered medium to coarse and small pebbles;trace medium to coarse pyrite masses;very slightly to slightly calcareous; 10 to 30%point source medium yellow fluorescence;slow streaming cut to slightly milky blue-white;trace straw colored residue fluoresces medium yellow; no oil odor or visible stain. Siltstone(5160-5270)=light to medium light gray to brownish gray;recovered as soft irregular masses with adherent sand; silty to sandy; dull earthy to gritty luster; moderately cohesive; slightly adhesive; hydrophilic can wash away in sample preparation; trace to common finely ground tan shell fragments; common thin to micro-thin carbonaceous lamina; interbedded with thin to silty sandstones; sand stone is compositionally similar to upper sands and contains scattered medium to coarse and small pebbles;trace medium to coarse pyrite masses;very slightly to slightly calcareous; 10 to 30%point source medium yellow fluorescence;slow streaming cut to slightly milky blue-white;trace straw colored residue fluoresces medium yellow;no oil odor or visible stain. Silty Clay(5270'-5320')=olive gray light olive gray;soft;very poorly to non-indurated;cohesive,adhesive, plastic and pliable; lumpy to clumpy consistency; tenacity is flexible to elastic to stiff; fracture is irregular; cuttings habit is massive; luster is dull to earthy; texture is clayey to silty to gritty; massive structure; overall sample fluoresces very faint dull yellow; very slow, faint streaming white cut; no residual cut. Silty Clay(5320'-5390')=olive gray light olive gray;soft;very poorly to non-indurated;cohesive, adhesive, plastic and pliable; lumpy to clumpy consistency; tenacity is flexible to elastic to stiff; fracture is irregular; cuttings habit is massive; luster is dull to earthy; texture is clayey to silty to gritty; massive structure; overall sample fluoresces very faint dull yellow; very slow, faint streaming white cut; no residual cut. Sand (5390' - 5470') = olive gray to olive black; lower very fine to upper fine grained; spherical to sub- discoidal; rounded to sub-rounded;well to very well sorted; unconsolidated sand; grain supported;texturally mature;compositionally sub-mature;translucent and milky white quartz predominate with chert,glauconite and pyrite;sand fluoresces 100%straw,greenish gold;sample cuts instantaneous blooming,bright,bluish white; residual cut 100%bright white;sand grains stained amber;oil odor present;free oil visible at end of shakers; porosity and permeability visually very good. PEAKS Depth TG C1 C2 C3 C4I C4N C51 C5N 4490 52 10240 37 11 3 7 4 21 4553 38 7415 40 4661 208 41553 370 98 133 35 6 4769 308 58251 613 132 90 32 45 4875 324 62274 705 201 108 44 84 9 TOP "OA" SAND at 4976.0' MD/-3574.4' TVDSS Sand (4950-5020) = clear to very light gray to medium gray; upper very fine to upper fine; subangular to subrounded with low to moderate sphericity; moderately to well sorted;trace orange lithics, shell fragments, and brilliant green glauconite; slightly calcareous; slight odor, 50%-60% light brown stain, 50% even dull yellow fluorescence, streaming amber cut with streaming bright white cut fluorescence, heavy dark brown residue with dull yellow residue fluorescence. "OA" SAND Sub-layer 2 at 5566.0' MD/-3568.5' TVDSS Siltstone(5520'-5610') =grayish black to olive gray;friable to firm; poorly moderately indurated; dense to brittle to crumbly tenacity; irregular to earthy fracture;elongated to nodular cuttings habit;dull to earthy luster; silty to gritty texture; massive structure, at times barely discernable laminae; sample fluoresces 80% light green and 20% yellow gold; instantaneous blooming milky white cut; medium oil odor; no oil at shakers; 17 CAINRIC] NIKAITCHUQ OP12-01 eni residual cut bright white. "OA" SAND Sub-layer 3 at 5614.0' MD/-3572.5' TVDSS Siltstone (5610' - 5700') = grayish black to olive gray; friable to firm friable; poorly moderately indurated; dense to brittle to crumbly tenacity; irregular to earthy fracture; elongated to nodular cuttings habit; dull to earthy luster; silty to gritty texture; massive structure, at times barely discernable laminae; sand/sandstone upper fine to upper very fine grained; quartz with some glauconite; sample fluoresces 60% light green, 20% yellow gold; instantaneous blooming milky white cut; medium oil odor; no oil at shakers; residual cut bright white; amber grain staining in siltstone and sandstone, porosity and permeability visually good. Sand(5700'-5790')=dark gray to medium dark gray; upper very fine to lower fine grained;spherical to sub- discoidal;sub-rounded to rounded;well to very well sorted;unconsolidated sand;grain supported;translucent and milky white quartz sand grains,<1%glauconite;shell fragments;sample fluoresces light green with some bright yellow gold;sample cuts and instantaneous bright white bloom; residual cut is a dull green;moderate to moderately strong oil odor; no oil at shakers; porosity and permeability visually good to very good. Sand(5790'-5880')=dark gray to medium dark gray; upper very fine to lower fine grained;spherical to sub- discoidal;sub-rounded to rounded;well to very well sorted;unconsolidated sand;grain supported;translucent and milky white quartz sand grains,<1%glauconite;shell fragments;sample fluoresces light green with some bright yellow gold;sample cuts and instantaneous bright white bloom;residual cut is a dull green;moderate to moderately strong oil odor; no oil at shakers; porosity and permeability visually good to very good. Sand(5880'-5970')=olive black to grayish black in color; upper very fine to lower fine grained; spherical to sub-discoidal; sub-angular to sub-rounded; well to very well sorted; unconsolidated sand; grain supported; translucent with some milky white quartz grains with glauconite;sample fluoresces 100%dull green with some bright yellow gold; instantaneous bluish white streaming to blooming cut;medium strong oil odor; light amber grain staining on majority of grains; residual cut light green; porosity and permeability visually good. Fault#1 at 5950.0' MD/-3584.6' TVDSS Sand(5970'-6060')=olive black to grayish black in color; upper very fine to lower fine grained;spherical to sub-discoidal; sub-angular to sub-rounded; well to very well sorted; unconsolidated sand; grain supported; translucent with some milky white quartz grains with glauconite and red lithics; sample fluoresces 100%dull green with some bright yellow gold; instantaneous white blooming cut; medium strong oil odor; light amber grain staining on majority of grains; residual cut light green; porosity and permeability visually good. Sand (6060' -6150') = olive gray to light olive gray; upper very fine to lower fine grained; spherical to sub- discoidal; sub-angular to rounded;well to very well sorted; unconsolidated sand; grain supported;texturally sub-mature;compositionally sub-mature;translucent quartz predominate grains with some green glauconite and black carbonaceous lithics; sample fluoresces light green; instantaneous blooming milky white cut; medium to strong oil odor; no oil at shakers;very light amber staining on quartz grains; residual cut very light green; porosity and permeability visually good. Sand (6150' -6240') = olive gray to light olive gray; upper very fine to lower fine grained; spherical to sub- discoidal; sub-angular to rounded;well to very well sorted; unconsolidated sand; grain supported; texturally sub-mature; compositionally sub-mature;translucent quartz predominate grains with some green glauconite and black carbonaceous lithics; sample fluoresces light green; instantaneous blooming milky white cut; medium to strong oil odor; no oil at shakers;very light amber staining on quartz grains; residual cut very light green; porosity and permeability visually good. Sand (6240'-6330') = olive gray to light olive gray; upper very fine to lower fine grained; spherical to sub- discoidal; sub-angular to rounded;well to very well sorted; unconsolidated sand; grain supported;texturally sub-mature;compositionally sub-mature;translucent quartz predominate grains with some green glauconite and black carbonaceous lithics; sample fluoresces light green; instantaneous blooming milky white cut; 18 CANRIG NIKAITCHUQ OP12-01 -eni medium to strong oil odor; no oil at shakers;very light amber staining on quartz grains; residual cut very light green; porosity and permeability visually good. Sand (6330'-6420')= medium gray to dark gray; upper very fine to lower fine with some upper fine grains; spherical to sub-discoidal;sub-angular to rounded;moderately well to well sorted;unconsolidated sand;grain supported;texturally sub-mature;compositionally sub-mature;translucent quartz with glauconite,black lithics, and shell fragments;sample fluoresces an even light green; instantaneous streaming bright bluish white cut; slight oil odor; <50% grains are amber stained; no oil at shakers; residual cut dull light green; porosity and permeability visually good. Sand (6420'-6510')= medium gray to dark gray; upper very fine to lower fine with some upper fine grains; spherical to sub-discoidal;subangular to rounded;moderately well to well sorted; unconsolidated sand;grain supported;texturally sub-mature;compositionally sub-mature;translucent quartz with glauconite,black lithics, and shell fragments;sample fluoresces an even light green; instantaneous streaming bright bluish white cut; slight oil odor; <50% grains are amber stained; no oil at shakers; residual cut dull light green; porosity and permeability visually good. Sand(6510'-6630')=medium to medium light greenish gray overall with individual grains dominantly clear to translucent quartz, light to medium gray,medium to dark greenish gray,trace black,pale rose and dark bluish green;very fine upper to rare very coarse upper,dominantly fine lower to medium lower;angular to subangular with trace rounded very coarse liths; moderate to moderately well sorted; dominantly unconsolidated; trace glauconite and shell fragments; sample fluoresces uniform dull green from oil base mud; 10% -40% dull yellow fluorescence from stained grains and sandstone fragments;instant bright milky white cut fluorescence; trace streaming yellowish white cut fluorescence from stained pieces; light straw visible cut; bright yellowish white residual ring fluorescence; no visible residual ring; no free oil; no odor above oil base background. Sand/ Sandstone (6630' - 6750') = medium to medium dark gray overall with individual grains the same colors as noted;very fine lower to trace very coarse upper,dominantly fine lower to medium lower;angular to subangular with trace rounded pebbles; moderately well to very well sorted; dominantly unconsolidated with scattered grain supported sandstone pieces; medium to dark gray to brownish gray from staining; very fine lower to fine lower, commonly grading between silty sandstone/sandy siltstone 30%-60%greenish yellow fluorescence above oil base background;flash yellowish white cut fluorescence; light to medium straw visible cut; trace to 30% medium to dark brown stain; yellowish white residual ring fluorescence; no to trace pale brown residual ring; no free oil; no odor above background levels. Fault#2 at 6712.0' MD/-3586.5'TVDSS "OA" SAND Sub-layer 4 at 6712.0 MD/-3586.5' TVDSS Siltstone(6720'-6830')= medium to medium dark gray with trace light yellow to yellowish brown and dark grayish brown secondary hues; firm to very firm; irregular, rounded cuttings with occasional "scooped" bit action appearance;silty to slightly gritty texture;dull,earthy to slightly waxy luster;30%-60%bright yellowish green sample fluorescence above background levels;trace dark brown stain on sandstone fragments;flash bright yellowish white cut fluorescence;medium to dark straw visible cut; light to medium brown residual ring; bright yellow residual ring fluorescence; no free oil noted; no odor above background levels detected; note some siltstone grades between silty sandstone and sandy siltstone. Sand/Sandstone(6830'-6960')=medium to medium dark gray with brownish gray secondary hues overall, individual grains dominantly light to medium gray, medium to dark gray to greenish gray and brownish gray, black,clear to translucent quartz,trace dark bluish green glauconite nodules;very fine lower to medium lower, dominantly fine upper to lower; angular to subangular; moderate to very well sorted; dominantly unconsolidated to very loosely consolidated; loose grains generally have no staining; very fine consolidated sandstone has medium to dark brown stain;firm to moderately hard;grain supported;40%-80%moderate to bright yellowish green sample fluorescence; flash yellowish white cut fluorescence; pale to medium straw visible cut; dull yellow residual ring fluorescence; medium straw residual ring; no free oil; no odor above background level; trace shell fragments. 