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Home My WebLink About210-080New Plugback Esets 6/26/2024 Well Name API Number PTD Number ESet Number Date 2L-320 PB1 50-103-20627-70-00 210-166 T39025 3-8-2011 2L-320 PB2 50-103-20627-71-00 210-166 T39026 3-8-2011 CD4-23 PB1 50-103-20621-70-00 210-067 T39027 8-30-2010 CD4-23 PB2 50-103-20621-71-00 210-067 T39028 8-30-2010 ODSK-13 PB1 50-703-20607-70-00 209-146 T39029 11-18-2011 ODSK-13 PB2 50-703-20607-71-00 209-146 T39030 11-18-2011 ODSK-14 PB1 50-703-20610-70-00 209-155 T39031 3-24-2010 ODSK-14 PB2 50-703-20610-71-00 209-155 T39032 3-24-2010 OP05-06 PB1 50-029-23427-70-00 210-080 T39033 10-28-2010 OP05-06 PB2 50-029-23427-71-00 210-080 T39034 10-28-2010 P2-22A PB1 50-029-22850-71-00 209-161 T39035 6-4-2010 P2-22A PB2 50-029-22850-72-00 209-161 T39036 6-4-2010 S-129 PB1 50-029-23433-70-00 210-132 T39037 5-12-2011 S-129 PB2 50-029-23433-71-00 210-132 T39038 5-12-2011 W-219 PB1 50-029-23429-70-00 210-105 T39039 1-27-2011 W-219 PB2 50-029-23429-71-00 210-105 T39040 1-27-2011 W-220 PB1 50-029-23432-70-00 210-126 T39041 3-27-2013 W-220 PB2 50-029-23432-71-00 210-126 T39042 3-27-2013 OP05-06 PB1 50-029-23427-70-00 210-080 T39033 10-28-2010 OP05-06 PB2 50-029-23427-71-00 210-080 T39034 10-28-2010 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP change out Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic and printed data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 17,035 feet N/A feet true vertical 3,994 feet N/A feet Effective Depth measured 16,920 feet N/A feet true vertical 4,001 feet N/A feet Perforation depth Measured depth 8684-17035 feet True Vertical depth 3831-3994 feet Tubing (size, grade, measured and true vertical depth)4.5 L-80 8,111 3732' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Stefano Pierfelici Contact Name: 3/7/2022 Contact Email: Authorized Title:Contact Phone: 321-637 Sr Pet Eng: slotted Sr Pet Geo:Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 45 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 272 214 slotted Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379Well Operations Project Manager measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 802 195131 256 268 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 579 Gas-Mcf MD 160 2,415 N/A 201 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-080 50-029-23427-00-00 N/A 5. Permit to Drill Number:4. Well Class Before Work: 355024, 373301, 390615, 355023 Schrader Bluff Oil Pool 2. Operator Name: Eni US Operating Co. Inc. 3700 Centerpoint Dr. Ste 500, Anchorage, AK, 99503 3. Address: OP05-06 measuredPlugs Junk measured N/A Length 154 2,382 Size Conductor Surface Intermediate 20" 13.375" 9.625" Production Liner 8,651 8,426 Casing Structural TVD 160 2,189 3,831 5.5" 8,684 16,920 4,001 4,790 0 5,210 6,890 Burst Collapse 0 2,480 t a O A PG , R Fra O 6. A R tt Form 10-404 Revised 10/2021 Submit Within 30 days of Operations Nikaitchuq/ By Meredith Guhl at 10:39 am, Mar 07, 2022 Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2022.03.07 10:25:03 -08'00' Stefano Pierfelic i RBDMS SJC 031122 4-½” 12.6 ppf TK15-XT (Internal Coated) L80 W563 Production Tubing5-½” Oil Swell Packer4-½” X-Coupling Clamps for ESP Power Cable, (1) 3/8" Chem Inj LineOP05-06Dual Lateral Producer With ESP LiftNikaitchuq Field –Oliktok PointTD 17,035' MD, 3,994' TVD, 94º Inc.As CompletedFebruary 21-2022Tracer September 2010 Resman Oil/WaterTracer Sub 9-5/8", 47# Intermediate Casing 8,684' MD, 3,831' TVD, 90º Inc.5-½” Ecc. Nose Guide Shoe, 16,920' MD, 4,001' TVD, 92º Inc.8,494' MD, 3,816' TVD,9-5/8" SLXP Liner Hanger System 8,182' MD, 3,751' TVD, 77° Inc., Bottom of Motor Centralizer Centrilift ESP, 66 Stages Flex 47 + 20 Stages GINPSHH, GASSEP 538, 2 x GSB3DB Seals, 250 HP XP Motor 8,206' MD, 3,759' TVD – L1,9-5/8" SLXP Liner Hanger System5-½” Ecc. Nose Guide Shoe with Bent Joint, 17,015 MD, 4,053' TVD, 89º Inc.8,387-8,404' MD, Casing Exit WindowTD 17,035' MD, 4,053' TVD, 89º Inc.8,186'' MD, 3,751' TVD - Bottom of Motor 7-5/8" Shroud5-½” 15.5 ppf Slotted Liner5-½” 17 ppf Slotted Liner 13-5/8", 68# Surface Casing 2,415' MD, 2,189' TVD, 50º Inc.8,111' MD, 3,732' TVD- DGU Well Name: OP05-06 OR Wellbore Name: OP05-06 Well Code: 23985 Job: WORKOVER WCEI: N/A Daily Report Date: 2/11/2022 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.26 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast WC -49° Temperature (°F) -25.1 Wind SW @ 13 MPH Days LTI (days) Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Complete location prep work for moving rig. Move rig over OP05-06. Spot over well. Load pits with 8.8 ppg brine. Rig up to perform well kill. 24h Summary Complete passport testing on OP10-09. Crane removed ESP cable spools and 3/8" capillary spools and install spools for pulling ESP cable and capillary line. Logistics scrape and level pad. Lay rig mats and herculite for rig move. Operation at 07.00 Moving Rig Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 16:00 00:00 8.00 8.00 W.O. A 1 P Complete passport testing on OP10-09. Good tests. Remove ESP spool and spooler with good cable and capillary line spool from rig and install empty spools for pulling completion. Lay out herculite and rig mats for rig move. 24 Hour Notice for Testing BOPE given to AOGCC on Feb 11 2022 @ 7:27 pm Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Matt Martyn ASRC Company Man OPPDrilling@eni.com 907-685-0710 Eni representative Mike Aivano ASRC Company Man 685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tim Childs ASRC Energy Services HSE Tool Push Nate Sipes Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Safety Representative Matt Meinhold Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 8,482.9 16,920.0 4,001.2 9/9/2010 Well Name: OP05-06 OR Wellbore Name: OP05-06 Well Code: 23985 Job: WORKOVER WCEI: N/A Daily Report Date: 2/12/2022 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.26 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Broken Skies WC-63° Temperature (°F) -39.0 Wind SW @ 8 MPH Days LTI (days) Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Kill well with 8.8 ppg brine by bull heading down tubing and A-annulus. Flow check. Set back pressure valve in hanger. Nipple down tree. Nipple up riser and BOPE. 24h Summary Finish preparing the pad for rig move with herculite and rig mats. Move rig over to OP05-06. Level and shim the rig. Berm the rig. Take on 8.8 ppg brine to rig pits. Bleed gas from A-Annulus and Tbg. Operation at 07.00 Killing well with 8.8 ppg brine. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. A 2 P Crew Change and PJSM. Continue to lay transition mats and build transition area between mats. Move Hi-Line module. Warm up moving system. Remove berm from around rig and Hi-Line protectors from driller's side of the rig. 01:30 04:00 2.50 4.00 W.O. A 2 P Jack up rig and install 2 mats under rear of rig. Move away from well bay. Transition off double mats. 04:00 06:00 2.00 6.00 W.O. A 2 P Moved rig sideways. Position rig and then pull over the well. 06:00 07:00 1.00 7.00 W.O. A 2 P Remove well bay hatch cover, Lower BOP enclosure and secure. 07:00 12:00 5.00 12.00 W.O. A 2 P Berm up herculite around the rig. Pull rig mats from OP10. Spot equipment and get ENI electrician to un spool more Hi-Line cable. Install Hi-Line cable in to cable protection trays. Spot trays under stairs. 12:00 19:00 7.00 19.00 W.O. A 2 P Crew Change out. PJSM. Finish berm for rig and cuttings box. Spot bleed trailer and heaters. Route heat socks to rig floor. Hook up circulating lines to kill well. 19:00 00:00 5.00 24.00 W.O. A 5 P PJSM. Rig up to A-annulus and bleed to bleed trailer. Initial pressure = 332 psi. Bleed down to 14 psi. Tubing pressure = 266 psi bleed down to 21 psi. Start loading pipe shed with 4" DP. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Matt Martyn ASRC Company Man OPPDrilling@eni.com 907-685-0710 Eni representative Mike Aivano ASRC Company Man 685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tim Childs ASRC Energy Services HSE Tool Push Nate Sipes Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Safety Representative Matt Meinhold Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 8,482.9 16,920.0 4,001.2 9/9/2010 Well Name: OP05-06 OR Wellbore Name: OP05-06 Well Code: 23985 Job: WORKOVER WCEI: N/A Daily Report Date: 2/13/2022 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.26 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast WC -60° Temperature (°F) -35.0 Wind SW @ 13 MPH Days LTI (days) Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Test BOPE 250 psi / 3500 psi. Pull blanking sleeve and BPV. Pull and lay down tubing hanger and 4-1/2" tubing completion. 24h Summary Complete bleeding gas head pressure off tubing and A-annulus. Bullhead kill tubing and A-annulus with 8.8 ppg brine, monitor well for flow for 1 hour. Set BPV in tubing hanger. Nipple down tree and nipple up riser and BOPE. Function BOP's and rig up test equipment. Operation at 07.00 Testing BOPE Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:30 3.50 3.50 W.O. A 5 P Continue to monitor and bleed gas from tubing and A-annulus down to near zero psi. 03:30 04:00 0.50 4.00 W.O. M 1 P PJSM with vac-truck drivers and rig crew on well kill. Pressure test kill lines to tubing and A-Annulus to 3500 psi. 04:00 06:30 2.50 6.50 W.O. M 9 P Pump down tubing with an initial pump rate of 3.5 bpm and 2950 psi. Stage pump up to 5.0 bpm Bull head 169 bbls.. Final rate and pressure 5 bpm at 2800 psi. Shut down pump and blow down line to tubing. Tubing at -14 psi at shut down. Rig up to pump down A-Annulus. Initial rate 5 bpm at 170 psi. Stage pump up to 9.5 bpm at 450 psi. Bullhead a total of 681 bbls down A-Annulus. A-Annulus at -13 psi. at shut down. 06:30 08:00 1.50 8.00 W.O. M 9 P Blow down lines. Monitor well for 1 hour and release vacuum from tubing and A-annulus. Tubing at -2 psi and A-Annulus at - 1.4 psi. 08:00 10:00 2.00 10.00 W.O. C 5 P PJSM. Set BPV with Vault rep. Power issues across all of OPP, halt work on nipple down and leave the well secured till power issues resolved. 10:00 12:00 2.00 12.00 W.O. C 5 P Resume nipple down of tree, stow in BOP enclosure. Terminate capillary line and install test dart. 12:00 18:00 6.00 18.00 W.O. C 5 P Crew change out and PJSM. Assist Vault hand in prepping Graylock flange. Set riser and make up Graylock flange as per Vault instructions. Set single gate ram, double gate rams, annular and make up all bolts. 18:00 21:00 3.00 21.00 W.O. C 5 P Make up choke and kill lines. Record RKB's. Function test BOPE. Install flow riser. 21:00 23:00 2.00 23.00 W.O. C 5 P Make up 4-1/2" test joint. 23:00 00:00 1.00 24.00 W.O. C 5 P Fluid pack lines. Thaw choke line from BOP enclosure. Complete loading and strapping drill pipe. Daily losses = 1633 bbls 8.8 ppg brine Cumulative losses = 1633 bbls 8.6 ppg brine. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Matt Martyn ASRC Company Man OPPDrilling@eni.com 907-685-0710 Eni representative Mike Aivano ASRC Company Man 685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tim Childs ASRC Energy Services HSE Tool Push Nate Sipes Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Safety Representative Matt Meinhold Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 8,482.9 16,920.0 4,001.2 9/9/2010 Well Name: OP05-06 OR Wellbore Name: OP05-06 Well Code: 23985 Job: WORKOVER WCEI: N/A Daily Report Date: 2/14/2022 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.26 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast WC -65° Temperature (°F) -35.0 Wind SW @ 17 MPH Days LTI (days) Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Pull out of hole and lay down 4-1/2" tubing and ESP completion. Make up clean out BHA and run in hole with 4" XT39 drill pipe singles from pipe shed. 24h Summary Test BOPE to 250 psi low and 3500 psi high. Pull BPV. Pull tubing hanger free from well head. Lay down tubing hanger and swivel joint. Pull out of the hole and lay down 4-1/2" tubing. Operation at 07.00 Pulling out of the hole and laying down 4-1/2" tubing. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. C 5 P Crew change and PJSM. Continue to thaw choke line. Flood and liquid pack choke manifold. 01:00 03:00 2.00 3.00 W.O. C 12 P Attempt to shell test. Re-tighten Gray-lock clamps on choke line. 03:00 04:00 1.00 4.00 W.O. C 12 P Begin testing BOPE, 250 psi low and 3500 psi high. Test witness waived by Guy Cook at AOGCC, Feb 11, 2022 at 7:38 pm by email. 04:00 05:30 1.50 5.50 W.O. C 12 P Rig down long 4-1/2" test joint. R/U 4" XT-39 test joint. 05:30 07:00 1.50 7.00 W.O. C 25 U Trouble shoot draw works purge system. Unable to move draw works up. 07:00 10:00 3.00 10.00 W.O. C 12 P Continue test BOPE 250 psi low / 3500 psi high. 10:00 11:00 1.00 11.00 W.O. C 25 TR05 Found drip from blind ram door seal. Drain stack and change out door seal. Flood stack and BOPE equipment with water. 11:00 12:00 1.00 12.00 W.O. C 12 P Continue testing BOPE 250 psi low / 3500 psi high. 12:00 13:00 1.00 13.00 W.O. C 12 P Crew change. PJSM. Continue with test BOPE 250 psi low / 3500 psi high. 13:00 15:30 2.50 15.50 W.O. C 12 P PJSM. Blow down all surface lines. Re-fluid pack BOPE. Test lower pipe rams to 250 psi low / 3500 psi high with 4" test joint Good test. Blow down surface equipment. 15:30 16:30 1.00 16.50 W.O. C 5 P Break down 4" test joint. 16:30 18:30 2.00 18.50 W.O. C 1 P Prepare to Pull BPV. Check A-annulus pressure and confirm no flow. Engage TWC and monitor well. Fluid in BOP stack falling. Pull BPV from hanger and fluid in BOP stack fell out and down hole. Break out lock down screws on tubing hanger. Pick up and engage tubing hanger with landing joint. 18:30 21:00 2.50 21.00 W.O. L 4 P Pull tubing hanger to the rig floor. Tubing hanger pulled free at 195k lbs. Continue to pull to the floor with a pick up weight of 105k lbs. Terminate capillary line and ESP cable. PJSM on pulling and laying down 4-1/2" tubing and begin pulling out of hole with tubing. Perform kick while tripping drill. 21:00 23:00 2.00 23.00 W.O. L 4 P Pull out of hole and lay down 4-1/2" tubing. from 7992' - 6877'. Fill annulus with double displacement plus 10 bbls per hour. Lay down first 30 joints from pipe shed. 23:00 00:00 1.00 24.00 W.O. L 4 P Pull out of the hole and lay down 4-1/2" tubing from 6877' - 5718'. Fill annulus with double displacement plus 10 bbls per hour. Joint #58 of 196 out of the hole at midnight. Daily losses = 273 bbls of 8.8 ppg brine Total Losses = 1936 bbls of 8.8 ppg brine Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Matt Martyn ASRC Company Man OPPDrilling@eni.com 907-685-0710 Eni representative Mike Aivano ASRC Company Man 685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tim Childs ASRC Energy Services HSE Tool Push Nate Sipes Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Safety Representative Matt Meinhold Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 8,482.9 16,920.0 4,001.2 9/9/2010 Well Name: OP05-06 OR Wellbore Name: OP05-06 Well Code: 23985 Job: WORKOVER WCEI: N/A Daily Report Date: 2/15/2022 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.26 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Skies WC -59° Temperature (°F) -36.4 Wind SW @ 10 MPH Days LTI (days) Days RI (days) POB 39.0 Daily Summary Operations 24h Forecast Complete cut and slip drilling line. Continue running in the hole with scraper on 4" DP from pipe shed. Pull out of the hole and rack back drill pipe. Make up Baker retrievable test packer. RIH and test 9-5/8" casing to 1600 psi. 24h Summary Pull out of the hole and lay down 4-1/2" tubing from 5018' to surface. Break out and lay down ESP assembly. Load and tally BHA for scraper run. RIH scraper BHA on 4" XT-39 drill pipe from pipe shed. Slip and cut drilling line. Operation at 07.00 RIH with clean out BHA. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 10:30 10.50 10.50 W.O. L 4 P Pull out of the hole and lay down 4-1/2" tubing from 5818' to 102'. Unloading pipe shed every 30 joints. Filling annulus with 10 bbls per hour plus double pipe displacement. 10:30 12:00 1.50 12.00 W.O. L 5 P Cut ESP cable and cut capillary line. Lay down ESP assembly. Collect samples from pump. Pump still free spinning, seals and motor free spinning. 12:00 13:30 1.50 13.50 W.O. L 5 P Crew change. PJSM. Complete laying down ESP assembly. Recovered 196 cross coupling clamps, 2 splice clamps, 4 equipment clamps, 3 bow springs, 1 pump clamp, 1 half clamp, 1 stainless steel band. 13:30 16:00 2.50 16.00 W.O. L 5 P Assisted Baker prepping spooling units to be craned out. Prep pipe shed for BHA. Load BHA components, strap and tally BHA. Set wear ring and RILDS with Vault. 16:00 18:30 2.50 18.50 W.O. L 5 P PJSM. Make up BHA#1 with mule shoe, scraper, magnets, jars, bumper sub,and XO. Total length = 81.13'. 