19 CANRIG NIKAITCHUQ OP12-01 eni "OA" SAND Sub-layer 3 bottom at 6910.0' MD/-3586.5' TVDSS Sand(6960'-7070')=medium to medium light gray with light greenish gray secondary hues and a moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz, light to medium gray to light greenish gray, black, dark greenish gray and trace pale rose; very fine upper to fine upper, dominantly fine grain; angular to subangular unconsolidated; very well sorted; trace shell fragments; 10%-60% bright yellowish green fluorescence above background levels;weak milky white cut fluorescence no to trace visible pale straw cut; no residual ring or ring fluorescence; no staining present; no free oil or odor. Sand (7050' -7140') = medium to medium light gray with occasional medium dark brown secondary hues, individual grains continue as described above; very fine upper to medium lower, dominantly fine upper to lower; angular to subangular;trace subrounded to rounded pebbles;well sorted; dominantly disaggregated; dull greenish yellow fluorescence from oil base mud; trace to 30% yellowish gold fluorescence; trace light brown stain on very fine grain sandstone fragments;fragments commonly grade between silty sandstone and sandy siltstone;fast milky white cut fluorescence; no to trace pale straw cut;weak pale straw residual ring;no to weak gold residual ring fluorescence; no free oil noted; no odor above oil base mud background. Sand / Sandstone (7150' - 7260') = medium gray with greenish gray secondary hues, individual grains dominantly clear to translucent quartz, light gray to light greenish gray,medium to dark gray,black trace dusky dark red,pale rose and dark bluish green glauconite nodules;very fine lower to medium lower,dominantly fine lower to upper;angular to subangular;moderate to very well sorted;dominantly unconsolidated with trace very fine sandstone; firm to slightly fragile medium gray to brownish gray from staining; grain supported; uniform dull greenish yellow sample fluorescence from oil base mud; 10% -60% yellowish gold fluorescence from stained sands;instant bright yellowish white cut fluorescence; light straw visible cut;very light brown residual ring;bright white residual ring fluorescence;no to trace free oil on stained sandstone fragments; no odor noted above oil base mud levels. "OA" SAND Sub-layer 2 bottom at 7380.0' MD/-3575.0' TVDSS Sand(7260'-7360')=medium to medium light gray with light greenish gray secondary hues,individual grains dominantly clear to translucent quartz, light to medium gray to light greenish gray,medium to dark gray,trace black, pale rose and dark bluish green glauconite nodules very fine upper to medium lower, dominantly fine grain;angular to subangular;very well sorted;dominantly disaggregated with trace sandstone fragments;grain supported;very fine to fine grain firm to hard; occasionally grading to sandy siltstone/silty sandstone; 10%- 50% bright yellowish green fluorescence above background levels; moderate to fast milky white cut fluorescence; trace to light straw visible cut; no to trace light straw residual ring; moderate gold residual ring fluorescence;scattered medium to dark brown staining; no free oil; no odor above background levels;trace to common shell fragments. Siltstone (7390' -7460') = medium gray with grayish brown secondary hues; firm; waxy; irregular, curved cuttings, commonly showing scooped bit action appearance silty to clayey to slightly gritty; dull to waxy to slight sparkly luster;commonly grades between a silty sandstone and sandy siltstone;trace shell fragments; 20%-60%yellow sample fluorescence above background levels;flash milky white cut fluorescence; light to medium straw visible cut; strong yellowish white residual ring fluorescence; medium brown residual ring; no free oil; no to slight petroleum odor above oil base mud background levels. Sandstone/Sand (7460' -7550') = medium to medium dark gray with medium brownish gray secondary hues; firm to friable; rounded fragments; grain supported; very fine lower to fine upper; very well sorted; commonly grading to sandy siltstone and silty sandstone;estimate fair to good porosity and permeability;30% -70%yellow fluorescence above background levels;common to abundant dark brown staining; instant flash, bright milky white cut fluorescence;medium to dark straw visible cut;light straw residual ring; bright yellowish white residual ring fluorescence; no to trace very dark brown oil in stained fragments; slight petroleum odor above oil base mud background levels. 20 CANRIG NIKAITCHUQ OP12-01 eni "OA" SAND Sub-layer 1 bottom at 7520.0' MD/-3569.9' TVDSS Sand/Sandstone(7550'-7650')=medium gray to medium dark gray with brownish gray sub-hues; upper very fine to lower fine grained; spherical to sub-discoidal; angular to sub-rounded; very well sorted; unconsolidated sand, sandstone is friable; grain supported; texturally sub-mature; compositionally mature; calcite cement;translucent quartz sand with glauconite and black chert; even light green fluorescence from naf, bright yellow gold in sandstones; instantaneous streaming to blooming bluish white cut; oil odor is medium; residual cut yellow; no oil at shakers; amber staining on grains in sandstone; porosity and permeability visually good. Sand/Sandstone(7650'-7740')=medium dark gray to medium gray with olive gray sub-tones; upper very fine to lower fine grained;spherical to sub-discoidal;angular to sub-rounded;very well sorted;unconsolidated sand, friable sandstone; grain supported; texturally sub-mature; compositionally mature; calcite cement; translucent quartz sand with glauconite, black chert and shell fragments;yellow gold fluorescence where not naf contaminated sandstone cuts and instantaneous bluish white; residual cut bright white; medium oil odor; no oil at shakers; amber staining on sandstone grains; porosity and permeability visually good. Sand/Sandstone(7740'-7830')=medium gray to medium dark gray with olive gray sub-hues; upper very fine to lower fine grained;sub-discoidal to spherical;angular to sub-rounded;very well sorted;unconsolidated sand,friable sandstone;grain supported;sub-mature texture;mature composition;calcite cement;translucent quartz with glauconite,black chert, red lithics and shell fragments;yellow gold fluorescence above background naf fluorescence; sandstone streams an instantaneous bluish white cut; faint residual cut with bluish white halo; medium to light oil odor; no oil at shakers; amber staining on grains within sandstone; porosity and permeability visually good. Sand(7830'-7920')=medium dark gray to dark gray with olive gray sub-tones; upper very fine to lower fine with occasional upper fine grains; spherical to sub-discoidal; sub-rounded to angular; well sorted; unconsolidated sand;grain supported;texture sub-mature;compositionally sub-mature;translucent quartz with glauconite, black chert, red lithics and shell fragments; dull light green background fluorescence; medium streaming bluish white cut; dull white residual cut; medium oil odor; very faint amber oil staining; no oil at shakers; porosity and permeability visually good, slow fluorescence cut likely due to naf. Sand (7920'-8010')=dark gray to medium dark gray with olive gray sub-hues; upper very fine to lower fine grained;spherical to sub-discoidal;sub-angular to sub-rounded;very well sorted; unconsolidated sand;grain supported;texturally sub-mature; compositionally sub-mature to mature;translucent quartz is predominates with glauconite,black chert and shell fragments; light green background fluorescence with spotted gold yellow 1%-2%; medium streaming bluish white cut;faint white residual cut; no oil at shakers;faint oil odor; porosity and permeability visually good. Sand(8010'-8100')=medium dark gray to dark gray with olive gray sub-tones; upper very fine to lower fine grained,occasional upper fine grain;spherical to sub-discoidal;sub-angular to sub-rounded;very well sorted; sand is unconsolidated;grain supported;texturally sub-mature;compositionally sub-mature;translucent quartz with glauconite, black chert and shell fragments;calcite deposit from 8093'to 8098'; light even fluorescence; instantaneous blooming bluish white cut;faint white residual cut; no oil at shakers;faint oil odor;porosity and permeability visually good. Sand(8100'-8220')=dark gray to medium dark gray with olive gray sub-tones; upper very fine to lower fine grained; spherical to sub-discoidal; angular to sub-rounded; very well sorted; unconsolidated sand; grain supported;texturally sub-mature;compositionally sub-mature;translucent quartz with glauconite,black chert and shell fragments;sample fluoresces even dull green;sample cuts an instantaneous bluish white; residual cut faint white; no oil at shakers;faint oil odor;very faint amber stain on sand grains;porosity and permeability visually good. Sand (8220' - 8310') = medium dark gray to dark gray with olive sub-hues; upper very fine to lower fine 21 CANRIG NIKAITCHUQ OP1 2-01 Pni grained; spherical to sub-discoidal; sub-rounded to angular; very well sorted; unconsolidated sand; grain supported; texturally sub-mature to mature; compositionally sub-mature to mature; translucent quartz with glauconite, black chert and shell fragments; thing siltstone beds cemented with calcite; sample cuts instantaneous bluish white;faint white residual cut; no oil at shakers;faint oil odor; very faint amber stain on sand grains; porosity and permeability visually good. Sand(8310'-8400')=dark gray to medium dark gray with olive gray sub-tones; upper very fine to lower fine grained; spherical to sub-discoidal; sub-rounded to angular; very well sorted; unconsolidated sand; grain supported; texturally sub-mature; compositionally sub-mature to mature;translucent quartz with glauconite, black chert and shell fragments;calcitic siltstone, moderately hard to hard, moderate to well indurated, brittle to dense tenacity, irregular and planar fracture, massive cuttings habit; dull to earthy luster, silty to gritty texture, laminae structure; dull light green fluorescence; sample cuts instantaneous bluish white;faint white residual cut; very faint amber stain on grains; faint oil odor; no oil at shakers; porosity and permeability visually good. "OA" SAND Sub-layer 2 at 8493.0' MD/-3581.8' TVDSS Sand(8400'-8460')=medium dark gray to medium gray with olive gray sub-hues; upper very fine to lower fine; spherical to sub-discoidal; sub-rounded angular; very well sorted; sand is unconsolidated; grain supported; translucent quartz with glauconite, black chert and shell fragments; light green fluorescence; instantaneous bluish white cut; faint white residual cut; very faint amber stain; porosity and permeability visually good. Siltstone(8430'-8610')=grayish black to dark gray;friable to easily moderately indurated; brittle tenacity; subrounded, irregular shaped cuttings, some show pdc bit action scooped appearance; silty to slightly gritty texture;dull,waxy to slightly sparkly luster;siltstone occasionally grades between a silty sandstone and sandy siltstone;trace shell fragments;dull green sample fluorescence from oil bas mud;trace to 20%yellowish green sample fluorescence above background levels; instant milky white cut fluorescence; very pale straw visible cut;weak residual ring ; no free oil or odor above background level. "OA" SAND Sub-layer 3 at 8595.0' MD/-3586.1' TVDSS Sand (8590'-8700') = medium to medium light gray overall with a moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz, light to medium translucent gray, light greenish gray, dark gray to black,trace dark bluish green glauconite nodules, pale rose and dark dusky red;very fine upper to medium lower, dominantly fine upper to lower; angular to subangular; very well sorted; dominantly disaggregated; trace grain supported fragments; very friable; trace to common shell fragments;40%-90% yellow sample fluorescence above background levels; instant bright milky white cut fluorescence;fast medium straw visible cut;bright yellowish white residual ring fluorescence;very light straw residual ring; no free oil; no to slight petroleum odor above background level. Sand(8690'-8790')=medium to medium dark gray, individual grains dominantly light to medium gray, light greenish gray, clear to translucent quartz, trace black and dark red liths; very fine upper to medium lower, dominantly fine lower to upper; angular to subangular; moderately well sorted; unconsolidated; trace to common shell fragments; 10%-60%yellowish green fluorescence above background levels; instant milky white cut fluorescence;slow pale straw visible cut;bright yellowish white residual ring fluorescence;pale light brown residual ring; no staining; no free oil; no odor above background levels. Sand(8790'-8880')= medium dark gray to medium gray; upper very fine to lower fine grained; spherical to sub-discoidal;sub-angular to rounded;very well sorted; unconsolidated sand;grain supported;texturally sub- mature;compositionally mature;translucent quartz with glauconite, black chert and shell fragments; sample fluoresces dull even light green;cut is instant bluish white blooming;residual cut is faint pale white;faint amber stain on some grains;very faint oil odor; no oil at shakers; no free oil;porosity and permeability visually good. 22 CANRIG Pik NIKAITCHUQ OP12-01 eni Sand (8880'-8970')= medium dark gray to medium gray; lower fine to upper very fine grained; spherical to sub-discoidal sphericity; sub-angular to rounded rounding; very well sorted; unconsolidated sand; grain supported;texturally sub-mature;compositionally sub-mature;translucent quartz with glauconite,black chert and pale orange shell fragments; dull even light green sample fluorescence (naf induced); sample cuts instantaneous blooming bluish white with white halo; residual cut is faint pale white;very faint amber stain on some grains; very faint oil odor; no oil at shakers; no free oil; porosity and permeability visually good. Sand (8970' - 9060') = medium gray to medium dark gray; upper very fine to lower fine grained with occasional upper fine grains;spherical to sub-discoidal sphericity;rounded to sub-angular rounding;very well sorted; unconsolidated sand;grain supported; sub-mature texturally; sub-mature to mature compositionally; translucent quartz with glauconite, black chert and pale orange shell fragments;dull even light green sample fluorescence; sample cuts instantaneous blooming bluish white cut with white halo; residual cut faint pale white;stain very faint amber;very faint oil odor;no oil at shakers; no free oil;porosity and permeability visually good. Sand/Sandstone(9060'-9150')=medium dark gray to medium gray; upper very fine to lower fine grained with occasional upper fine to lower medium;spherical to sub-discoidal;rounded to sub-angular rounding;very well sorted; unconsolidated sand, sandstone friable to easily friable; grain supported;texturally sub-mature; compositionally sub-mature;translucent quartz with glauconite, black chert and pale orange shell fragments; calcite deposits around 9120';even dull light green sample fluorescence;instantaneous blooming bluish white cut becoming streaming,with white halo;residual cut faint pale white;very faint amber stain;very faint oil odor; no oil at shakers; no free oil; porosity and permeability visually good. Sand(9150'-9240')=medium gray to medium dark gray; upper very fine to lower very fine,occasional upper fine to lower medium;spherical to sub-discoidal sphericity;sub-rounded to rounded;very well sorted;sand is unconsolidated; grain supported; sub-mature texturally; compositionally sub-mature to mature; translucent quartz with glauconite,black chert and pale orange shell fragments;even dull light green sample fluorescence; cut is instantaneous blooming bluish white with white halo; faint pale white residual cut; staining very faint amber; very faint oil odor; no oil at shakers; no free oil; porosity and permeability visually good. Sand (9240' -9360') = medium dark gray to medium gray; upper very fine to lower fine grained with some upper fine to lower medium grains; spherical to sub-discoidal; sub-rounded to rounded; very well sorted; unconsolidated sand;grain supported;texturally sub-mature;compositionally sub-mature to mature; sand is translucent quartz with glauconite, black chert and pale orange shell fragments; sample fluoresces an even light green; instantaneous, blooming, bluish white cut with white halo; faint light green residual cut; staining pale amber; very faint oil odor; no oil at shakers; no free oil; porosity and permeability visually good. Sand (9360'-9450) = medium gray to medium dark gray; upper very fine to lower fine grains, some upper fine and lower medium grains; spherical to sub-discoidal; rounded to sub rounded; very well sorted; unconsolidated sand; grains supported; texturally sub-mature; sub-mature to mature compositionally; translucent quartz sand with glauconite, black chert and pale orange shell fragments; overall sample fluorescence even light green; instantaneous blooming bluish white cut; light green residual cut; light pale amber stain; very faint oil odor; no oil at shakers; no free oil; porosity and permeability visually good. Sand (9450'-9540') = medium gray to medium dark gray; upper very fine to lower fine grained, occasional upper fine to lower medium; spherical to sub-discoidal; sub-rounded to rounded; very well sorted; unconsolidated sand;grain supported;sub-mature texture;mature to sub-mature compositionally;translucent quartz with glauconite, black chert and pale orange shell fragments; sample fluoresces even light green; instantaneous streaming to blooming bluish white cut with white halo; light green residual cut; very faint oil odor; pale amber stain; no oil at shakers; no free oil; porosity and permeability visually good. Sand(9450'-9630')=medium gray to dark medium gray; upper very fine to lower very fine;spherical to sub- discoidal; sub-angular to rounded; very well sorted; unconsolidated sand; grain supported; texturally sub- mature;compositionally sub-mature to mature;translucent quartz grains with glauconite,black chert,and pale 23 CANRIG NIKAITCHUQ OP12-01 en - i orange shell fragments; even green fluorescence; instantaneous blooming bluish white cut; faint green residual cut; very faint oil odor; pale amber staining; no oil at shakers; no free oil; porosity and permeability visually good. Sand(9630'-9740')=medium to medium light gray with light greenish gray secondary hues and a moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz, light gray to translucent gray, medium to dark greenish gray,trace black and dark bluish green glauconite nodules;very fine lower to medium lower,dominantly fine upper to lower;angular to trace subrounded,dominantly subangular;moderate to well sorted;unconsolidated;common to abundant pinkish orange shell fragments;no free oil;no petroleum odor above background levels; 10%-60%dull yellow fluorescence above oil base mud background levels; slow, pale milky white cut fluorescence;trace very pale straw visible cut; slight straw residual ring and bright yellowish white residual fluorescence; no staining. "OA" SAND Sub-layer 2 bottom at 9842.0' MD/-3592.4'TVDSS Sand(9750'-9860')=medium to medium dark gray with individual grains dominantly light to medium gray to greenish gray,clear to translucent quartz,dark gray to black,trace dark bluish green glauconite nodules;very fine lower to medium lower, dominantly fine grain; angular to subrounded; moderately well sorted; unconsolidated to loosely grain supported; scattered sandstone commonly grades between silty sandstone and sandy siltstone; common shell fragments; trace chert fragments; 10% - 50% dull yellow fluorescence; instant bright milky yellow cut fluorescence; pale straw visible cut; bright yellowish white residual ring fluorescence;weak, light brown residual ring; no staining; no free oil; no odor above background levels. "OA" SAND Sub-layer 1 bottom at 9970.0' MD/-3587.4' TVDSS Sandstone/Sand(9850'-9950')=medium to medium dark gray with an olive gray secondary hue,individual grains generally the same as already noted;very fine lower to medium lower,dominantly fine lower;angular to subangular;moderate to moderately well sorted;moderately well consolidated;generally grain supported;firm to friable,occasionally hard to brittle;irregular shaped fragments;trace shell fragments;sandstone commonly grades to sandy siltstone/silty sandstone; medium to dark brown staining inside fragments;trace visible oil on freshly exposed surfaces; 30%-80%dull yellow fluorescence;flash,bright yellowish white cut fluorescence; light to medium straw visible streaming cut; intense white residual ring fluorescence; medium to dark straw residual ring; no to slight petroleum odor above background levels. Siltstone (9900' -10000') = medium to medium light gray with light brownish gray secondary hues; firm to moderately hard;irregular to bit action scooped appearance;silty to slightly gritty texture;dull,earthy to slightly waxy luster; siltstone commonly grades to silty sandstone/sandy siltstone; 20%-60%yellow fluorescence; fast yellowish white cut fluorescence; medium straw visible cut; dark straw residual ring; yellowish white residual ring fluorescence; slight light brown stain on fresh exposed surfaces; no free oil; no odor above background levels. Sand (10020' - 10140') = medium to medium light gray, individual grains dominantly clear to translucent quartz,light to medium translucent gray, light to medium gray,trace dark gray to black;very fine lower to trace medium upper,dominantly fine upper to lower;angular to subangular;well sorted;dominantly disaggregated; no staining present; 10%-40%dull yellow sample fluorescence;slow milky yellowish white cut fluorescence; weak,pale straw visible cut;very light straw residual ring,bright yellowish white residual fluorescence;no free oil; no odor. Sand(10110'-10230')=medium to medium light gray overall,individual grains continue to show same colors as noted above; very fine upper to rare medium upper, dominantly fine lower to medium lower; angular to subangular; moderate to moderately well sorted; dominantly unconsolidated with trace very friable grain supported sandstone; occasionally grading to sandy siltstone/ silty sandstone; trace to common shell fragments; no to trace light brown stain on freshly exposed sandstone pieces; 10%-50%dull yellow sample fluorescence above oil base mud background levels; instant flash,milky yellowish white cut fluorescence;very pale straw visible cut; trace light brown residual ring; bright yellow residual ring fluorescence; no free oil; no 24 CANRIG NIKAITCHUQ OP12-01 eni odor above background. Sand (10220' - 10330') = medium light to medium gray with a slight salt and pepper appearance overall, individual grain dominantly clear to translucent quartz,light to medium translucent gray,medium to dark gray, black, light to medium to dark greenish gray, trace dark bluish green glauconite nodules; very fine lower to medium lower, dominantly fine upper to lower; angular to subangular; moderate to well sorted; dominantly disaggregated; common to abundant shell fragments;30% - 90% yellow/ gold sample fluorescence over background; no visible staining; instant milky yellowish white cut fluorescence; pale straw visible cut and residual ring; bright yellowish white residual ring fluorescence; no free oil; no odor above background levels. Sand(10320'-10420')=medium to medium light gray with a strong salt and pepper appearance, individual grains continue with the same general color characteristics as above; very fine lower to medium lower, dominantly fine upper to lower; angular to subangular; moderate to very well sorted; note increase in glauconite nodules; trace to common shell fragments; 10% - 60% yellow sample fluorescence above background levels;fast milky yellowish white cut fluorescence;slow,pale straw visible cut; no visible residual ring; bright yellowish white residual ring fluorescence; no staining; no free oil; no odor. Sand(10420'-10500')=medium gray to medium dark gray;upper very fine to lower fine with some upper fine to lower medium; spherical to sub-discoidal; rounded to sub-angular;very well sorted; unconsolidated sand; grain supported; texturally sub-mature; compositionally sub-mature to mature; translucent quartz with pale yellow orange shell fragments, glauconite and black chert; sample fluoresces even light green; sample cuts medium fast streaming to blooming bluish white with white halo ring;faint oil odor; no oil at shakers; no free oil; faint light amber grain staining; light white residual cut; porosity and permeability visually good. Sand (10500' - 10590') = medium dark gray to medium gray; upper very fine to lower fine with occasional upper fine to lower medium grains; spherical to sub-discoidal; rounded to sub-angular; very well sorted; unconsolidated sand; grain supported; texturally sub-mature; compositionally mature to sub-mature; translucent quartz with pale yellow orange shell fragments,glauconite and black chert;sample fluoresces even light green;sample cuts medium streaming bluish white with white halo ring; residual cut light white; no oil at shakers; no free oil; faint oil odor; faint light amber grain staining; porosity and permeability visually good. Sand(10590'-10740')=medium dark gray to medium gray; upper very fine to lower fine with some upper fine grains; spherical to sub-discoidal; rounded to sub-rounded; very well sorted; unconsolidated sand; grain supported;texturally sub-mature; compositionally mature to sub-mature;translucent quartz with pale yellow orange shell fragments,glauconite and black chert; 10620'sample highly contaminated with Safe Carb mud additive,others also contaminated;even light green sample fluorescence;medium to medium slow streaming bluish white cut; light white green residual cut; faint oil odor; no oil at shakers; very faint oil stain on some grains; porosity and permeability visually good. Sand(10740'-10830')=medium gray to medium dark gray with olive gray sub-tones;upper very fine to lower fine grained with occasional upper fine and lower medium grains;spherical to sub-discoidal; rounded to sub- angular;very well sorted; unconsolidated sand;grain supported;texturally sub-mature;compositionally mature to sub-mature;translucent quartz with pale yellow orange shell fragments, glauconite, and black chert; Safe Carb mud additive contaminates samples; even light green sample fluorescence; instantaneous blooming bluish white cut; light green white residual cut; faint oil odor; faint amber stain on some grains; no oil on shakers; no free oil; porosity and permeability good. Sand(10830'-10920')=medium dark gray to medium gray with olive gray sub-hues; upper very fine to lower fine grain with some upper fine and lower medium grains;spherical to sub-discoidal; rounded to sub-angular; very well sorted; sand is unconsolidated; grain supported; texturally sub-mature; mature to sub-mature compositionally;translucent quartz grains with pale yellow orange shell fragments,glauconite and black chert; Safe Carb mud additive contamination; sample fluoresces even light green; cut is medium streaming to blooming bluish white; residual cut is light white;faint oil odor; light amber grain stain; no free oil;porosity and permeability good. 25 CANRIG fah NIKAITCHUQ OP12-01 eni Sand(10920'-11010')=medium dark gray to medium gray with olive gray sub-tones;upper very fine to lower fine grained with occasional upper fine and lower medium grains;spherical to sub-discoidal; rounded to sub- angular; very well sorted; sand is unconsolidated; grain supported; texturally sub-mature; compositionally mature to sub-mature;translucent quartz grains with glauconite,pale yellow orange shell fragments,and black chert;sample fluoresces light even green; sample cuts instantaneous bright bluish white; residual cut is light white; faint oil odor; light amber grain staining; no free oil; porosity and permeability visually good. "OA" SAND Sub-layer 2 at 11053.0' MD/-3584.2' TVDSS Sand(11010'-11100')=medium dark gray with olive gray sub-tones; upper very fine to lower fine grained; spherical to sub-discoidal; rounded to sub-angular; very well sorted; sand unconsolidated; grain supported; translucent quartz grains,shell fragments;instantaneous bluish white cut;white residual cut;light amber stain; no free oil; porosity and permeability visually good. "OA" SAND Sub-layer 3 at 1167.0' MD/-3588.2' TVDSS Siltstone (11070' - 11170') = medium gray to medium dark gray; hardness friable; poorly to moderate indurated; dense to brittle tenacity; irregular fracture; sub-nodular cuttings habit; dull to earthy luster; silty to gritty texture; no structure; very light green fluorescence; instantaneous streaming bluish white cut; white residual cut; faint oil odor; no free oil. Sand (11160' -11300') = medium to medium dark gray with greenish and brownish gray secondary hues, individual grains dominantly light to medium gray and translucent gray, clear to translucent quartz light to medium greenish gray, trace black and dark bluish green; very fine upper to medium lower, dominantly fine upper to lower; angular to trace subrounded, dominantly subangular; moderate to moderately well sorted; dominantly unconsolidated with scattered very fine medium gray sandstone;firm to moderately hard;trace to common shell fragments; 10% -40% dull yellow sample fluorescence over background levels; weak, very slow, light straw visible cut flash very pale milky yellowish white cut fluorescence; no visible residual ring, bright white residual ring fluorescence;trace light brown stain on freshly exposed sandstone surfaces;no free oil; no petroleum odor over background. Sand (11280' - 11380') = medium to medium light gray with light olive gray secondary hues overall with individual grains dominantly clear to translucent quartz,light to medium translucent gray medium to dark gray, light to medium greenish gray, trace black; very fine