18:30 21:00 2.50 21.00 W.O. L 4 P Run in hole with BHA #1 on 4" XT-39 drill pipe from pipe shed to 1396'. 21:00 23:00 2.00 23.00 W.O. L 25 P PJSM on slipping and cutting drill line. Hang the blocks. Slip and cut drill line. 23:00 00:00 1.00 24.00 W.O. L 25 TR01 Diagnose draw works, zone management issues. Daily losses = 342 bbls of 8.8 ppg brine Cumulative losses = 2278 bbls of 8.8 ppg brine. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Eni representative Mike Aivano ASRC Company Man 685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tim Childs ASRC Energy Services HSE Tool Push Nate Sipes Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Safety Representative Matt Meinhold Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 8,482.9 16,920.0 4,001.2 9/9/2010 Well Name: OP05-06 OR Wellbore Name: OP05-06 Well Code: 23985 Job: WORKOVER WCEI: N/A Daily Report Date: 2/16/2022 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.26 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast WC -53° Temperature (°F) -24.3 Wind WC @ 18 MPH Days LTI (days) Days RI (days) POB 38.0 Daily Summary Operations 24h Forecast Pull out of hole with BHA #1 and rack back drill pipe. Lay down BHA#1 and pick up BHA#2 (retrievable test packer) and run in the hole. Test casing to 1600 psi as per procedure. 24h Summary Complete slip and cut of drilling line. Continue running in the hole with BHA #1 on 4" XT-39 drill pipe from the pipe shed to 8191'. Attempt to circulate bottoms up, no returns to surface. Pumped 140 bbls of 8.8 ppg brine. Operation at 07.00 Pulling out of hole with BHA #1 Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 00:30 0.50 0.50 W.O. M 25 TR01 Crew change, PJSM. Continue with trouble shooting draw works zone management system. 00:30 03:00 2.50 3.00 W.O. M 25 P PJSM. Complete slip and cut of drilling line. Calibrate zone management system. Calibrate Pason system. 03:00 04:30 1.50 4.50 W.O. M 21 TR99 PJSM with crew on running in hole with drill pipe. Pick up 4" drill pipe from the shed and run in the with BHA #1 from 1,396'. Iron Roughneck failure. Issue with ram unseating from seating block. Unable to repair. PJSM and risk discussion with crew on using rig tongs to make up drill pipe. 04:30 09:30 5.00 9.50 W.O. M 4 P Run in the hole with 4" XT-39 drill pipe from the shed from 1,396' to 3,931'. 09:30 12:00 2.50 12.00 W.O. M 5 P Lift meeting discussion for taking out ESP cable and capillary line spooler from rig floor. Lift out ESP spool, spooler and capillary line spool from rig floor with crane. 12:00 19:30 7.50 19.50 W.O. M 4 P Crew Change. PJSM on running drill pipe. Run in the hole with 4" drill pipe from 3.931' to 7,773' 19:30 20:30 1.00 20.50 W.O. M 4 TR03 Brown out issue with rig electrical power system. Unable to establish Ethernet communication to hydrualic power unit. Trouble shoot, discuss with PECO support over phone to resolve issues. 20:30 22:00 1.50 22.00 W.O. M 4 P Continue to run in the hole with 4" XT-39 drill pipe from 7,773' to 8191'. Pick up weight = 109k lbs, Slack off weight = 78k lbs. 22:00 00:00 2.00 24.00 W.O. M 7 P PJSM with rig crew and Worley vac-trucks. Pump down drill pipe at 8 bpm and 930 psi in attempt to circulate bottoms up. No returns to surface. Pumped a total of 140 bbls. Blow down surface lines. Daily losses = 418 bbls of 8.8 ppg brine. Cumulative losses = 2666 bbls of 8.8 ppg brine. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Eni representative Mike Aivano ASRC Company Man 685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tim Childs ASRC Energy Services HSE Tool Push Nate Sipes Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Safety Representative Matt Meinhold Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 8,482.9 16,920.0 4,001.2 9/9/2010 Well Name: OP05-06 OR Wellbore Name: OP05-06 Well Code: 23985 Job: WORKOVER WCEI: N/A Daily Report Date: 2/17/2022 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.26 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast WC -48° Temperature (°F) -21.8 Wind WSW @ 22 MPH Days LTI (days) Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Pull out of the hole with BHA #1 and rack back drill pipe in the derrick. Lay down scraper and magnets. Pick up retrievable test packer BHA and run in the hole to pressure test 9-5/8" casing. 24h Summary Pull out of the hole with BHA#1, racking back drill pipe in the derrick. Clean off magnet and scraper, Run back in the hole with BHA#1. Operation at 07.00 Pulling out of hole with BHA #1 Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. M 25 P Crew change out. PJSM. Finish blowing down top drive and circulating system. Position Top drive to change out grabber box dies. 01:00 02:00 1.00 2.00 W.O. M 25 P Change out grabber box dies on top drive. Grease Iron Roughneck and grease draw works. 02:00 03:00 1.00 3.00 W.O. M 25 TS03 Repair articulating ram on Iron Roughneck that failed previous day. 03:00 08:30 5.50 8.50 W.O. M 4 P PJSM. Pull out of the hole standing back 4" XT 39 drill pipe. from 8,189' to 5,386'. 08:30 11:00 2.50 11.00 W.O. M 25 P Replace dies and carrier on Iron Roughneck. Loaded 38 joints of 4-1/2" 12.6# Hyd 563 TK-15XT Tubing into pipe shed. 11:00 12:00 1.00 12.00 W.O. M 4 P Pull out of the hole with 4" DP and rack back in the derrick from 5,386' - 4,405'. Breaking each connection with rig tongs. 12:00 17:00 5.00 17.00 W.O. M 4 P Crew change. PJSM. Pull out of the hole from 4,405' to surface. 17:00 18:00 1.00 18.00 W.O. M 5 P Inspect BHA#1. Clean magnets. Discuss with Anchorage team. Decision made to re-run scraper and magnets again, same BHA. Recovered approximately 40 lbs of material on the magnets. 