upper to medium lower, dominantly fine upper to lower; angular to subangular with trace subrounded; moderately well sorted; disaggregated; trace shell fragments; trace to 30%dull yellow fluorescence above background; trace, very slow pale straw visible cut; slow weak, milky yellowish white cut fluorescence; no visible residual ring; spotty yellowish white residual ring fluorescence; no staining; no free oil; no odor. Sand(11370'-11480')=medium to medium light gray with a moderate salt and pepper appearance overall, individual grains dominantly clear to translucent quartz, light to medium translucent gray light to medium greenish gray;dark gray to black;very fine upper to medium lower,dominantly fine upper to lower;angular to trace subrounded, dominantly subangular; very well sorted; unconsolidated trace to 30%dull yellow sample fluorescence over background; very slow, weak pale straw visible cut; moderate milky yellowish white cut fluorescence; no residual visible ring; weak, spotty yellow residual ring fluorescence; no stain; no free oil; no odor above background level Sand (11450'-11560')=medium light gray with light greenish gray secondary hues and moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz,light to medium gray,light to dark greenish gray, black and trace dark bluish green glauconite nodules; very fine upper to medium lower dominantly fine grain; angular to subangular with trace subrounded; very well sorted; unconsolidated; no staining; trace to 40% dull yellow fluorescence above background levels; slow, pale straw visible cut; moderately fast milky yellowish white cut fluorescence;trace spotty very pale straw residual ring and yellowish white residual fluorescence; no free oil; no odor. 26 CANRIG NIKAITCHUQ OP12-01 ena Sand (11550' - 11660') = medium to medium light gray overall with a slight to moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz,light to medium translucent gray,light to medium greenish gray, medium to dark gray, trace black; very fine upper to medium lower, dominantly fine upper to lower;angular to trace subrounded,dominantly subangular;very well sorted;disaggregated;trace to 40% dull yellow fluorescence above oil base mud background levels; weak, slow pale straw visible cut; moderately fast, milky yellowish white cut fluorescence; very weak, spotty pale straw residual ring; spotty bright whitish yellow residual fluorescence; no staining; no free oil; no petroleum odor above background levels. Sand (11660' - 11760') = medium gray with light olive secondary hue and moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz,light to medium gray, light greenish gray, black and trace bluish green glauconite nodules; very fine upper to medium lower, dominantly fine upper to lower; angular to subangular; very well sorted; unconsolidated; trace to abundant pinkish orange shell fragments; 20% -60% dull yellow fluorescence; very slow, weak, pale straw visible cut; instant very milky yellowish white cut fluorescence; trace weak, spotty, pale straw residual ring; spotty, bright whitish yellow residual ring fluorescence; no staining; no free oil; no odor. Siltstone(11787' -11808')= note thin siltstone bed in dominantly sand formation; medium to medium light gray with light brown to olive secondary hues;firm to occasionally hard; irregular to splintery shaped; silty to clayey to ashy texture; dull, earthy luster; sub-blocky to subplaty; no staining; no free oil; trace to 40% dull yellow fluorescence;weak,pale straw cut and residual ring;milky yellowish white cut fluorescence and bright yellowish white residual ring fluorescence; no odor above background. Sand(11808'-11910')=medium gray to dark medium gray with olive gray sub-hues;upper very fine to lower fine grained; spherical to sub-discoidal; sub-angular to sub-rounded;very well sorted; unconsolidated sand; grain supported; texturally sub-mature; compositionally mature to sub-mature; translucent quartz with pale yellow orange shell fragments,glauconite,and black chert;even light pale green sample fluorescence;quick streaming to blooming bluish white cut;very light amber grain staining;white residual cut; no free oil;faint oil odor; porosity and permeability visually good. Sand(11910'-12000')=medium dark gray to medium gray with olive gray sub-tones;upper very fine to lower fine grained with some upper fine to lower coarse grains; spherical to sub-discoidal; sub-angular to sub- rounded; very well sorted; sand is unconsolidated; grain supported; sub-mature texture; compositionally mature to sub-mature;translucent quartz with pale yellow orange shell fragments,glauconite,and black chert; even pale green sample fluorescence; streaming to blooming bluish white sample cut with white halo;white residual cut; very light amber grain staining; no free oil; porosity and permeability visually good. Sand(12000'-12090')=dark gray to medium dark gray with olive gray sub-hues; upper very fine to lower fine grains with occasional upper fine and lower coarse grains; spherical to sub-discoidal; sub-rounded to sub- angular; very well sorted; unconsolidated sand; grain supported; sub-mature texture; mature to sub-mature compositionally;translucent quartz with light pale yellow orange shell fragments,glauconite,and black chert; sample fluorescence even light to medium green;streaming to blooming bluish white cut with white ring;light white residual cut; very light amber grain staining; no free oil; porosity and permeability visually good. Sand (12090' - 12210') = dark medium gray to medium gray; with olive gray sub-tones; upper very fine to lower fine grained with some upper fine and lower coarse grains; sub-discoidal to spherical; sub-angular to sub-rounded;very well rounded;sand unconsolidated;grain supported;sub-mature texture;compositionally mature to sub-mature;translucent quartz with pale yellow orange shell fragments,glauconite,and black chert; sample fluorescence even light green;streaming bluish white cut with white halo; light white residual cut;very light amber grain staining; no free oil; porosity and permeability visually good. Siltstone(12200'-12290')=dark gray to grayish black;friable to easily friable hardness;poorly to moderately indurated; teancity brittle to crumbly; irregular fracture; cuttings habit is sub-nodular, massive or elongated; luster is dull to earthy; silty to gritty texture; laminae structure defined by black carbonaceous material and erosional patterns;70%light green sample fluorescence; instantaneous blooming bluish white cut;light white 27 CANRIG NIKAITCHUQ OP12-01 en' residual cut; slight oil odor; no free oil; amber stain when breaking open siltstone. Sand(12290'-12390')=dark gray to medium dark gray; upper very fine to lower fine with occasional upper fine and lower medium grains;spherical to sub-discoidal;sub-angular to sub-rounded;very well sorted;sand is unconsolidated; grain supported; texturally sub-mature; compositionally mature to sub-mature; translucent quartz with glauconite, pale yellow orange shell fragments and black chert; sample fluoresces even light green;cut is instantaneous streaming to blooming bluish white cut with white halo;residual cut faint white;pale amber staining on grains; no free oil; porosity and permeability visually good. Sand (12390' -12480')=dark gray to medium dark gray; upper very fine to lower fine with some upper fine and lower medium sand grains; sub-discoidal to spherical; sub-rounded to sub-angular; very well sorted; unconsolidated sand; grain supported; sub-mature texturally; mature to sub-mature compositionally; translucent quartz with glauconite, black chert, and pale yellow orange shell fragments; even light green sample fluorescence; instantaneous streaming to blooming bluish white cut with white ring; residual cut faint white; pale amber staining on grains; no free oil; porosity and permeability visually good. Sand(12490'-12600')=medium to medium light gray with light olive gray and light greenish gray secondary hues overall, individual grains dominantly clear to translucent quartz, light to medium translucent gray, light greenish gray, trace black and dark greenish blue glauconite nodules; very fine lower to medium lower, dominantly fine upper to lower;angular to trace subrounded,dominantly subangular;moderate to moderately well sorted; unconsolidated; trace pinkish orange shell fragments; trace medium gray to grayish brown siltstone;20%-50%dull yellow fluorescence above background levels;faint pale straw visible cut;fast milky yellowish white cut fluorescence; pale straw visible residual ring; bright yellowish white residual ring fluorescence; no staining; no free oil; no odor above oil base mud background levels. "OA"SAND Sub-layer 2 bottom at 12610.0' MD/-3579.9' TVDSS "OA"SAND Sub-layer 3 bottom at 12680.0' MD/-3575.0' TVDSS Sand/Sandstone(12600'-12720') = medium to medium light gray with greenish gray and brownish gray secondary hues, individual grains dominantly light to medium translucent gray, clear to translucent quartz, medium gray,greenish gray,black;sandstone pieces show same general color characteristics with fine grain dark bluish green glauconite nodules interbedded;very fine lower to rare medium upper,dominantly fine grain angular to subangular; dominantly grain supported; firm to friable; well sorted; very fine grain sandstone commonly grade to sandy siltstone/silty sandstone; 20% -70% dull yellow fluorescence; weak pale straw visible cut;fast, milky yellow cut fluorescence;weak pale straw residual ring; bright yellowish white residual ring fluorescence;medium to dark brown stain on freshly exposed sandstone surfaces;no free oil;slight odor above background levels. Sand/Sandstone(12720'-12800')= medium gray overall with individual grains dominantly medium gray, light to medium translucent gray, light to medium greenish gray, clear to translucent quartz,trace black;very fine lower to medium lower, dominantly fine; angular to sub-rounded, dominantly subangular; moderately sorted; sandstone is grain supported; firm to friable and brittle; commonly grading to sandy siltstone/silty sandstone; 10% - 40% dull yellow fluorescence; slow, pale straw visible cut; flash milky yellow cut fluorescence;weak,pale straw residual ring;bright yellowish white residual ring fluorescence;no staining;no free oil; no odor above background levels. "OA" SAND Top at 12760.0' MD/-3569.7'TVDSS Siltstone (12760' - 12860') = medium to medium dark gray with olive gray secondary hues; firm to slightly hard, occasionally fragile; irregular to sub-tabular shaped cuttings; silty to slightly gritty texture; dull, earthy luster; commonly grades to silty sandstone/ sandy siltstone;20% - 60% dull yellow fluorescence above background; instant flash, milky yellowish white cut fluorescence; weak, pale straw visible cut and spotty residual ring; bright yellowish white residual ring fluorescence; no stain; no free oil. FINAL TD at 12860.0' MD/-3561.4 TVDSS 28 CANRIG iik NIKAITCHUQ OP12-01 enw s PEAKS Depth TG C1 C2 C3 C4I C4N C5I C5N 5310 104 19580 191 150 77 104 51 32 5409 777 119203 1784 1760 1038 1361 730 485 5450 1256 182650 2744 2564 1402 1878 956 636 5474 1123 174750 2564 2439 1397 1883 1015 671 5503 471 76155 110 1149 727 986 577 387 5661 211 37309 199 142 61 72 37 23 6093 387 82830 472 361 168 230 129 69 6315 548 108185 666 423 206 280 153 119 6648 504 70113 515 340 179 294 181 172 6736 409 65098 446 333 183 315 188 194 7274 376 67947 548 427 304 382 264 175 7752 351 66204 397 218 148 179 133 91 7992 306 57275 336 171 121 150 73 118 8134 409 18010 476 231 181 215 171 106 8426 368 60996 343 146 112 126 97 65 8905 463 85849 414 145 85 91 46 38 9212 489 89154 448 169 113 124 72 44 10014 370 67590 348 144 104 136 80 57 10246 353 66641 376 117 122 142 108 84 10535 293 54397 322 157 112 130 90 71 10728 296 55139 332 162 112 127 94 73 10814 280 50739 279 143 106 131 94 78 11293 218 41603 247 126 87 108 74 62 11581 269 50236 322 166 126 136 93 64 11718 250 46643 297 161 118 144 100 76 11878 254 44793 259 127 83 102 78 69 12390 262 49924 284 139 102 120 77 62 12452 280 51701 330 171 124 141 99 70 YRI7 29 cA NIKAITCHUQ OP12-01 eni - r 3.6 Connection Gases 1 unit=0.05% Methane Equivalent Depth Gas over BGG (feet) (units) 9194 105 3.7 Trip(Wiper)Gases 1unit=0.05% Methane Equivalent Depth Trip to Gas (feet) (feet) (units) 5527 surface 190 5527 surface 119 5527 surface 64 12860 8600 22 R�7 30 C Pk NIKAITCHUQ OP12-01 eni s 3.8 Sampling Program/Sample Dispatch Set Type/Purpose Frequency Interval Dispatched to Washed-and-dried Fugro Data Solutions A Reference Samples, 30'/20' 1000' -5520' 3311 S. US Hwy 77 Set Owner: ENI per plan Schulenburg, TX 78956 Washed-and-dried AOGCC B Reference Samples, per plan 1000' -5520' 333 W. 7TH Ave., Suite 100 Set Owner: State of Alaska Anchorage,AK 99501 Washed, Spin-dried Fugro Data Solutions C Reference Samples (vials), 30 5520'—12860' 3311 S. US Hwy 77 Set Owner: ENI per plan Schulenburg, TX 78956 Washed, Spin-dried AOGCC 0' D Reference Samples(vials), per plan 5520'- 12860' 333 W. 7TH Ave., Suite 100 Set Owner: State of Alaska Anchorage,AK 99501 CANR1G 31 Pit NIKAITCHUQ OP12-01 en - i 3.9 Approved Sample Plan OP12-01 Dry samples: (2 sets) Every 30' from 1000' to TD (-12,710' MD). Note: increase to 20' plus peak samples intervals in the N Sand. No Wet Samples Iso-Tubes: None required Note: sample on 100' intervals for any show in the Ugnu. Canned Cuttings Samples: (In Iso-Jars) None required. Note: sample on 100' intervals for any show in the Ugnu. Over the Schrader Bluff N-Sand,sample frequency is increased as specified,beginning 100'above the listed "N-Sand" and continuing to 30' past the predicted base of the N-Sand. Confirm with the Wellsite Geologist before stopping 20' samples to make sure we are through the base of the interval. 20' Samples beginning at 5190'to 100' beyond thw top of the OA sand, or Casing TD. N Sand Top: 4,628' and (-3,380'tvdss) N Sand Bottom:4,737' and (-3,421'tvdss) 32 CANRIG u) a E az M u)) 0 N o N M CD 0 00 X aa) m En U U cas 0 as Iii a O W a) a c o H cu 0'5 0 0 g 3aaiaS n TD m c o as y N _o .c Iii c 0 a 5 W I- U .Q a)a) N O N z u c o. a J .-• N cr, co D O_ D D > II u) • a) U a) it W N N a QN J > -J -a O a i2 2 W aj a)4 O H 0. , c •c O N N a a) 1 O Z u) c U c M X c L( co A aC7 • a N N 2 a O• A cd C 2 a a � D o co •• c p W O d U C .r _c I' II > 0 a 0 O .-. i U E O •c w a d 0 Q co O N CO C .- a N N• 2 Q. co co O) aj N N O -p : 3 Ws C ..--, c 0 o co @ J •C a ui N ui (n O V) O o_ co V) l� U) N V o_a a)) N 0 E N- CD • ca N +• X c N O 1- Ch el C .a)7, o .. a c 0 a) i E a as N N E H O �- N c w O -o—' omy 0 a U) a o ' _O-� o T2 .c = c 0 E O ▪ .-. O ^ uu)) a"a) �. 0 O C C.) N > U . . y Q d Q g, 1 N as Q a) N a a) to N C O E rnCDa E o °) a a e c O uJ Cli e. v O 0 .O ), O N O+ 3 a -c aa)i a% v o o �? � � a0 5 —° �n3 ru ca 'a O ca y w o N C c a cam U) a (6 F- c o a >, U) O o Nco - a 0 Oc }. Z mr o 0 y 0 a) o a € o H- rn o a J u y >. U) II p 0 0 o al 0 CN v) ) 0 c 34 Q- c00 °o ao oo I- o c c ca � W N = 6ba• 3a CO _c c 3 Z r \ c C 7 C ,U >,w p L N V) O o 3 e CO CO o f/1 N N •- N o Q u) co I R p t, Oc) 0) c I I V c 3 0 v, a •. W E O R o O a a ca O a V H > a) it r E 0 U c U) O a W c0 O C d J p a • >; L N y (a E II E a)CL O ' a s c as Cl,- 0 QC v0 0 t ° a LL ,� U) U) U o a o a) a) H w y E a) w voi b coi c a = a W (� o m a � m yH c .a_) �• re 0 I. TA `� mu'� C7c° mv�oi a >, a) o � � aa, aQa) N H c y 7. O o � aa c) c U a) n u) a) Cl) a W a R m c m li c � m � w � �3 a' E °r : 12 >, a � o amp m aS LL . c L a m L >, rn d ui d w •c - C N > o a, o I- ° co •- m .N 3 0 CD la a) a) O O N a) u) _c _ca V Z a F- .S0Q u- t- co 0- Pk NIKAITCHUQ OP12-01 eni 5 DRILLING DATA 5.1 Survey Data Measured True Vertical Latitude Departure Dogleg Incl. Azim. Depth Vertical Section (ft) (ft) Rate (ft) (°) (°) Depth(ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 112.70 0.26 6.04 112.70 0.17 0.25 0.03 0.23 179.91 0.77 308.58 179.90 0.72 0.69 -0.31 0.99 236.10 2.17 320.77 236.08 2.16 1.75 -1.28 2.54 278.07 2.29 323.20 278.02 3.79 3.03 -2.28 0.36 308.27 2.63 321.90 308.18 5.08 4.06 -3.07 1.14 340.55 2.92 322.48 340.43 6.64 5.30 -4.03 0.91 370.36 3.15 322.45 370.20 8.22 6.55 -4.99 0.76 407.22 3.17 318.98 407.00 10.25 8.12 -6.28 0.52 459.95 2.94 332.41 459.66 13.02 10.42 -7.86 1.42 491.29 3.29 328.69 490.95 14.69 11.90 -8.70 1.29 522.36 3.77 331.34 521.97 16.57 13.56 -9.65 1.61 552.02 4.52 333.78 551.55 18.66 15.46 -10.64 2.61 585.87 5.31 333.16 585.27 21.47 18.05 -11.93 2.33 616.51 6.12 331.14 615.76 24.44 20.75 -13.36 2.72 644.64 7.05 327.23 643.71 27.62 23.51 -15.02 3.68 678.52 7.34 326.37 677.31 31.83 27.06 -17.34 0.92 740.99 9.58 323.33 739.10 40.97 34.56 -22.66 3.64 836.75 11.94 322.50 833.17 58.81 48.81 -33.44 2.48 932.50 16.51 321.34 925.96 82.31 67.30 -47.98 4.78 1028.54 17.97 326.04 1017.69 110.67 90.24 -64.79 2.10 1124.12 21.95 325.72 1107.51 143.07 117.24 -83.09 4.17 1220.30 27.38 324.72 1194.88 182.99 150.18 -106.01 5.66 1279.80 27.57 325.01 1247.67 210.31 172.63 -121.80 0.39 34 CANRIG Pit NIKAITCHUQ OP12-01 eni Measured True Vertical Latitude Departure Dogleg Incl. Azim. Depth ° Vertical Section (ft) (ft) Rate (ft) Depth (ft) (ft) N(+),S(-) E(+),W(-) 0100ft) 1375.89 32.37 325.07 1330.89 258.06 211.96 -149.30 5.00 1469.58 31.67 326.51 1410.32 307.41 253.03 -177.23 1.11 1565.02 27.75 326.51 1493.20 354.33 292.47 -203.33 4.11 1661.07 26.33 325.25 1578.75 397.71 328.62 -227.81 1.59 1756.27 28.53 324.51 1663.24 441.35 364.49 -253.04 2.34 1852.29 30.32 324.98 1746.87 488.31 403.01 -280.27 1.88 1948.07 34.40 324.23 1827.76 539.35 444.78 -309.97 4.28 2043.97 37.78 324.33 1905.25 595.62 490.64 -342.94 3.53 2141.44 41.23 325.66 1980.44 657.31 541.43 -378.48 3.64 2237.48 44.07 325.68 2051.07 721.97 595.16 -415.18 2.96 2333.48 48.70 327.89 2117.28 790.85 653.31 -453.19 5.10 2495.97 53.04 329.92 2219.81 915.08 761.25 -518.21 2.84 2591.82 53.72 329.74 2276.98 990.72 827.75 -556.87 0.73 2687.70 52.54 330.95 2334.51 1066.01 894.41 -594.82 1.59 2783.68 52.73 333.26 2392.77 1140.39 961.82 -630.51 1.92 2880.79 52.69 334.13 2451.60 1215.23 1031.08 -664.75 0.71 2975.81 52.94 333.89 2509.03 1288.46 1099.12 -697.92 0.33 3072.16 52.87 333.16 2567.14 1362.96 1167.91 -732.18 0.61 3167.40 52.73 332.49 2624.72 1436.72 1235.40 -766.83 0.58 3263.26 52.77 331.17 2682.75 1511.21 1302.66 -802.85 1.10 3359.69 52.77 331.57 2741.09 1586.30 1370.06 -839.64 0.33 3455.32 52.79 333.74 2798.94 1660.39 1437.69 -874.61 1.81 3551.20 52.81 334.79 2856.91 1734.17 1506.49 -907.77 0.87 3645.63 52.76 335.40 2914.02 1806.54 1574.69 -939.44 0.52 3740.84 53.04 333.85 2971.46 1879.78 1643.30 -971.98 1.33 3836.61 52.97 331.87 3029.09 1954.14 1711.36 -1006.87 1.65 3932.61 53.09 331.00 3086.82 2029.13 1778.72 -1043.55 0.73 4028.18 53.49 329.14 3143.96 2104.39 1845.12 -1081.77 1.62 Measured Incl. Azim. True Vertical Latitude Departure Dogleg I 35 CANRIG NIKAITCHUQ OP12-01 eni - Depth (°) (°) Vertical Section (ft) (ft) Rate (ft) Depth (ft) (ft) N(+),S(-) E(+),W(-) (°/100ft) 4123.83 54.78 328.40 3199.99 2180.86 1911.39 -1121.96 1.49 4219.15 57.25 326.91 3253.27 2259.05 1978.15 -1164.26 2.90 4315.64 60.43 326.29 3303.19 2340.94 2047.07 -1209.71 3.34 4411.78 64.17 325.17 3347.88 2425.52 2117.39 -1257.64 4.02 4507.44 67.40 323.44 3387.11 2512.42 2188.22 -1308.55 3.76 4602.24 68.38 322.06 3422.79 2600.08 2258.13 -1361.71 1.70 4698.29 68.87 320.89 3457.80 2689.46 2328.10 -1417.43 1.24 4793.02 69.20 319.00 3491.70 2777.91 2395.81 -1474.35 1.90 4889.04 72.35 317.60 3523.31 2868.55 2463.48 -1534.66 3.56 4984.93 76.12 316.37 3549.36 2960.73 2530.94 -1597.61 4.12 5080.50 79.74 315.91 3569.34 3054.03 2598.31 -1662.36 3.82 5176.40 83.32 314.76 3583.47 3148.64 2665.76 -1729.03 3.92 5272.06 84.44 312.60 3593.67 3243.29 2731.44 -1797.81 2.53 5367.80 83.86 310.20 3603.43 3337.61 2794.42 -1869.24 2.57 5461.97 84.15 309.35 3613.26 3429.97 2854.34 -1941.22 0.95 5577.24 85.03 310.83 3624.13 3543.24 2928.24 -2029.01 1.49 5673.03 87.15 311.04 3630.66 3637.78 2990.85 -2101.20 2.22 5768.74 87.35 311.03 3635.25 3732.38 3053.61 -2173.32 0.21 5864.50 88.87 312.47 3638.41 3827.25 3117.34 -2244.72 2.19 5959.28 89.74 312.84 3639.56 3921.38 3181.56 -2314.42 1.00 6055.33 90.53 312.68 3639.33 4016.80 3246.77 -2384.93 0.84 6151.60 90.30 315.42 3638.64 4112.65 3313.69 -2454.12 2.86 6246.85 89.28 317.29 3638.99 4207.77 3382.61 -2519.85 2.24 6342.03 88.43 316.55 3640.89 4302.84 3452.12 -2584.85 1.18 6439.15 88.99 319.55 3643.07 4399.90 3524.32 -2649.75 3.14 6535.19 90.17 320.64 3643.78 4495.93 3597.99 -2711.36 1.67 6630.55 91.10 321.28 3642.72 4591.24 3672.05 -2771.42 1.18 6726.87 91.14 322.43 3640.84 4687.45 3747.79 -2830.90 1.19 6822.58 88.64 319.84 3641.02 4783.09 3822.30 -2890.94 3.76 Measured Incl. Azim. True Vertical Latitude Departure Dogleg Depth (°) (°) Vertical Section (ft) (ft) Rate 36 CANRIG NIKAITCHUQ OP12-01 eni (ft) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 6918.33 91.43 320.73 3640.96 4878.82 3895.94 -2952.12 3.06 7014.14 90.93 320.95 3638.99 4974.58 3970.22 -3012.61 0.57 7109.05 91.32 320.98 3637.13 5069.43 4043.93 -3072.37 0.41 7204.59 91.36 320.97 3634.89 5164.90 4118.13 -3132.51 0.04 7299.91 91.80 321.56 3632.27 5260.13 4192.45 -3192.13 0.77 7395.16 92.03 322.28 3629.08 5355.23 4267.39 -3250.84 0.79 7489.01 92.24 321.75 3625.59 5448.91 4341.31 -3308.56 0.61 7585.12 90.47 320.87 3623.31 5544.93 4416.30 -3368.62 2.06 7680.12 89.91 320.94 3623.00 5639.89 4490.03 -3428.53 0.59 7775.42 89.66 320.06 3623.36 5735.17 4563.56 -3489.15 0.96 7870.98 89.48 317.73 3624.07 5830.72 4635.56 -3551.97 2.45 7967.06 89.60 317.12 3624.84 5926.74 4706.31 -3616.97 0.65 8063.03 89.97 318.14 3625.21 6022.67 4777.21 -3681.64 1.13 8157.45 88.75 317.68 3626.26 6117.05 4847.27 -3744.93 1.38 8253.59 89.35 317.79 3627.85 6213.14 4918.41 -3809.58 0.63 8349.58 87.01 316.04 3630.90 6308.99 4988.47 -3875.11 3.04 8446.39 88.27 315.73 3634.89 6405.54 5057.92 -3942.44 1.34 8542.21 87.38 315.27 3638.53 6501.08 5126.21 -4009.55 1.05 8636.41 88.04 315.45 3642.29 6594.98 5193.18 -4075.68 0.73 8732.78 89.67 317.25 3644.21 6691.19 5262.90 -4142.19 2.52 8828.67 88.00 314.44 3646.16 6786.87 5331.67 -4208.96 3.41 8924.20 88.13 313.40 3649.39 6881.92 5397.90 -4277.73 1.10 9020.44 89.31 313.43 3651.54 6977.63 5464.02 -4347.62 1.23 9116.06 89.28 312.09 3652.72 7072.61 5528.94 -4417.82 1.40 9210.74 89.45 312.92 3653.77 7166.62 5592.90 -4487.61 0.89 9306.46 89.88 313.81 3654.33 7261.82 5658.63 -4557.20 1.03 9402.94 90.61 315.74 3653.91 7357.99 5726.57 -4625.68 2.14 9498.12 89.52 314.48 3653.81 7452.91 5794.00 -4692.85 1.75 9594.33 90.00 314.83 3654.21 7548.80 5861.62 -4761.29 0.62 9690.05 92.41 314.88 _ 3652.20 7644.20 5929.12 -4829.13 2.52 Measured Incl. Azim. True Vertical Latitude Departure Dogleg Depth (°) (°) Vertical Section (ft) (ft) Rate 37 CANRIG NIKAITCHUQ OP12-01 eni (ft) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 9786.02 91.48 313.20 3648.94 7739.70 5995.79 -4898.07 2.00 9879.94 93.02 311.37 3645.25 7832.84 6058.93 -4967.50 2.55 9977.07 90.85 310.61 3641.97 7928.88 6122.60 -5040.77 2.37 10073.55 89.62 310.63 3641.58 8024.25 6185.41 -5114.00 1.28 10169.50 91.20 311.51 3640.89 8119.20 6248.44 -5186.33 1.88 10265.46 91.40 312.07 3638.71 8214.31 6312.37 -5257.86 0.62 10360.77 90.08 311.49 3637.48 8308.78 6375.87 -5328.92 1.51 10457.20 89.23 311.87 3638.06 8404.35 6439.99 -5400.94 0.97 10552.65 89.95 312.30 3638.74 8499.04 6503.96 -5471.78 0.88 10648.66 90.16 314.56 3638.65 8594.54 6569.96 -5541.50 2.36 10744.14 90.95 315.96 3637.73 8689.77 6637.77 -5608.70 1.68 10838.27 91.20 317.14 3635.96 8783.77 6706.10 -5673.42 1.28 10934.19 88.83 316.61 3635.94 8879.60 6776.10 -5738.99 2.53 11030.99 88.43 316.13 3638.25 8976.24 6846.14 -5805.76 0.65 11124.30 87.85 315.69 3641.28 9069.34 6913.13 -5870.65 0.78 11221.16 87.88 315.70 3644.89 9165.94 6982.39 -5938.26 0.03 11316.56 89.89 317.96 3646.74 9261.22 7051.95 -6003.51 3.17 11412.27 89.92 319.75 3646.90 9356.92 7124.02 -6066.48 1.87 11506.10 89.84 320.86 3647.10 9450.74 7196.22 -6126.40 1.19 11599.87 89.34 321.16 3647.77 9544.46 7269.10 -6185.40 0.62 11698.10 89.17 322.16 3649.05 9642.60 7346.14 -6246.33 1.03 11796.50 88.83 323.59 3650.77 9740.79 7424.58 -6305.71 1.49 11890.21 88.60 323.85 3652.87 9834.20 7500.11 -6361.15 0.37 11984.30 88.29 323.21 3655.42 9928.00 7575.74 -6417.05 0.76 12078.97 89.56 323.82 3657.20 10022.40 7651.84 -6473.33 1.49 12178.81 91.72 324.94 3656.08 10121.84 7732.99 -6531.47 2.44 12273.98 91.93 324.15 3653.05 10216.56 7810.47 -6586.65 0.86 12371.19 93.05 322.86 3648.83 10313.42 7888.54 -6644.41 1.76 12466.67 93.07 322.05 3643.73 10408.62 7964.14 -6702.51 0.85 12561.72 93.96 321.67 3637.90 10503.40 8038.76 -6761.10 1.02 Measured I Incl. I Azim. I True Vertical Latitude I Departure I Dogleg 38 CANRIG NIKAITCHUQ OP12-01 ena Depth (°) (°) Vertical Section (ft) (ft) Rate (ft) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 12657.01 94.04 320.20 3631.25 10598.41 8112.56 -6821.00 1.54 12752.88 93.64 317.80 3624.83 10694.06 8184.75 -6883.75 2.53 12795.76 94.94 317.88 3621.63 10736.80 8216.44 -6912.45 3.04 12860.00 94.94 317.88 3616.09 10800.79 8263.91 -6955.38 0.00 12657.01 94.04 320.20 3631.25 10598.41 8112.56 -6821.00 1.54 12752.88 93.64 317.80 3624.83 10694.06 8184.75 -6883.75 2.53 12795.76 94.94 317.88 3621.63 10736.80 8216.44 -6912.45 3.04 12860.00 94.94 317.88 3616.09 10800.79 8263.91 -6955.38 0.00 39 CANRIG Q I N C) LO CO 0 0 0 17 H p v 0 17 O Z o i r Z Z co W T a X x v) 1- 0!) m M r M N M ^ N C')d Q 7:-. O. , '4) co r- N M m N 3 r Y a Q 0 M v c(0 o +, N rn u) o N m = N Nt co a 0 7 —u. d o N. M 1 _ U - Q�Q 0 0 N M N g. Y Z C ` 0O N co d N L.0 0 N Q O (0 (0 N M H 7 M (0 .- co o U to p •� y °v a 0 N o U) a rn N Lo C. ■ o H CO X N C'1 Ce X 2 a rn 0) ✓• 0 t O t c[ 2 co >, m a+ I I m N in N ) .- N CO � N r m ,_ N M V - 0 0 0 0 0 0 0 0 0 0 0 0 Co CO v v CO r0 C) CO v v 0 0 0 0 0 0 0 0 0 0 0 0 °O °o °o LII ( E M 0 0 N N 0 O N O O O O O COO ..r U) If) I 0o Cn M Co Co Cr) C0 Cr) CO N Cn LO G. CA CA CA 00 CO CA 0 O O O 00 O i- LO N U) U) L m N N N N N i N r CD r r • N N r r r T- In En e U) I O O O CV A- O i i O O G M co M in in r O O O O N Cr) r O r Co In O O CT O CA O CA O CA CA N N N O O co \ \ \ \ \ M M M M M CO N- 0) CO f� f • f• N A- 0 - H LO LO LO N C ° CO CO CD O 1 ~ ~ CD CCi LC) O L - Y. a) LL. tt►►�� a (0 In In Y D u) -I v Cn N N N In Co CO 2 ; IL CO 00 f� I� r 00 In 4 4 4 Ln I I I V I- - Y N 0) O en in Nr M Cr; O 7— N M N N r CO C7 C7 Z N 00 r -a r M O 45 Lo N CD • CB M M V' O N N N . Cn N N N O 17 0�0 I Co N M M In N Cr) r r r r r N LC) _ O O 0) 0 In N- N- Cr) 0 I- 0 M CO Cr C) >- N d' N N N r Cr) Cr) Cr) Cr) N r '- r r O M CV > N co N N N- O ti N- 0 CO N- N- LO N d r r N N r r N r r r N (N 0 Z Cl) J CO a r C) N O) O Cn N N 0 CO 0 CO C) O 5 N N- CO N- N- CO U) CO CO ti Cn Cn Cn N- 00 Cr) it..■• N t 0 0 00 O M In In Cn o N V' Cr) CO CO ct CA CA _ 2 C CO CO CA CA CA co CA CA CA CA O CA co O0 00 Q) r► IC) r 0 0 0 00 00 00 CO r r O CA CA o) Tr N Q 2 = 0 N 6 r N- N- N N A r r r r In r ' 00 A- N N N N Cr) Cr) M M M M M M N.• '^ 0 4) ` \ \ \ 0 0 0 \ \ \ \ \ \ \ \ \ v/ a Q N Co N- 0 0 0 O) 00 M f� N- N- N- In CD CD . Cn CI C) O .1 co M M co CO N N N N CO LO' r 0) O 'Cr 'Cr CO r If) LO LO LO CO O0 N N N N N In UC') LC) In In In V• O a, _ 2 -5` I- o O O O O O O O O o O O O O O C= a d 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CI V �' N N N N N N N N N N N N N N N R \ \ \ 0 0 \ \ \ \ \ \ N a') O CO f� CO CO O r N Cr) I- In CO h CO O A- r r r N N N N N N N N N N Cr) N- N- N I Ns N- N- N- N- N- N- N- N- N- N ca E▪. O E 1 1 1 I I I N NI- T • O O O O O O O y () O O 53 O O O _O O N • �t stf V' r- N. CO a 0) C all O Q. i I I ` 12 U 45 a) O 6 Hm CO W 1 1 1 1 1 I 1 a O— w 45 At p II ii u • I ID 1 I I I I I v' W u O 0 'cr N •;,, N N N N O 2 P. 0) 0 T N .. O C U N N N! �. C0 M N- CO c O o M LO 1.0 CA 1 1 t O co (n O CO 00 cc C N Ca• LL N d N N N II II U) o (_n LI J V I Co o o I I I L IL u U) t H g, 1 co O) Z N (0 � CO 0 CD O) Ci) O) to N O U C co ; a. N- CO •v 0 N a) w 0 ..= s as > V d N N N N N II II N -. O U > ..