18:00 23:30 5.50 23.50 W.O. M 4 P PJSM. Run in the hole with BHA#1 again on 4" drill pipe to 8191' 23:30 00:00 0.50 24.00 W.O. M 9 P Make up top drive and pump 40 bbls 8.6 ppg brine at 4 bpm and 128 psi. Blow down all surface lines. Austin McLeod with AOGCC waived witness to casing pressure test on Feb. 16, 2022 at 6:46 am by email. Daily losses = 309 bbls of 8.8 ppg brine. Cumulative losses = 2935 bbls of 8.8 ppg brine. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Eni representative Mike Aivano ASRC Company Man 685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tim Childs ASRC Energy Services HSE Tool Push Nate Sipes Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Safety Representative Matt Meinhold Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 8,482.9 16,920.0 4,001.2 9/9/2010 Well Name: OP05-06 OR Wellbore Name: OP05-06 Well Code: 23985 Job: WORKOVER WCEI: N/A Daily Report Date: 2/18/2022 Report #: 8 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.26 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast WC -48° Temperature (°F) -24.3 Wind N @ 9 MPH Days LTI (days) Days RI (days) POB 41.0 Daily Summary Operations 24h Forecast Pull out of hole and lay down drill pipe. Lay down BHA# 2. Prep and rig up to run ESP completion on 4-1/2" 12.6# Hyd 563 L-80 TK-15XT internally coated tubing. 24h Summary Pull out of the hole and lay down BHA# 1, casing scraper and magnets. Pick up BHA# 2 with retrievable test packer and run in the hole with drill pipe. Pressure Test Casing MIT 1600 psi - good test. Begin pulling out of hole and laying down drill pipe. Operation at 07.00 Pulling out of hole laying down drill pipe. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. M 25 P PJSM. Grease Iron Roughneck, block and crown, Load and clean 4-1/2" tubing in pipe shed. 01:00 09:00 8.00 9.00 W.O. M 4 P POOH with 4" drill pipe and rack back in derrick from 8191'. Continue to load 4-1/2" completion tubing in the pipe shed. 09:00 11:00 2.00 11.00 W.O. M 5 P PJSM. Clean metal off magnets. Upper magnet small amount of material, lower magnet clean. Lay down Razorback scraper and magnets. 11:00 12:00 1.00 12.00 W.O. M 5 P Clean and clear rig floor. Use Logistics and zoom boom to offload scraper and magnets. 12:00 14:00 2.00 14.00 W.O. M 5 P Crew change. PJSM. Complete off loading of scraper and magnets with zoom boom. Continue to load, strap, clean, and tally 4-1/2" completion tubing. Prepare test packer to be picked up. Finalize BHA. 14:00 15:00 1.00 15.00 W.O. M 5 P PJSM. Pick up BHA#2 ( Baker retrievable test packer) 15:00 20:00 5.00 20.00 W.O. M 4 P Run in hole with test packer. Baker recommends 150 ft / min make speed. Run in hole with BHA#2 with drill pipe from derrick from surface to 7745'. 20:00 21:00 1.00 21.00 W.O. M 9 P PJSM. Set Baker test packer at 7739'. Fill casing x drill pipe annulus with 8.8 ppg brine. required 53 bbls to fill annulus. Fluid level was at approximately 918'. 21:00 23:00 2.00 23.00 W.O. M 12 P Pressure test casing in 200 psi increments and hold for 5 mins each from 200 psi to1600 psi. Pressure test at 1600 psi for 30mins, charted - passed, required 2.5 bbls to pressure. Casing pressure test lost 7 psi in first 15 mins and 3 psi in second 15 mins. 10 psi overall loss over 30 mins. Bleed down 2.5 bbls to trip tank. MIT witness waived by Austin Mcleod of AOGCC on Feb 16, 2022 by email. 23:00 00:00 1.00 24.00 W.O. M 4 P Unseat test packer as per Baker rep. Pull out of hole laying down drill pipe from 7739' to 7349'. Daily losses: 335 bbls 3%KCL/NaCl brine with biocide Cumulative: 3270 bbls 3%KCL/NaCl brine with biocide Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Eni representative Mike Aivano ASRC Company Man 685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tim Childs ASRC Energy Services HSE Tool Push Nate Sipes Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Safety Representative Matt Meinhold Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 8,482.9 16,920.0 4,001.2 9/9/2010 Well Name: OP05-06 OR Wellbore Name: OP05-06 Well Code: 23985 Job: WORKOVER WCEI: N/A Daily Report Date: 2/19/2022 Report #: 9 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.26 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Broken Skies WC-45° Temperature (°F) -18.0 Wind NE @ 14 MPH Days LTI (days) Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Continue to make up ESP equipment. Run in hole with ESP completion on 4-1/2" Hyd563 L-80 12.6# TK-15XT internally coated tubing. 24h Summary Pull out of the hole and lay down drill pipe. Lay down BHA# 2. Pull wear bushing. Load ESP equipment into pipe shed. Load ESP cable spool and capillary spool on rig floor. Pick up and make up shroud and ESP equipment. Operation at 07.00 Testing ESP components before RIH. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 09:30 9.50 9.50 W.O. M 4 P PJSM. Continue to pull out hole and lay down 4" XT-39 DP from 7349' to surface. 09:30 10:30 1.00 10.50 W.O. M 5 P Lay down jars, bumper sub and test packer. 10:30 11:30 1.00 11.50 W.O. M 4 P Run in hole with 4 stands of drill pipe from the derrick. Pull out of hole and lay down 12 joints of drill pipe. 11:30 12:00 0.50 12.00 W.O. C 5 P Pull wear ring with Vault. 12:00 13:30 1.50 13.50 W.O. M 1 P Crew change. PJSM with crane crew for picking up completion spooling units. 