--. Cl)• cr co N- ° 0) N co co N co N- •i a O) CO co co O O O) iii. m C,, 00 OD 00 oO ai O o0 Cl) N O O N c0 CO c0 CO CU = co CO CO CO CO CO CO (d U• ■N- it. moil) C") M M M M M o 4 v co° (0 0m co ,a) iz I) C D ° co co co co H a) ,_ v) co O N N N N N C O cn d O 0 a -0 ID C N N _ 0 0 0 0 0 0 0 L II m 0 0 0 0 0 0 0 ° II II 0 = N M 10 (0 Q 2 U >- M O O O O o 0 N. CO CO CO CO CO CO Daily Report Page 1 of 1 ENI Petroleum PI EPOCH DAILY WELLSITE REPORT 0P12-01 REPORT FOR DAVE MORRIS DATE Jul 16,2010 DEPTH 303.00000 PRESENT OPERATION DRILLING AHEAD TIME 2400 YESTERDAY 1.00000 24 HOUR FOOTAGE 302 CASING INFORMATION 20"CONDUCTOR @ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 112.70 0.26 6.04 112.70 SURVEY DATA 179.91 0.77 308.58 179.90 236.10 2.17 320.77 236.08 BIT INFORMATION INTERVAL CONDITION REASON I NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" SMITH XR+ PM4050 3020 1016 1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 303.00000 0 @ 303.00000 0.0 20.91467 FT/HR SURFACE TORQUE 0 @ 303.00000 0 @ 303.00000 0.0 020000 AMPS WEIGHT ON BIT 0 @ 303.00000 0 @ 303.00000 0.0 729318 KLBS ROTARY RPM 0 @ 30320000 0 @ 303.00000 0.0 0.00000 RPM PUMP PRESSURE 0 @ 30320000 0 @ 303.00000 0.0 489.07385 PSI DRILLING MUD REPORT DEPTH MW 8.8 VIS 71 PV 12 YP 29 FL 17.5 Gels 25/32/57 CL- 1300 FC 4/ SOL 4 SD - OIL /96 MBL 22.5 pH 9.8 Ca+ 80 CCI MW D SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 303.00000 0 @ 303.00000 0.0 TRIP GAS CUTTING GAS 0 @ 303.00000 0 @ 303.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 0 @ 303.00000 0 @ 303.00000 0.0 CONNECTION GAS HIGH ETHANE(C-2) 0 @ 303.00000 0 @ 303.00000 0.0 AVG PROPANE(C-3) 0 @ 303.00000 0 @ 303.00000 0.0 CURRENT BUTANE(C-4) 0 @ 303.00000 0 @ 303.00000 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 303.00000 0 @ 303.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PERMAFROST PRESENT LITHOLOGY PERMAFROST DAILY ACTIVITY SUMMARY MAKE UP SPUD MUD,DRILL OUTCONDUCTOR WITH DUMB IRON,CIRUCULATE CLEAN,MAKE UP BHA,DRILL OUT EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum El EPOCH DAILY WELLSITE REPORT OP12-01 REPORT FOR Beauchamp/Morris DATE Jul17,2010 DEPTH 1069.00000 PRESENT OPERATION DRILL AHEAD TIME 24:00:00 YESTERDAY 250.00000 24 HOUR FOOTAGE 819 CASING INFORMATION 20" DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" SMITH XR+ PM4050 3020 1016 1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 320.9 @ 692.00000 4.4 @ 767.00000 92.8 12.30214 FT/HR SURFACE TORQUE 4237 @ 1027.00000 811 @ 254.00000 389.8 3855.14453 AMPS WEIGHT ON BIT 37 @ 688.00000 0 @ 452.00000 15.1 17.86287 KLBS ROTARY RPM 46 @ 1025.00000 0 @ 903.00000 7.8 39.12059 RPM PUMP PRESSURE 1378 @ 1000.00000 429 @ 251.00000 755.0 1190.92725 PSI DRILLING MUD REPORT DEPTH MW 9.0 VIS 89 PV 8 VP 40 FL 16.5 Gels 35/38/44 CL- 1950 FC 4/ SQL 5 SD 0.05 OIL /95 MBL 22.5 pH 9.5 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 1 @ 1067.00000 0 @ 761.00000 0.1 TRIP GAS 0 CUTTING GAS 0 @ 1069.00000 0 @ 1069.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 89 @ 922.00000 0 @ 1013.00000 19.4 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 1069.00000 0 @ 1013.00000 0 AVG 1 PROPANE(C-3) 0 @ 1069.00000 0 @ 1013.00000 0 CURRENT 1 BUTANE(C-4) 0 @ 1069.00000 0 @ 1013.00000 0 CURRENT BACKGROUND/AVG 1 PENTANE(C-5) 0 @ 1069.00000 0 @ 1013.00000 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION Conglomerate Sand/Sand=Grayish black to medium gray;sand is trimodal,pebble clasts,gravel and lower medium to upper medium;gravel/pebble exhibits su-prismoidal to sub-discoidal LITHOLOGY spericity while sand is spherical to sub-discoidal;all grains are subOrounded to well rounded;sand is overall poorly sorted;unconsolidated sand;cement unknown;matrix unknown;grain supported;texturally sub-mature to metre;quartz is predominate grain;pyrite overgrowth visble on some conglomerate dusts,pyrite grains also present prosotiy and permeability good;no oil indicators. PRESENT Conglomerate 20%,Conglomerate Sand 20%,Sand 30%,Claystone 30% LITHOLOGY g DAILY ACTIVITY SUMMARY Drill ahead while building angle EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY Tollef Winslow ,1__//!\_1Tl_ ___-___-_`_ ___ 1f�_..'._ __1T.__ _1_ A 1.__'._111 if Ts __ ._._111 X- 1X/_11_1TA1i1T_11_ T_._ '1/1A//1A1A Daily Report Page 1 of 1 ENI Petroleum PI EPOCH DAILY WELLSITE REPORT OP12-01 REPORT FOR DATE Jul 18,2010 DEPTH 2216.00000 PRESENT OPERATION DRILL TO SURFACE CASING TD TIME 2400 YESTERDAY 1069.00000 24 HOUR FOOTAGE 1147 CASING INFORMATION 20"CONDUCTOR DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2141.44 41.25 327.00 1980.25 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" SMITH XR+ PM4050 3x20 1x16 1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1701.3 @ 1369.00000 7.5 @ 2186.00000 155.8 200.89285 FT/HR SURFACE TORQUE 16385 @ 1948.00000 20 @ 1298.00000 1320.2 3955.36719 AMPS WEIGHT ON BIT 39 @ 1073.00000 0 @ 2166.00000 19.5 9.84243 KLBS ROTARY RPM 47 @ 2059.00000 0 @ 1688.00000 13.1 36.06731 RPM PUMP PRESSURE 1942 @ 2213.00000 492 @ 1744.00000 1343.2 1730.10120 PSI DRILLING MUD REPORT DEPTH MW 9.3 VIS 89 PV 14 YP 25 FL 8.5 Gels 18/41/47 CL- 1600 FC 2/ SOL 6.5 SD 0.2 OIL 1/93 MBL 22 pH 9.3 Car- 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 403 @ 1831.00000 0 @ 1174.00000 84.2 TRIP GAS 0 CUTTING GAS 0 @ 2216.00000 0 @ 2216.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 80020 @ 1831.00000 36 @ 1174.00000 16436.1 CONNECTION GAS HIGH 0 ETHANE(C-2) 12 @ 1292.00000 0 @ 1660.00000 0.3 AVG 84 PROPANE(C-3) 0 @ 2216.00000 0 @ 2216.00000 0.0 CURRENT 59 BUTANE(C-4) 0 @ 2216.00000 0 @ 2216.00000 0.0 CURRENT BACKGROUND/AVG 40 PENTANE(C-5) 8 @ 1292.00000 0 @ 1281.00000 0.1 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION CARBONACEOUS SHALE(2130'-2190')=DARK GRAY TO BLACK;HARDNESS IS FIRM FRIABLE TO FRIABLE;MODERATELY INDURATED;DENSE TO BRITTLE TENACITY;HACKLY LITHOLOGY FRACTURES;MASSIVE CUTTINGS HABIT;LUSTER IS RESINOUS TO GREASY;TEXTURE IS SMOOTH OR MATTE;LAMINAE BEDDING STRUCTURE;LAMINAE BEDS GRADE BETWEEN DARK CARBONACEOUS MATERIAL AND LIGHTER BROWN CARBONACEOUS MATERIAL;VERY SLIGHT OUTGASSING OBSERVED IN A NEW FRACTURE;NO OIL. PRESENT CARBONACEOUS SHALE 20%.CLAY 70%,SAND 10% LITHOLOGY DAILY ACTIVITY SUMMARY DRILL AHEAD EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIG WATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT Ell OP12-01 REPORT FOR Beauchamp/Morris DATE Jul 19,2010 DEPTH 2429.00000 PRESENT OPERATION Running 13 3/8"Casing TIME 24:00:00 YESTERDAY 2221.00000 24 HOUR FOOTAGE 208 CASING INFORMATION 20"Conductor @ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2333.48 48.52 329.24 2117.16 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" SMITH XR+ PM4050 3x20 1x16 160 2430 2270 28.9 2-3-WT-A-E- NO TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 399.1 @ 2341.00000 30.5 @ 2300.00000 195.7 188.99622 FT/HR SURFACE TORQUE 17888 0 2235.00000 145 0 2331.00000 1746.4 5654.45947 AMPS WEIGHT ON BIT 26 0 2386.00000 1 0 2324.00000 15.3 22.12824 KLBS ROTARY RPM 43 0 2395.00000 1 @ 2342.00000 14.1 40.43150 RPM PUMP PRESSURE 2017 0 2330.00000 1669 0 2347.00000 1814.0 1856.28210 PSI DRILLING MUD REPORT DEPTH MW 9.5 VIS 74 PV 22 YP 27 FL 7.2 Gels 7/17/31 CL- 1250 FC 2/ SOL 6.5 SD - OIL 1/93 MBL 20 pH 8,6 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 71 0 2349.00000 12 0 2410.00000 42.1 TRIP GAS 0 CUTTING GAS 0 0 2429.00000 0 0 2429.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 13620 0 2349.00000 2364 0 2410.00000 8034.7 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 0 2429.00000 0 0 2429.00000 0.0 AVG 0 PROPANE(C-3) 0 0 2429.00000 0 0 2429.00000 0.0 CURRENT 0 BUTANE(C-4) 0 0 2429.00000 0 0 2429.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 0 2429.00000 0 0 2429.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGV CLAY=OLIVE GRAY TO LIGHT OLIVE GRAY IN COLOR;HARDNESS IS SOFT;CLAY IS COHESIVE,PLASTIC,AND PLIABLE;CONSISTENCY IS LUMPY TO CLUMPY;TENACITY IS STIFF TO ELASTIC;FRACTURE IS IRREGULAR;CUTTINGS HABIT IS MASSIVE;LUSTER IS WAXY;NO OIL. PRESENT CLAY 100% LITHOLOGY DAILY ACTIVITY DRILL TO 2414',REAM/WASH FROM 2381'-2331,DRILL TO 2340'TD,CIRCUALTE AND CONDITION MUD,PUMP HIGH VIS SWEEP,CIRCULATE BOTTOMSU UP 4X,SHORT TRIP SUMMARY TO 691,RIH TO 2430,CURCULATE AND CONDITION MUD,PUMP HIGH VIS SWEEP,CIRUCLATE BOTTOMS UP 4X,TRIP OUT OF HOLE,LAY DOWN BHA,RIG UP TO RUN 13 3/8" CASING,RUN 13 3/8"CASING EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT El I OP12-01 REPORT FOR Beauhamp/Morris DATE Jul 20,2010 DEPTH 2430.00000 PRESENT OPERATION Nippling up BOP's TIME 24:00:00 YESTERDAY 2430.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2421' 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 9.5 VIS 56 PV 22 YP 12 FL Gels 3// CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAY=OLIVE GRAY TO LIGHT OLIVE GRAY IN COLOR;HARDNESS IS SOFT;CLAY IS COHESIVE,PLASTIC,AND PLIABLE;CONSISTENCY IS LUMPY TO CLUMPY;TENACITY IS STIFF TO ELASTIC;FRACTURE IS IRREGULAR;CUTTINGS HABIT IS MASSIVE;LUSTER IS WAXY;NO OIL. PRESENT CLAY 100% LITHOLOGY DAILY ACTIVITY RUN 13 3/8"CASING TO 2420',CIRCULATE AND CONDITION,CBU,PUMP CEMENT,RIG DOWN CEMENT/CASING TOOLS,CLEAN MUD SYSTEM,NIPPLE DOWN RISER, SUMMARY INSTALL WELHEADS,NIPPLE UP BOPS. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum El EPOCH DAILY WELLSITE REPORT OP12-01 REPORT FOR BEAUCHAMP/MORRIS DATE Jul 21,2010 DEPTH 2430.00000 PRESENT OPERATION PREPARING TO DRILL OUT TIME 24:00:00 YESTERDAY 2430.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2421' 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 2 12 1/4" Hycalog MSX619S 226208 6x16 2430 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 2421 MW 8.9 VIS 50 PV 7 YP 13 FL 0 Gels 6/8/9 CL- 400 FC .2/ SOL 4 SD OIL 1/95 MBL - pH 9.3 Ca+ 60 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 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CLAY 100% DAILY ACTIVITY NIPPLE UP BOPS,RIG UP TEST PLUG,TEST BOPS,BOPS LEAK,LAY DOWN TEST TOOL,NIPPLE DOWN BOPS CHANGE OUT LEAKING SEAL RING,NIPPLY UP BOPS,RIG UP SUMMARY TEST TOOL,TEST BOPS,LAY DOWN TEST TOOL,PICK UP BHA,CIRUCLATE/CONDITION/FILL PIPE,TRIP IN HOLE,PRESSURE TEST CASSING/SHOE TO 2500 PSI FOR 30 MIN. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum El EPOCH DAILY WELLSITE REPORT OP12-01 REPORT FOR BEAUCHAMP/SMITH DATE Jul 22,2010 DEPTH 2930.00000 PRESENT OPERATION DRILL AHEAD TIME 24:00:00 YESTERDAY 2430.00000 24 HOUR FOOTAGE 500 CASING INFORMATION 13 3/8"@ 2421' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2880.79 52.72 334.35 2392.6 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" HYCALOG MSX619S 226208 6 x 16 2430 1 16" SMITH XR+ PM4050 3x20 1x16 160 2430 2270 28.9 2-3-Wi-A-E-I-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 478.5 @ 2526.00000 3.4 @ 2900.00000 153.7 28.74022 FT/HR SURFACE TORQUE 19851 @ 2879.00000 927 @ 2870.00000 5401.6 5571.99512 AMPS WEIGHT ON BIT 25 @ 2897.00000 0 @ 2480.00000 6.5 14.94804 KLBS ROTARY RPM 119 @ 2882.00000 56 @ 2452.00000 83.3 100.76130 RPM PUMP PRESSURE 1366 @ 2879.00000 469 @ 2515.00000 993.2 1266.17200 PSI DRILLING MUD REPORT DEPTH 284P'MD/2426'TVD MW 9.0 VIS 45 PV 5 YP 30 FL 8 Gels 9/10/11 CL- 450 FC - SOL 4 SD 0.05 OIL 1/95 MBL 2 pH 9.6 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 83 @ 2926.00000 0 @ 2437.00000 17.3 TRIP GAS 0 CUTTING GAS 0 @ 2930.00000 0 @ 2930.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 16151 @ 2926.00000 46 @ 2437.00000 3277.3 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 2930.00000 0 @ 2930.00000 0.0 AVG 10 PROPANE(C-3) 0 @ 2930.00000 0 @ 2930.00000 0.0 CURRENT 65 BUTANE(C-4) 0 @ 2930.00000 0 @ 2930.00000 0.0 CURRENT BACKGROUND/AVG 55 PENTANE(C-5) 0 @ 2930.00000 0 @ 2930.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION CARBONACEOUS SHALE=GRAYISH BLACK TO BLACK;FIRM FRIABLE HARDNESS;POORLY TO POORLY MODERATE INDURATION;TENACITY IS BRITTLE TO DENSE;PLANAR LITHOLOGY AND IRREGULAR FRACTURE;CUTTINGS HABIT IS MASSIVE;WAXY TO DULL LUSTER;TEXTURE IS GRITTY;STRUCTURE IS COMPOSED OF ALTERNATING BLACK AND REDDISH BROWN LAMINATIONS OF CARBONACEOUS MATERIAL;NO OUTGASSING OBSERVED;NO OIL INDICATORS. PRESENT CARBONACEOUS SHALE 100% LITHOLOGY DAILY ACTIVITY SUMMARY DRILL OUT PLUG,DRILL OUT CEMENT,DISPLACE DRILLING FLUID WITH LSND,FIT EMW 13.7,DRILL AHEAD. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum PI EPOCH DAILY WELLSITE REPORT OP12-01 REPORT FOR BEAUCHAMP/SMITH DATE Jul 23,2010 DEPTH 4345.00000 PRESENT OPERATION DRILLING AHEAD TIME 24:00:00 YESTERDAY 2930.00000 24 HOUR FOOTAGE 1415 CASING INFORMATION 13 3/8"@ 2421' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4219.15 57.29 327.60 3252.55 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" HYCALOG MSX619S 26208 6 x 16 2430 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 352.1 @ 2973.00000 4.0 @ 4059.00000 145.3 13.13734 FT/HR SURFACE TORQUE 12085 @ 3689.00000 3372 @ 3238.00000 5789.6 6860.19434 AMPS WEIGHT ON BIT 22 @ 4284.00000 0 @ 3644.00000 5.5 5.74725 KLBS ROTARY RPM 123 @ 3923.00000 69 @ 3242.00000 1084 120.36281 RPM PUMP PRESSURE 1818 @ 4322.00000 997 @ 4285.00000 1505.7 1713.70093 PSI DRILLING MUD REPORT DEPTH 4188'MD/3241'TVD MW 902 VIS 62 PV 17 YP 34 FL .0 Gels 14/21/24 CL- 1100 FC 1/ SOL 6 SD 0.2 OIL 3/91 MBL 11.25 pH 9.3 Ca+ 90 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 76 @ 2934.00000 0 @ 4252.00000 17.8 TRIP GAS 0 CUTTING GAS 0 @ 4345.00000 0 @ 4345.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 14818 @ 2934.00000 43 @ 4252.00000 3387.8 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 4345.00000 0 @ 4345.00000 0.0 AVG 12 PROPANE(C-3) 0 @ 4345,00000 0 @ 4345.00000 0.0 CURRENT 1 BUTANE(C4) 0 @ 4345.00000 0 @ 4345.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 4345.00000 0 @ 4345.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND(4170'-4290')=MEDIUM DARK GRAY TO DARK GRAY;LOWER MEDIUM TO UPPER FINE GRAINED;SPHERICAL TO SUB-DISCOIDAL;ANGULAR TO SUB-ANGLUAR LITHOLOGY ROUNDING;WELL SORTED;UNCONSOLIDATED SAND;GRAIN SUPPORTED;TEXTURALLY IMMATURE;COMPOSITIONALLY SUB-MATURE;TRANSLUCENT QUARTZ GRAINS WITH CHERT GREEN LITHICS AND BLACK LITHICS;POROSITY AND PERMEABILITY VISUALLY GOOD;NO OIL INDICATORS. PRESENT SAND 100% LITHOLOGY DAILY ACTIVITY SUMMARY ROTARTY DRILL FROM 2930'TO 4345',2-20k ON BIT EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW r'1_.///-1-\TN/l!'IT T1\.TT1ATTO AA TT\ C,T!TTTAT!-,COST'.Tl/NrIT T A TlW NTAT 1\IT'T T/l!n TW R171\TTV%11/1X7 IS TT!T '7 In A inn 1 n Daily Report Page 1 of 1 ENI Petroleum PI EPOCH DAILY WELLSITE REPORT OPt 2-01 REPORT FOR KEENER/SMITH DATE Jul 24,2010 DEPTH 5520.00000 PRESENT OPERATION DRILL AHEAD TIME 24:00:00 YESTERDAY 4345.00000 24 HOUR FOOTAGE 1175 CASING INFORMATION 13 3/8"@ 2421' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5367.8 83.88 311.24 3602.15 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" HYCALOG MSX619s 226208 6 x 16 2430 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 367.2 @ 4860.00000 2.2 @ 4350.00000 141.9 24.72595 FT/HR SURFACE TORQUE 9670 @ 4348.00000 3169 @ 5247.00000 6315.7 8206.15918 AMPS WEIGHT ON BIT 27 @ 4352.00000 0 @ 5446.00000 10.5 18.87095 KLBS ROTARY RPM 141 @ 5520.00000 72 @ 4348.00000 115.7 141.71913 RPM PUMP PRESSURE 2080 @ 5390.00000 999 @ 4405.00000 1812.7 2066.11475 PSI DRILLING MUD REPORT DEPTH 5433'MD/3641'TVD MW 9.4 VIS 62 PV 17 VP 34 FL 4.5 Gels 15/23/32 CL- 1250 FC 1/ SOL 7.5 SD 0.1 OIL 3/90 MBL 16 pH 9.6 Ca-I. 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 1262 @ 5449.00000 0 @ 4348.00000 122.1 TRIP GAS 0 CUTTING GAS 0 @ 5520.00000 0 @ 5520.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 183345 @ 5449.00000 66 @ 4348.00000 20622.2 CONNECTION GAS HIGH 0 ETHANE(C-2) 2769 @ 5449.00000 0 @ 4448.00000 249.7 AVG 122 PROPANE(C-3) 2614 @ 5448.00000 0 @ 4448.00000 171.9 CURRENT 60 BUTANE(C-4) 3376 @ 5448.00000 0 @ 4557.00000 226.0 CURRENT BACKGROUND/AVG 200 PENTANE(C-5) 1697 @ 5473.00000 0 @ 4585.00000 116.1 HYDROCARBON Shrader Bluff Production Zone SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 5390-PRESENT SAND=OLIVE GRAY TO OLIVE BLACK;LOWER VERY FINE TO UPPER FINE GRAINED;SPHERICAL TO SUB-DISCOIDAL;ROUNDED 1129 Units(1 METHANE 177519 PPM DEPTH TO SUB-ROUNDED;WELL TO VERY WELL SORTED;UNCONSOLIDATED SAND;GRAIN SUPPORTED;TEXTURALLY MATURE; unit=200 ppm ETHANE 2596 PPM COMPOSITIONALLY SUB-MATURE;TRANSLUCENT AND MILKY WHITE QUARTZ PREDOMINATE WITH CHERT,GLAUCONITE AND Methane PROPANE 2342 PPM PYRITE;SAND FLUORESCES 100%STRAW,GREENISH GOLD;SAMPLE CUTS INSTANTANEOUS BLOOMING,BRIGHT,BLUISH Equivalent) BUTANE 2920 PPM WHITE;RESIDUAL CUT 100%BRIGHT WHITE;SAND GRAINS STAINED AMBER;OIL ODOR PRESENT;FREE OIL VISIBLE AT END OF PENTANE 1393 PPM SHAKERS;POROSITY AND PERMEABILITY VISUALLY VERY GOOD. SAND=OLIVE GRAY TO OLIVE BLACK;LOWER VERY FINE TO UPPER FINE GRAINED;SPHERICAL TO SUB-DISCOIDAL;ROUNDED TO SUB-ROUNDED;WELL TO VERY WELL LITHOLOGY SORTED;UNCONSOLIDATED SAND;GRAIN SUPPORTED;TEXTURALLY MATURE;COMPOSITIONALLY SUB-MATURE;TRANSLUCENT AND MILKY WHITE QUARTZ PREDOMINATE WITH CHERT,GLAUCONITE AND PYRITE;SAND FLUORESCES 100%STRAW,GREENISH GOLD;SAMPLE CUTS INSTANTANEOUS BLOOMING,BRIGHT,BLUISH WHITE;RESIDUAL CUT 100%BRIGHT WHITE;SAND GRAINS STAINED AMBER;OIL ODOR PRESENT;FREE OIL VISIBLE AT END OF SHAKERS;POROSITY AND PERMEABILITY VISUALLY VERY GOOD. PRESENT SAND 80%CLAY 20% LITHOLOGY DAILY ACTIVITY SUMMARY ROTARY DRILL FROM 4345'TO 5520'WITH 12k WOB EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum PI EPOCH DAILY WELLSITE REPORT OP12-01 REPORT FOR Keener/Morris DATE Jul 25,2010 DEPTH 5527.00000 PRESENT OPERATION TRIP IN HOLE W/BULL NOSE HOLE OPENER. TIME 24:00:00 YESTERDAY 5520.00000 24 HOUR FOOTAGE 7 CASING INFORMATION 13 3/8"@ 2421' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5461.97' 84.15 309.27 3429.16' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" HYCALOG MSX619S 226208 6 x 16 2430 5527 3097 46.53 1-3-S-X-I-NO-TD TD 3 8" BULL NOSE HOLE OPENER(PDC) 224762 3 x 16 1 x 24 5527 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 392 @ 5522.00000 0.7 @ 5527.00000 17.6 0.65592 FT/HR SURFACE TORQUE 8206 @ 5520.00000 5695 @ 5522.00000 8095.8 6997.77100 AMPS WEIGHT ON BIT 21 0 5521.00000 15 @ 5522.00000 217 18.22276 KLBS ROTARY RPM 141 @ 5520.00000 63 @ 5524.00000 107.5 89.92826 RPM PUMP PRESSURE 2066 @ 5520.00000 1961 @ 5526.00000 2299.5 1964.04016 PSI DRILLING MUD REPORT DEPTH 5527'MD/3619'TVD MW 9.3 VIS 70 PV 20 YP 30 FL .0@ Gels 12/20/24 CL- 1100 FC 1/ SOL 7 SD 0.05 OIL 3/90 MBL 17.5 pH 9.2 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 60 @ 5520.00000 10 @ 5527.00000 29.3 TRIP GAS 0 CUTTING GAS 0 @ 5527.00000 0 @ 5527.00000 0.0 WIPER GAS 62 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 5137 @ 5520.00000 1038 @ 5526.00000 2562.7 CONNECTION GAS HIGH 0 ETHANE(C-2) 86 @ 5520.00000 10 @ 5527.00000 36.7 AVG 5 PROPANE(C-3) 151 @ 5520.00000 21 @ 5526.00000 67.5 CURRENT 0 BUTANE(C-4) 319 @ 5520.00000 50 @ 5526.00000 145.8 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 204 @ 5520.00000 22 @ 5527.00000 85.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND=OLIVE GRAY TO OLIVE BLACK;LOWER VERY FINE TO UPPER FINE GRAINED;SPHERICAL TO SUB-DISCOIDAL;ROUNDED TO SUB-ROUNDED;WELL TO VERY WELL LITHOLOGY SORTED;UNCONSOLIDATED SAND;GRAIN SUPPORTED;TEXTURALLY MATURE;COMPOSITIONALLY SUB-MATURE;TRANSLUCENT AND MILKY WHITE QUARTZ PREDOMINATE WITH CHERT,GLAUCONITE AND PYRITE;SAND FLUORESCES 100%STRAW,GREENISH GOLD;SAMPLE CUTS INSTANTANEOUS BLOOMING,BRIGHT,BLUISH WHITE;RESIDUAL CUT 100%BRIGHT WHITE;SAND GRAINS STAINED AMBER;OIL ODOR PRESENT;FREE OIL VISIBLE AT END OF SHAKERS;POROSITY AND PERMEABILITY VISUALLY VERY GOOD. PRESENT SAND 80%CLAY 20% LITHOLOGY DAILY ACTIVITY ROTARTY DRILL FROM 5520'TO 5527',CIRUCULATE AND CONDITION MUD,TRIP OUT OF HOLE,LAY DOWN BHA,PICK UP BHA WWITH BULL NOSE HOLE OPENER,TRIP IN SUMMARY HOLE TO 2400',CIRUCLATE AND CONDITION/BOTTOMS UP,CUT AND SLIP DRILL LONE,TRIP IN HOLE. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT El OP12-01 REPORT FOR KEENER/SMITH DATE Jul26,2010 DEPTH 5527.00000 PRESENT OPERATION WORK ON PIPE SKATE TIME 24:00:00 YESTERDAY 5527.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2421' 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 NO BIT 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 9.3 VIS 58 PV 16 YP 23 FL 4.8 Gels 9/17/22 CL- 1100 FC 1/ SOL 7 SD - OIL 3/90 MBL 17.5 pH 8.9 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 1 CUTTING GAS @ @ WIPER GAS 190 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY SAND 80%,CLAY 20% DAILY ACTIVITY TRIP IN HOLE TO 4600',CIRCULATE AND CONDITION FOUR BOTTOMS UP,TRIP OUT OF HOLE,LAY DOWN BHA,CHANGE RAMS,TEST BOPS RIG UP TO RUN CASING, SUMMARY RUN CASE TO 700',FIX SKATE. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum HI EPOCH DAILY WELLSITE REPORT OP12-01 REPORT FOR Keener/Smith DATE Jul 27,2010 DEPTH 5227.00000 PRESENT OPERATION Trip in hole to break down old drill pipe TIME 24:00:00 YESTERDAY 5227.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2421'9 5/8"@ 5510' 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 NO BIT 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 5527'MD/3619'TVD MW 9.3 VIS 50 PV 14 YP 18 FL 5 Gels 8/15/19 CL- 1100 FC 1/ SOL 7 SD - OIL 3/90 MBL 17.5 pH 8.5 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 128 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY SAND 80%CLAY 20% DAILY ACTIVITY RUN 9 5/8"CASING TO 5510',CIRUCLATE AND CONDITION MUD;PUMP CEMENT;RIG DOWN CASING TOOLS;CHANGE RAMS;TEST BOPS;CLEAN MUD SYSTEM/ SUMMARY DISPLACE MUD,TRIP IN HOLE WITH HWDP. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3405, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum EPOCH C} 1 DAILY WELLSITE REPORT OP12-01 REPORT FOR Keener/Smith DATE Jul 28,2010 DEPTH 5527.00000 PRESENT OPERATION Make up BHA TIME 24:00:00 YESTERDAY 5527.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2421'9 5/8"@ 5510' 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 3 8 1/2" HUGHES IADC M323 7017337 1 012 6 x 13 5527 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 5510'MD/3619'TVD MW 6.4 VIS 56 PV 17 YP 7 FL - Gels 3/5/6 CL- 51000 FC - SOL 8 SD - OIL 78/22 MBL - pH - Ca-r. - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY SAND 80%,CLAY 20% DAILY ACTIVITY SUMMARY RIH w/5"DP,POOH 5"DP and Stand back in derick,ciruclate and condition mud to 8.5 ppg,P/U M/U BH#5. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT OP12-01 REPORT FOR KEENER/SMITH DATE Jul 29,2010 DEPTH 6110.00000 PRESENT OPERATION DRILLING AHEAD TIME 24:00:00 YESTERDAY 5527.00000 24 HOUR FOOTAGE 583 CASING INFORMATION 13 3/8"@ 2421'9 5/8"@ 5510' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6055.33'; 90.46 311.12 3639.87' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 1/2" HUGHES IADC MM323 7017337 1 x 12 6 X 13 5527 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 494.2 @ 5900.00000 0.7 @ 5527.00000 208.8 199.42389 FT/HR SURFACE TORQUE 7255 @ 5951.00000 4223 @ 5546.00000 5313.2 5339.91113 AMPS WEIGHT ON BIT 18 @ 5527.00000 0 @ 6086.00000 4.8 2.38226 KLBS ROTARY RPM 143 @ 6013.00000 64 @ 5534.00000 127.6 140.42619 RPM PUMP PRESSURE 2368 @ 5989.00000 794 @ 6094.00000 2177.0 2312.32007 PSI DRILLING MUD REPORT DEPTH 5864/3654 MW 8.9 VIS 79 PV 27 YP 14 FL Gels 11/22/31 CL- 50000 FC - SOL 10 SD - OIL 77/23 MBL - pH - Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 387 @ 6093.00000 0 @ 5528.00000 135.0 TRIP GAS 0 CUTTING GAS 0 @ 6110.00000 0 @ 6110.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 52524 @ 5909.00000 107 @ 5528.00000 20107.2 CONNECTION GAS HIGH 0 ETHANE(C-2) 294 @ 5909.00000 0 @ 5533.00000 114.9 AVG 135 PROPANE(C-3) 284 @ 5834.00000 0 @ 5533.00000 92.6 CURRENT 157 BUTANE(C-4) 264 @ 5855.00000 0 @ 5533.00000 89.5 CURRENT BACKGROUND/AVG 150 PENTANE(C-5) 143 @ 5855.00000 0 @ 5533.00000 45.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND=OLIVE BLACK TO GRAYISH BLACK IN COLOR;UPPER VERY FINE TO LOWER FINE GRAINED;SPHERICAL TO SUB-DISCOIDAL;SUB-ANGULAR TO SUB-ROUNDED;WELL TO LITHOLOGY VERY WELL SORTED;UNCONSOLIDATED SAND;GRAIN SUPPORTED;TRANSLUCENT WITH SOME MILKY WHITE QUARTZ GRAINS WITH GLAUCONITE AND RED LITHICS;SAMPLE FLUORESCES 100%DULL GREEN WITH SOME BRIGHT YELLOW GOLD;INSTANTANEOUS WHITE BLOOMING CUT;MEDIUM STRONG OIL ODOR;LIGHT AMBER GRAIN STAINING ON MAJORITY OF GRAINS;RESIDUAL CUT LIGHT GREEN;POROSITY AND PERMEABILITY VISUALLY GOOD. PRESENT SAND 100% LITHOLOGY DAILY ACTIVITY PICK UP BHA,LOAD NUKES,PICK UP DRILL PIPE,TRIP IN HOLE,CIRUCLATE AND CONDITION MUD,PRESSURE TEST CASING/SHOE @ 3000 PSI FOR 30 MINUTES,TEST SUMMARY GOOD,DRILL CEMENT/PLUGS,DRILL FROM 5527'TO 5547',FIT/LOT TEST=12.11 EMW,DRILL FROM 5527'TO 6110. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045,RIGWATCH$1450 REPORT BY TOLLEF WINSLOW rs., rri-, ,r�.--ot 71 IIT-91 TT., •1 T T1TTTTI 7,4(-I\T-.TO,0"177• Tel sil 71 1 Tlr T\!\lIT TI..TI TTf,l XX7'VW'TT 'T/rl ll//1/,1 A Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT El OP12-01 REPORT FOR KEENER/LONGO DATE Jul 30,2010 DEPTH 8125.00000 PRESENT OPERATION DRILLING AHEAD TIME 24:00:00 YESTERDAY 6110.00000 24 HOUR FOOTAGE 2015 CASING INFORMATION 13 3/8"@ 2421'9 5/8"@ 5510' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8063.03 89.89 316.93 3628.02 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 81/7' HUGHES IADC MM323 7017337 1x12 6x13 5527 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 363.9 @ 6986.00000 6.9 @ 6804.00000 186.1 78.62322 FT/HR SURFACE TORQUE 10038 @ 8035.00000 4752 @ 6405.00000 6286.1 7471.94092 AMPS WEIGHT ON BIT 17 @ 8029.00000 0 @ 6260.00000 3.1 9.55496 KLBS ROTARY RPM 144 @ 8064.00000 81 @ 6777.00000 131.2 142.02888 RPM PUMP PRESSURE 2603 @ 8124.00000 1563 @ 6251.00000 2406.3 2498.37524 PSI DRILLING MUD REPORT DEPTH 7855/3617 MW 8.9 VIS 84 PV 25 VP 19 FL - Gels 23/26/31 CL- 46000 FC / SOL 11 SD - OIL 79/21 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 548 @ 6315.00000 1 @ 7150.00000 221.9 TRIP GAS 0 CUTTING GAS 0 @ 8125.00000 0 @ 8125.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 108185 @ 6315.00000 202 @ 7150.00000 37646.3 CONNECTION GAS HIGH 0 ETHANE(C-2) 1852 @ 6174.00000 1 @ 7149.00000 275.3 AVG 350 PROPANE(C-3) 1829 @ 6174.00000 0 @ 7149.00000 191.8 CURRENT 37 BUTANE(C-4) 3215 @ 6174.00000 1 @ 7149.00000 286.0 CURRENT BACKGROUND/AVG 100 PENTANE(C-5) 3260 @ 6174.00000 0 @ 7150.00000 209.7 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND=MEDIUM DARK GRAY TO DARK GRAY WITH OLIVE GRAY SUB-TONES;UPPER VERY FINE TO LOWER FINE GRAINED,OCCASIONAL UPPER FINE GRAIN;SPHERICAL TO LITHOLOGY SUB-DISCOIDAL;SUB-ANGULAR TO SUB-ROUNDED;VERY WELL SORTED;SAND IS UNCONSOLIDATED;GRAIN SUPPORTED;TEXTURALLY SUB-MATURE;COMPOSITIONALLY SUB-MATURE;TRANSLUCENT QUARTZ WITH GLAUCONITE,BLACK CHERT AND SHELL FRAGMENTS;CALICTE DEPOSIT FROM 8093'TO 8098';LIGHT EVEN FLUORESCENCE; INSTANTANEOUS BLOOMING BLUISH WHITE CUT;FAINT WHITE RESIDUAL CUT;NO OIL AT SHAKERS;FAINT OIL ODOR;POROSITY AND PERMEABILITY VISUALLY GOOD. PRESENT SAND 100% LITHOLOGY DAILY ACTIVITY SUMMARY ROTARY DRILL FROM 6050'TO 7080'W/2K-6K WOB,ROTARY DRILL FROM 7080'-7700'W/1K-10K WOB,ROTARY DRILL FROM 7700'TO 8115'W/2K-11K WOB. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, DML$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT El OP12-01 REPORT FOR KEENER/LONGO DATE Jul 31,2010 DEPTH 9178.00000 PRESENT OPERATION DRILLING AHEAD TIME 24:00:00 YESTERDAY 8125.00000 24 HOUR FOOTAGE 1053 CASING INFORMATION 13 3/8"@ 2421'9 5/8"@ 5510' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9116.06 89.23 310.47 3656.97 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 1/2" HUGHES IADC MM323 7017337 1x12 6x13 5527 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 5732 @ 8795.00000 9.6 @ 8127.00000 174.7 81.78844 FT/HR SURFACE TORQUE 10944 @ 8301.00000 6124 @ 8795.00000 8276.0 8357.61621 AMPS WEIGHT ON BIT 26 @ 8794.00000 0 @ 8625.00000 3.3 11.81184 KLBS ROTARY RPM 143 @ 8201.00000 71 @ 8794.00000 137.8 140.46490 RPM PUMP PRESSURE 2809 @ 9161.00000 1754 @ 8153.00000 2587.9 2098.82056 PSI DRILLING MUD REPORT DEPTH 8900/3656 MW 8.9 VIS 76 PV 21 YP 17 FL 0 Gels 21/26/28 CL- 49000 FC / SOL 11 SD - OIL 76/24 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 463 @ 8905.00000 4 @ 8795.00000 228.7 TRIP GAS 0 CUTTING GAS 0 @ 9178.00000 0 @ 9178.00000 0.0 WIPER GAS 55 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 85849 @ 8905.00000 815 @ 8795.00000 40169.6 CONNECTION GAS HIGH 105 ETHANE(C-2) 476 @ 8134.00000 3 @ 8795.00000 222.3 AVG 300 PROPANE(C-3) 262 @ 8490.00000 1 @ 8795.00000 98.5 CURRENT 281 BUTANE(C-4) 581 @ 8490.00000 7 @ 8795.00000 162.0 CURRENT BACKGROUND/AVG 300 PENTANE(C-5) 469 @ 8490.00000 6 @ 8795.00000 114.6 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND/SANDSTONE=MEDIUM DARK GRAY TO MEDIUM GRAY;UPPER VERY FINE TO LOWER FINE GRAINED WITH OCCASIONAL UPPER FINE TO LOWER MEDIUM;SPHERICAL TO SUB-DISCOIDAL;ROUNDED TO SUB-ANGULAR ROUNDING;VERY WELL SORTED;UNCONSOLIDATED SAND,SANDSTONE FRIABLE TO EASILY FRIABLE;GRAIN SUPPORTED; LITHOLOGY TEXTURALLY SUB-MATURE;COMPOSITIONALLY SUB-MATURE;TRANSLUCENT QUARTZ WITH GLAUCONITE,BLACK CHERT AND PALE ORANGE SHELL FRAGMENTS;CALCITE DEPOSITS AROUND 9120';EVEN DULL LIGHT GREEN SAMPLE FLUORESCENCE;INSTANTANEOUS BLOOMING BLUISH WHITE CUT BECOMING STREAMING,WITH WHITE HALO; RESIDUAL CUT FAINT PALE WHITE;VERY FAINT AMBER STAIN;VERY FAINT OIL ODOR;NO OIL AT SHAKERS;NO FREE OIL;POROSITY AND PERMEABILITY VISUALLY GOOD. PRESENT 100%SAND LITHOLOGY DAILY ACTIVITY SUMMARY ROATRAY DRILL TO 8796';BACK REAM FROM 8795'TO 5729';TRIP IN HOLE TO 8795'ROTARY DRILL FROM 8796'TO 9178'WITH 2K-6K WOB. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125,RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT Ell OP12-01 REPORT FOR KEENER/LONGO DATE Aug 01,2010 DEPTH 1071200000 PRESENT OPERATION DRILLING AHEAD TIME 24:00:00 YESTERDAY 9178.00000 24 HOUR FOOTAGE 1534 CASING INFORMATION 13 3/8"@2421'9 5/8"@ 5510' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10648.66' 90.11 312.76 3642.99' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 1/2" HUGHES IADC MM323 7017337 1x12 6013 5527 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 378.9 @ 9228.00000 10.6 @ 9273.00000 165.2 131.94547 FT/HR SURFACE TORQUE 14136 @ 9878.00000 8357 @ 9178.00000 10150.4 1066825098 AMPS WEIGHT ON BIT 19 @ 9369.00000 0 @ 9373.00000 3.7 5.83552 KLBS ROTARY RPM 152 @ 9338.00000 125 @ 9268.00000 142.5 142.66083 RPM PUMP PRESSURE 3043 @ 10694.00000 861 @ 10312.00000 2771.2 3005.02710 PSI DRILLING MUD REPORT DEPTH 10475/3670 MW 8.8 VIS 77 PV 24 YP 16 FL 4.8 Gels 19/25/29 CL- 49000 FC /2 SOL 10.5 SD - OIL 78/22 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 489 @ 9212.00000 3 @ 10253.00000 215.5 TRIP GAS 0 CUTTING GAS 0 @ 10712.00000 0 @ 10712.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 98947 @ 9194.00000 648 @ 10253.00000 39552.0 CONNECTION GAS HIGH 0 ETHANE(C-2) 501 @ 9656.00000 3 @ 10253.00000 225.7 AVG 215 PROPANE(C-3) 442 @ 9656.00000 1 @ 10253.00000 108.1 CURRENT 209 BUTANE(C-4) 854 @ 9656.00000 2 @ 10253.00000 180.4 CURRENT BACKGROUND/AVG 200 PENTANE(C-5) 823 @ 9773.00000 1 @ 10253.00000 123.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND=MEDIUM DARK GRAY TO MEDIUM GRAY;UPPER VERY FINE TO LOWER FINE WITH SOME UPPER FINE GRAINS;SPHERICAL TO SUB-DISCOIDAL;ROUNDED TO SUB- ROUNDED;VERY WELL SORTED;UNCONSOLIDATED SAND;GRAIN SUPPORTED;TEXTURALLY SUB-MATURE;COMPOSITIONALLY MATURE TO SUB-MATURE;TRANSLUCENT LITHOLOGY QUARTZ WITH PALE YELLOW ORANGE SHELL FRAGMENTS,GLAUCONITE AND BLACK CHERT;10620'SAMPLE HIGHLY CONTAMINATED WITH SAFE CARB MUD ADDITIVE,OTHERS ALSO CONTAMINATED;EVEN LIGHT GREEN SAMPLE FLUORESCENCE;MEDIUM TO MEDIUM SLOW STREAMING BLUISH WHITE CUT;LIGHT WHITE GREEN RESIDUAL CUT;FAINT OIL ODOR;NO OIL AT SHAKERS;VERY FAINT OIL STAIN ON SOME GRAINS;POROSITY AND PERMEABILITY VISUALLY GOOD. PRESENT SAND 100% LITHOLOGY DAILY ACTIVITY SUMMARY ROATRY DRILL FROM 9178'TO 10615',2K-12k WOB,CIRUCLATE AND CONDISTION,PUMP WEIGHTED SWEEP;ROTARY DRILL FROM 10615'TO 10712'2K-5K WOB. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125,RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum PI EPOCH DAILY WELLSITE REPORT OP12-01 REPORT FOR KEENER/LONDO DATE Aug 02,20/0 DEPTH 12242.00000 PRESENT OPERATION DRILLING AHEAD TIME 24:00:00 YESTERDAY 10712.00000 24 HOUR FOOTAGE 1530 CASING INFORMATION 13 3/8"@ 2421'9 5/8"@ 5510' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12178.81' 91.63 323.41 3660.80' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 1/2" HUGHES TADS MM323 7017337 1x12 6x13 5527 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 369.8 @ 11888.00000 6.1 @ 11159.00000 139.4 2647604 FT/HR SURFACE TORQUE 14621 @ 12216.00000 10424 @ 10713.00000 12075.9 12375.30371 AMPS WEIGHT ON BIT 15 @ 12193.00000 0 @ 11648.00000 3.3 11.38491 KLBS ROTARY RPM 145 @ 11132.00000 118 @ 12194.00000 137.9 140.51607 RPM PUMP PRESSURE 3239 @ 12145.00000 2248 @ 11843.00000 3007.0 2402.95679 PSI DRILLING MUD REPORT DEPTH 12415/3642 MW 8.8 VIS 70 PV 22 YP 14 FL 5.0 @150 Gels 18/28/31 CL- 49000 FC /2 SOL 10.5 SD - OIL 70 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 296 @ 10728.00000 2 @ 11933.00000 173.9 TRIP GAS 0 CUTTING GAS 0 @ 12242.00000 0 @ 12242.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 55137 @ 10728.00000 393 @ 11933.00000 32078.1 CONNECTION GAS HIGH 0 ETHANE(C-2) 408 @ 12180.00000 2 @ 11933.00000 200.8 AVG 173 PROPANE(C-3) 299 @ 12181.00000 1 @ 11933.00000 108.4 CURRENT 30 BUTANE(C-4) 649 @ 12182.00000 2 @ 11933.00000 182.3 CURRENT BACKGROUND/AVG 200 PENTANE(C-5) 662 @ 11201.00000 2 @ 11933.00000 131.9 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SILTSTONE=DARK GRAY TO GRAYISH BLACK;FRIABLE TO EASILY FRIABLE HARDNESS;POORLY TO MODERATELY INDURATED;TEANCITY BRITTLE TO CRUMBLY;IRREGULAR LITHOLOGY FRACTURE;CUTTINGS HABIT IS SUB-NODULAR,MASSIVE OR ELONGATED;LUSTER IS DULL TO EARTHY;SILTY TO GRITTY TEXTURE;LAMINAE STRUCTURE DEFINED BY BLACK CARBONACEOUS MATERIAL AND EROSIONAL PATTERNS;70%LIGHT GREEN SAMPLE FLUORESCENCE;INSTANTANEOUS BLOOMING BLUISH WHITE CUT;LIGHT WHITE RESIDUAL CUT;SLIGHT OIL ODOR;NO FREE OIL;AMBER STAIN WHEN BREAKING OPEN SILTSTONE. PRESENT LITHOLOGY SILTSTONE 70%,SAND 30% DAILY ACTIVITY ROATARY DRILL FROM 10712'TO 11190'2K-8K WOB,ROATARY DRILL FROM 11190'TO 11620'2K-8 WOB,ROATARY DRILL FROM 11620'TO 11900'2K-15K WOB, SUMMARY ROTARY DRILL FROM 11190'TO12242'4K-16K WOB. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum LI EPOCH DAILY WELLSITE REPORT OP12-01 REPORT FOR KEENER/BOWE DATE Aug 03,2010 DEPTH 12860.00000 PRESENT OPERATION BACK REAMING OUT OF THE HOLE TIME 24:00:00 YESTERDAY 12242.00000 24 HOUR FOOTAGE 618 CASING INFORMATION 13 3/8"@ 2421'9 5/8"@ 5510' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12795.76 94.94 317.88 3621.57 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 81/2" HUGHES TADS MM323 7917337 1x12 6x13 5527 12860 7333 66.0 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 239.6 @ 12840.00000 6.7 @ 12565.00000 141.9 99.94447 FT/HR SURFACE TORQUE 16280 @ 12549.00000 11166 @ 12484.00000 13917.7 14057.45410 AMPS WEIGHT ON BIT 17 @ 12338.00000 0 @ 12435.00000 5.6 10.54514 KLBS ROTARY RPM 145 @ 12650.00000 121 @ 12494.00000 139.9 144.57051 RPM PUMP PRESSURE 3326 @ 12253.00000 1107 @ 12447.00000 3069.6 3178.78955 PSI DRILLING MUD REPORT DEPTH 12860/3649 MW 8.9 VIS 79 PV 27 YP 18 FL 5.0 Gels 19/30/34 CL- 49000 FC /2 SOL 11 SD - OIL 71 MBL - pH - Ca-, - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 280 @ 12452.00000 4 @ 12568.00000 130.6 TRIP GAS 22 CUTTING GAS 0 @ 12860.00000 0 @ 12860.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 51701 @ 12452.00000 -1 @ 12677.00000 19636.5 CONNECTION GAS HIGH 0 ETHANE(C-2) 368 @ 12361.00000 -1 @ 12677.00000 122.3 AVG 130 PROPANE(C-3) 364 @ 12361.00000 -1 @ 12677.00000 68.8 CURRENT 3 BUTANE(C-4) 902 @ 12361.00000 -2 @ 12677.00000 123.9 CURRENT BACKGROUND/AVG 2 PENTANE(0-5) 879 @ 12361.00000 -2 @ 12677.00000 93.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION Siltstone(12760'-12860')=medium to medium dark gray with olive gray secondary hues;firm to slightly hard,occasionally fragile;irregular to sub-tabular shaped cuttings;silty to slightly gritty LITHOLOGY texture;dull,earthy luster;commonly grades to silty sandstone/sandy siltstone;20%-60%dull yellow fluorescence above background;instant flash,milky yellowish white cut fluorescence;weak, pale straw visible cut and spotty residual ring;bright yellowish white residual ring fluorescence;no stain;no free oil. PRESENT SILTSTONE 50%,SANDSTONE 30%,SAND 10%,SHELL FRAGMENTS 10% LITHOLOGY DAILY ACTIVITY ROTARY DRILL FROM 11241'TO 12860'TD,2K-15K WOB,CURCULATE AND CONDICTION DRILLING FLUID,CIRUCLATE BOTTUMS UP,PUMP SWEEP,BACK REAM FROM SUMMARY 12860'TO 8600'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum El EPOCH DAILY WELLSITE REPORT OP12-01 REPORT FOR KEENER/BOWE DATE Aug 04,2010 DEPTH 12860.00000 PRESENT OPERATION DISPLACING OBM WITH SEAWATER TIME 24;00;00 YESTERDAY 12860.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2421'9 5/8"@ 5510' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1275.76 94.94 317.88 3621.57 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8 1/2" HUGHES TADS MM323 7917337 1012 6013 5527 12860 7333 66.0 TD 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 12860/3616 MW 9.0 VIS 28 PV YP FL Gels CL- 76000 FC SOL SO OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION Siltstone(12760'-12860')=medium to medium dark gray with olive gray secondary hues;firm to slightly hard,occasionally fragile;irregular to sub-tabular shaped cuttings;silty to slightly gritty LITHOLOGY texture;dull,earthy luster;commonly grades to silty sandstone/sandy siltstone;20%-60%dull yellow fluorescence above background;instant flash,milky yellowish white cut fluorescence;weak, pale straw visible cut and spotty residual ring;bright yellowish white residual ring fluorescence;no stain;no free oil. PRESENT LITHOLOGY SILTSTONE 50%,SANDSTONE 30%,SAND 10%,SHELL FRAGMENTS 10% DAILY ACTIVITY CIRCULATE AND CONDITION MUD,CIRCULATE BOTTOMS UP TWICE @ 8475';BACK REAM WHILE WASHING FROM 8475'TO 5670';CIRUCLATE AND CONDITION MUD;BOTTOMS SUMMARY UP THRICE,PUMP WEIGHTED SWEEP;SERVICE TOP DRIVE/CUT SLIP DRILL LINE/SERVICE BLOCKS;TRIP IN HOLE FROM 5488'TO 12785';REAMNVASH DOWN FROM 12785'TO 12860';CIRUCLATE AND CONDITION HOLE;DISPLACE TO WATER BASE. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT OP12-01 REPORT FOR KEENER/BOWE DATE Aug 05,2010 DEPTH 12860.00000 PRESENT OPERATION TESTING BOP'S TIME 24:00:00 YESTERDAY 12860.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2421'9 5/8"@ 2421' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1275.76 94.94 317.88 3621.57 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HUGES TADS MM3223 7917337 1x12 6x14 5527 12860 7333 66.0 3-3-BT-A-X-IN-WO-TD TD 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 12860/3616 BRINE MW 9.0 VIS 28 PV VP FL Gels CL- 710000 FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY FINISH DISPLACEMENT OF NAF DRILLING FLUID WITH BRINE;TRIP OUT OF HOLE,TO 5460';CICRULATE AND CONDITION MUD;TRIP OUT OF HOLE;LAY DOWN BHA; SUMMARY REMOVE/INSTALL WEAR BUSHING;RIG UP BOP TEST PLUG;TEST BOPS. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045; RIGWATCH$1450 REPORT BY TOLLEF WINSLOW .c-.1_.1/L1.5 Tl l'1IT TA/1T1\TTC, A A.TT' C'T79,TTT T/,Ct\T7TI/l/,T T A Tl11/1TAT A/TA7 T sI 5f'T TA/TT'ATTC'\A/TA7 IT/T.'T 0/L 1/1/17/I Daily Report Page 1 of 1 ENI Petroleum DAILY WELLSITE REPORT El EPOCH OP12-01 REPORT FOR BEAUCHAMP/BOWE DATE Aug 06,2010 DEPTH 12860.00000 PRESENT OPERATION RUNNING CASING TIME 24:00:00 YESTERDAY 12860.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2421'9 5/8"@ 2421' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1280 94.94 317388 3616.094 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB/C PULLED 3 8 1/2" HUGHES TADS MM3223 7917337 1x12 6x13 5527 12860 7333 66.0 33-BT-A-X-IN-WO-TD TD 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 12860/3616 MW 8.9 VIS 28 PV YP FL Gels CL- 63000 FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY TEST BOPS;REMOVE/INSTALL WEAR BUSHING;PULL TEST PLUG;LAY DOWN TEST TOOLS/LAY DOWN DRILL PIPE;PICK UP 27 JOINTS HEAVY WEIGHT DRILL PIPE;PICK SUMMARY UP/RIG UP LINER RUNNING EQUIPMENT;RUN 5 1/2"SLOTTED LINER. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW 4 1A•//rte•\nnnnmantc and Qattinrrc\Rnnnh Arlmin\Aihi TlnnnmPntc\A7Tv WP11c\RIUT\')(11 M2(12 htrn 2/71')(11(1 C;ANRIG SHOW REPORT NO. 1 I)ftll.I INC TEl II INC C R C I,iv. ENI Petroleum OP12-01 Nikaitchuq,Oliktok Point,Alaska DEPTH INTERVAL: 4655 TO 4920 (MD) TOTAL FTG: 265 3441 TO 3531 {TVD) BIT INFORMATION: BIT TYPE- HYCNB#2 HYC MSX619s PDC BIT HOURS- AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 152.9 164.4 367.2 167.8 WOB 12.6 11.5 24 11.2 RPM 121.4 120.1 125 122.1 MUD WT 9.2 9.2 9.2 9.2 CHLORIDE 1100 1100 1100 1100 TOTAL GAS 41 163.6 386 96 C1 (ppm) 8034 29967 68502 17636 C2(ppm) 53 317 705 204 C3(ppm) 10 85 201 69 C4(ppm) 27 90 308 71 C5(ppm) 6 39 150 39 RATIO ROP INCREASE TO GAS INCREASE: 208/345 SAMPLE CUTTINGS FLUORESENCE%: 70 TO 100% COLOR yellow INTENSITY: medium CUT: yellow-white MUD FLUORESCENCE: FORMATION DESCRIPTION: Sand/sandstone; light brownish gray;dis-aggregated loose sand with occasional hard sandstone flakes;friable;appears primarily grain supported;some silty matrix support moderately well sorted; medium lower to fine upper and lower grain;trace medium upper and very fine; angular to sub-angular and sub-spheroidal; predominantly translucent white to clear quartz; common light to medium and dark gray lithics;trace black mafic mineral and lithics;trace dark bluish gray and greenish gray lithics;when present,matrix is light to very light gray silt/clay;trace white ash flakes; common oil stain on sand grains;trace oil blebs in matrix supported material;fair oil sheen on wash water;70-100%medium yellow fluorescence; moderate streaming cut to yellow-white;slight straw residue ring with an immediate cut to yellow-white; no oil odor;slightly calcareous. SHOW RATING: (T,P,F,G) F LOGGING GEOLOGIST(S): John Lundy CANRIG SHOW REPORT NO. 2 1)NILIIXC TFCH\UI 1ic1 I:II, ENI Petroleum OP12-01 Nikaitchuq,Oliktok Point,Alaska DEPTH INTERVAL: 5390 TO 5515 (MD) TOTAL FTG: 125 3605 TO 3618 (TVD) BIT INFORMATION: BIT TYPE- BIT#2 HYC MSX619s PDC BIT HOURS- AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 113.1 145.8 254.8 18 WOB 8.8 7.7 17 15 RPM 102.5 99.7 105 110.3 MUD WT 9.15 9.15 9.15 9.3 CHLORIDE 1000 1250 1250 1250 TOTAL GAS 53.2 546.5 1263 45.2 C1 (ppm) 9595 83480 183345 4333 C2(ppm) 93 1242 2769 74 C3(ppm) 74 1213 2614 126 C4(ppm) 97 1655 3376 261 C5(ppm) 46 856 1697 169 RATIO ROP INCREASE TO GAS INCREASE: 133/1210 SAMPLE CUTTINGS FLUORESENCE%: 100% COLOR STRAW-GREENISH GOLD INTENSITY: BRIGHT CUT: BLOOMING BRT BL-WHT MUD FLUORESCENCE: FORMATION DESCRIPTION: Sand; olive gray to olive black; lower very fine to upper fine grain; spherical to sub-discoidal; rounded to sub-rounded;well to very well sorted; unconsolidated sand;grain supported;texturally mature;compositionally sub-mature;translucent and milky white quartz predominate with chert,glauconite and pyrite;sand fluoresces 100%straw,greenish gold;sample cuts instantaneously blooming, bright white;sand grains stained amber; oil odor present;free oil visible at end of shakers; porosity and permeability visually very good. 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