13:30 15:00 1.50 15.00 W.O. M 5 P Prepare rig floor and pipe shed for running completion. Unload remaining 4" drill pipe out of pipe shed. 15:00 17:00 2.00 17.00 W.O. M 5 P Load ESP boxes into pipe shed. Unload new ESP components and load old ESP components into boxes for shipping out. 17:00 18:30 1.50 18.50 W.O. M 1 P Crane crew change out. Obtain new permits for making crane lift. 18:30 21:30 3.00 21.50 W.O. M 5 P Use crane to spot capillary line spooler, ESP spooler, and ESP cable spool on to rig floor. Off load old clamps from back deck of the rig and place new ESP cable clamps on back deck. 21:30 00:00 2.50 24.00 W.O. K 5 P PJSM with Baker and GBR. Pick up ESP shroud. Make up top connection and torque to spec. Pick up first section of ESP, install lower centralizer and set inside shroud. Confirm free rotation of ESP motor. Fill oil in motor section and seal sections. Daily losses: 371 bbls 3%KCL/NaCl brine Cumulative: 3641 bbls 3%KCL/NaCl brine Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Eni representative Mike Aivano ASRC Company Man 685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tim Childs ASRC Energy Services HSE Tool Push Nate Sipes Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Safety Representative Mat Salkeld Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 8,482.9 16,920.0 4,001.2 9/9/2010 Well Name: OP05-06 OR Wellbore Name: OP05-06 Well Code: 23985 Job: WORKOVER WCEI: N/A Daily Report Date: 2/20/2022 Report #: 10 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.26 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast WC -59° Temperature (°F) -36.0 Wind NW @ 10 MPH Days LTI (days) Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Run in the hole with ESP completion on 4-1/2", H563, 12.6#, L-80, TK-15XT internally coated tubing to approximately 7500'. Swap ESP cable spool swap and make cable splice. Continue to run in the hole and land tubing hanger. 24h Summary Make up ESP assembly and shroud. Run in hole with ESP completion on 4-1/2", H563, 12.6#, L-80, TK-15XT internally coated tubing. Depth at midnight 4499 ft. Operation at 07.00 Running in hole with ESP completion at 6,250' MD Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 08:00 8.00 8.00 W.O. K 5 P Continue to pick ESP assembly. Fill with oil and check rotation of motor, pump and seals. Connect MLE and motor, make continuity check. Perform MGU and DGU communication test through MLE. Install check valve. Connect 3/8" capillary line. Test check valve and pressure test capillary line. Install digital gauge on capillary line. 08:00 10:00 2.00 10.00 W.O. K 4 P Run in the hole with ESP completion on 4-1/2", H563, 12.6#, L-80, TK-15XT internally coated tubing to 567 ft. 10:00 13:00 3.00 13.00 W.O. K 21 U Hydraulic hose failure on GBR equipment outside of the rig. Install TIW and clean up spill. Need to change out GBR hydraulic power unit and hoses. Standby for GBR hoses and equipment to arrive from Deadhorse. Clean and organize rig. 13:00 13:30 0.50 13.50 W.O. K 5 U New hydraulic hose from GBR on location, assist in running new hose to rig floor. Warm up hydraulics and test equipment. 13:30 19:30 6.00 19.50 W.O. K 4 P Run in the hole with ESP completion on 4-1/2", H563, 12.6#, L-80, TK-15XT internally coated tubing from 567 ft to 2501 ft. Check ESP cable and communication with down hole equipment every 1000 ft. Continually monitor 3/8" capillary line pressure and maintain above 1000 psi. 19:30 20:00 0.50 20.00 W.O. K 25 P Service draw works 20:00 00:00 4.00 24.00 W.O. K 4 P Run in the hole with ESP completion on 4-1/2", H563, 12.6#, L-80, TK-15XT internally coated tubing from 2501 ft to 4499 ft. Check ESP cable and communication with down hole equipment every 1000 ft. Continually monitor 3/8" capillary line pressure and maintain above 1000 psi. Pump tubing volume at 3000 ft. Pump at 1.5 bpm and 60 psi for 45 bbls. Daily losses: 274 bbls 3%KCL/NaCl brine Cumulative: 3905 bbls 3%KCL/NaCl brine Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Eni representative Mike Aivano ASRC Company Man 685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tim Childs ASRC Energy Services HSE Tool Push Nate Sipes Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Safety Representative Mat Salkeld Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 8,482.9 16,920.0 4,001.2 9/9/2010 Well Name: OP05-06 OR Wellbore Name: OP05-06 Well Code: 23985 Job: WORKOVER WCEI: N/A Daily Report Date: 2/21/2022 Report #: 11 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.26 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Skies WC -51° Temperature (°F) -20.9 Wind E @ 24 MPH Days LTI (days) Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Complete nipple up tree and test. Vault to perform Passport testing of well head. Baker to perform final ESP cable/ motor electrical integrity tests. Complete Well and turn over to production. Production to freeze protect. 24h Summary Run ESP completion as per plan and land in tubing spool. Nipple down BOPE and nipple up tree. Operation at 07.00 Passport testing. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:30 4.50 4.50 W.O. K 4 P Make up and run in hole with 4.5” ESP completion from 4499’- 6034’. Test ESP cable every 1000’. 04:30 05:30 1.00 5.50 W.O. K 9 P Make up TIW valve and head pin. Pump 91 bbls of 8.8 ppg brine down tubing. 05:30 09:00 3.50 9.00 W.O. K 4 P Run ESP completion from 6034’ to 7514’, PUW 93k, SOW 68k. 09:00 10:30 1.50 10.50 W.O. K 5 P Conduct Lift Plan Meeting and change out ESP spools. 10:30 12:00 1.50 12.00 W.O. K 5 P Baker performed ESP splice and was witnessed by ENI electrician and Co-man. Tested good. 12:00 14:30 2.50 14.50 W.O. K 4 P Run ESP completion from 7514’ to 8185.81’. 14:30 16:30 2.00 16.50 W.O. K 5 P Pick up Vault tubing hanger with swivel joint and make up. Baker make penetration splice to hanger. 16:30 18:00 1.50 18.00 W.O. C 5 P Land hanger as per Vault. Open Work permit with DSO and run in lock down screws. Test hanger body seals ( upper / lower) to 5000 psi for 10 minutes. Witnessed by Co-man. 18:00 22:30 4.50 22.50 W.O. C 5 P Nipple down BOPE. Remove companion flange from IA and install diesel feed line. 22:30 00:00 1.50 24.00 W.O. C 5 P Dress grayloc flange and install new studs and nuts. Nipple up tree. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Company Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tim Childs ASRC Energy Services HSE Tool Push Nate Sipes Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Safety Representative Mat Salkeld Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 8,482.9 16,920.0 4,001.2 9/9/2010 Well Name: OP05-06 OR Wellbore Name: OP05-06 Well Code: 23985 Job: WORKOVER WCEI: N/A Daily Report Date: 2/22/2022 Report #: 12 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.26 Ground Level (ft) 12.20 First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast WC -4° Temperature (°F) 10.6 Wind S @ 9 MPH Days LTI (days) Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Moving to OP04-06 24h Summary Complete Passport testing and release rig at 12:00. Move from OP05 to OP04. Operation at 07.00 No Further work. Last report. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. C 5 P PJSM, Nipple up tree and tighten GrayLoc clamp. 02:00 09:30 7.50 9.50 W.O. C 12 P Conduct Passport testing on well head as per ENI policy. Prep for rig move. 09:30 10:00 0.50 10.00 W.O. C 20 P Safety Stand Down. Zero tolerance policy for violence and harassment in our workplace. 10:00 10:30 0.50 10.50 W.O. C 5 P Secure testing equipment. Scope BOP enclosure. Lift motor room landing stairs. 10:30 12:00 1.50 12.00 W.O. A 2 P PJSM, Start moving rig from OP05 to OP04, spot and level. Lower and secure BOP enclosure. Berm around rig. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Company Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tim Childs ASRC Energy Services HSE Tool Push Nate Sipes Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Dave Hiler Nordic Toolpusher dave.hiler@nordic-calista.com 907-685-1470 Safety Representative Mat Salkeld Nordic HSE matt.meinhold@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.89 L-80 8,482.9 16,920.0 4,001.2 9/9/2010 5HJJ-DPHV%2*& )URP5HJJ-DPHV%2*& 6HQW)ULGD\)HEUXDU\$0 7R$VKOH\7LPRWK\ &F%URRNV3KRHEH/2*& 6XEMHFW5(0,77HVW&KDUWDQGIRUP ZĞǀŝƐĞĚŽƵƌĐŽƉǇŽĨƚŚĞƚĞƐƚƌĞƉŽƌƚƚŽƐŚŽǁtĞůůKWϬϱͲϬϲ;WdϮϭϬϬϴϬϬͿ͘ :ŝŵZĞŐŐ ^ƵƉĞƌǀŝƐŽƌ͕/ŶƐƉĞĐƚŝŽŶƐ K' ϯϯϯt͘ϳƚŚǀĞ͕^ƵŝƚĞϭϬϬ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ϵϬϳͲϳϵϯͲϭϮϯϲ &ƌŽŵ͗ƐŚůĞǇdŝŵŽƚŚǇфdŝŵŽƚŚǇ͘ƐŚůĞǇΛĞǆƚĞƌŶĂů͘ĞŶŝ͘ĐŽŵх ^ĞŶƚ͗^ƵŶĚĂǇ͕&ĞďƌƵĂƌǇϮϬ͕ϮϬϮϮϴ͗ϰϴD dŽ͗KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗D/ddĞƐƚŚĂƌƚĂŶĚĨŽƌŵ 'ĞŶƚƐ͕ :ƵƐƚƌĞƐĞŶĚŝŶŐƚŚŝƐĨŽƌŵĂŶĚƚĞƐƚĐŚĂƌƚŝŶĐĂƐĞǇŽƵĚŝĚŶ͛ƚƌĞĐĞŝǀĞƚŚĞŵ͘ ZĞŐĂƌĚƐ͕ dŝŵƐŚůĞǇ ƌŝůůŝŶŐ^ƵƉĞƌǀŝƐŽƌ K^ ϵϬϳͲϲϳϬͲϲϲϬϲ ϲϬϭͲϴϯϮͲϭϴϳϬ ---------------------------------------------------------------------------------------------------------------------------------------------------- -------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ 6RPHSHRSOHZKRUHFHLYHGWKLVPHVVDJHGRQ WRIWHQJHWHPDLOIURPWLPRWK\DVKOH\#H[WHUQDOHQLFRP/HDUQZK\WKLVLVLPSRUWDQW &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH James B. Regg Digitally signed by James B. Regg Date: 2022.02.25 09:58:26 -09'00' Submit to: OOPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 210-080 Type Inj N Tubing Type Test P Packer TVD 3660 BBL Pump 2.5 IA 0 1739 1732 1729 Interval O Test psi 1500 BBL Return 2.5 OA 0 20 20 20 Result P 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 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 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 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 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 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 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 TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: ENI Nikaitchuq / Oliktok Point / Well: OP05-06 Witness Waived by Austin McLeod by Email Feb 16, 2022 Michael Aivano 2/18/2022 Notes:MIT of 9-5/8" casing as required by Sundry #321-637 Notes: Notes: Notes: OP05-06 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMech anical In tegr i ty Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2022-0219_MITP_Nikaitchuq_OP05-06 9 9 9 9 -%5 2/18/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Workover on well OP05-06 Sundry number 321-637 (PTD:210-080) Update Date:Friday, February 18, 2022 6:52:23 PM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (OGC) Sent: Friday, February 18, 2022 6:52 PM To: Chaudhry Amjad <Amjad.Chaudhry@eni.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: Workover on well OP05-06 Sundry number 321-637 (PTD:210-080) Update NIkaitchuq OP05-06 (PTD 2100800) Recent BOPE test performance has been good, including tests witnessed by AOGCC Inspectors. If you get a successful casing integrity test AOGCC will waive the BOPE test due 2/21/2022. If for some reason the ESP completion has to be returned to surface, the BOPE test must be performed before rerunning. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, February 18, 2022 5:44 PM To: Chaudhry Amjad <Amjad.Chaudhry@eni.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: Workover on well OP05-06 Sundry number 321-637 (PTD:210-080) Update Amjad, I will forward to Jim Regg for his review. Mel Rixse CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Bryan From: Chaudhry Amjad <Amjad.Chaudhry@eni.com> Sent: Friday, February 18, 2022 4:55 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Workover on well OP05-06 Sundry number 321-637 (PTD:210-080) Update Hi Mel, I wanted to give you an update about the current operation on OP05 well workover since Bryan is on vacation. We are currently running with the test packer to perform the casing integrity test. If everything goes according to plan we will be running our ESP completion on Saturday afternoon and I am confident that, if everything goes as per plan, we will be landing the hanger way before midnight Monday, February 21st, 2022. Our 7 day BOPE test is due on Monday, February 21st, 2022, and Eni would like to get approval for continuity of the operation, if for any operational reason, it took longer than what we have planned. Because of the cable, we can’t suspend the operation while running ESP completion and performing the BOPE test. Worst case scenario will be that the landing hanger may be a few hours late from the due date of midnight, Monday 21st, 2022. Eni will provide AOGCC with daily updates of the operation and a daily look ahead of the timings, and we will notify AOGCC of any delay foreseen in the operation. Thanks Best Regards Amjad Chaudhry P.Eng Sr. Drilling Engineer Eni US Operating Co. Inc. 3700 Centerpoint Dr., Suite 500 Anchorage, AK 99503 (: 907-865-3379 D (: 907-346-0591 M E.mail: amjad.chaudhry@eni.com Please note that my email address has been updated, it is now amjad.chaudhry@eni.com. Please update the email you have in your records. This document and any files or e-mail messages attached to it contain data or information that is confidential, privileged or otherwise restricted from disclosure. If you are not the intended recipient, be aware that any disclosure, copying, distribution or use of any of the data or information contained herein or in any of the attachments is strictly prohibited. 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Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP change out Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 17,035 feet N/A feet true vertical 3,994 feet N/A feet Effective Depth measured 16,918 feet N/A feet true vertical 4,001 feet N/A feet Perforation depth Measured depth 8,709-17,035 feet True Vertical depth 3,830-3,994 feet Tubing (size, grade, measured and true vertical depth) 4.5 L-80 8,159' MD 3,746' TVD Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Senior Engineer: Senior Res. Engineer: Slotted Collapse 2,480 4,790 Slotted Burst 5,210 6,890 2,188' 3,831' 4,001 13.375" 9.625" 5.5" 8,671' 16,918' Authorized Signature with date: Authorized Name: Liner Length 154' 2,416' 8,671' 8,424' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-052 289.0 Size Conductor Surface Intermediate Production measuredPlugs Junk measured N/A Casing Structural 20" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-080 50-029-23427-00-00 N/A 5. Permit to Drill Number: Schrader Bluff Oil Pool 3. Address: 4. Well Class Before Work: 424.0 Representative Daily Average Production or Injection Data 252.0230.0 Casing Pressure Tubing Pressure ADL 355024, 373301, 390615, 355023 Oil-Bbl measured true vertical Packer 3800 Centerpoint Dr. Ste 300, Anchorage, AK, 99503 OP05-06 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 395.0 Gas-Mcf MD 2,416' 224.0 212.0 247.0145.0 TVD 907-865-3379 2. Operator Name: Eni US Operating Co. Inc. Stefano Pierfleci Well Operations project Manager Amjad Chaudhry amjad.chaudhry@eni.com WINJ WAG 139.0 Water-Bbl t Fra O G L PG , R t 6. A Form 10-404 Revised 3/2020 Submit Within 30 days of Operations 04/14/2020 By Samantha Carlisle at 10:14 am, Apr 16, 2020 DSR-4/16/2020 SFD 4/23/2020RBDMS HEW 4/16/2020 MGR 4/23/2020 4-½” 12.6 ppf L80 W563 Production Tubing5-½” Oil Swell Packer4-½” X-Coupling Clamps for ESP Power Cable, (1) 3/8" Chem Inj LineOP05-06Dual Lateral Producer With ESP LiftNikaitchuq Field –Oliktok PointTD 17,035' MD, 3,994' TVD, 94º Inc.As Completed17-Mar-2020Tracer September 2010Resman Oil/WaterTracer Sub9-5/8", 47# Intermediate Casing 8,684' MD, 3,831' TVD, 90º Inc.5-½” Ecc. Nose Guide Shoe, 16,920' MD,4,001' TVD, 92º Inc.8,494' MD, 3,816' TVD,9-5/8" SLXP Liner Hanger System 8,159' MD, 3,746' TVD, 77° Inc., Bottom of Motor Centralizer Centrilift ESP, 66 Stages Flex 47 + 20 Stages GINPSHH, GASSEP 538, 2 x GSB3DB Seals, 250 HP XP Motor –Without Tubing Check Valve8,206' MD, 3,759' TVD – L1,9-5/8" SLXP Liner Hanger System5-½” Ecc. 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umber of Failures: 7 Test Results Test Time 30 Remarks: BOPE testing began on 3/3/2020 and ended on 3/5/2020 with 7 failures witnessed. The annular, upper and lower pipe rams, kill HCR and manual valves, #14 CMV and the upper top drive valve a aTi ea- CR a pressure tests^fhe annular element and the upper and lowery ram --body and door seals, kill RCR and manual valves and upper top drive valve were replaced and #14 CMV was greased, cycled and these items were successfully retested. The pit volume totalizer and gas detection alarm systems were tested and operated properly The extended test time was due in part to test equipment freezing problems (-45 deg. F ambient). �i.r� flr;J-�- 62c� Swat 5 tice- festa,,, ZOICI STATE OF ALASKA TEST DATA O'�� MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Reviewed By: P/F OIL AND GAS CONSERVATION COMMISSION P.I. Supry Zn Lpzo Location Gen.: BOPE Test Report for: NIKAITCHUQ OP05-06 Trip Tank P P Comm Contractor/Rig No.: Nordic 4 PTD#: 2100800 DATE: 3/5/2020 Inspector Jeff Jones Insp Source Operator: Eni US Operating Company Inc. Operator Rep: Gueco/Wimmer Rig Rep: Holmes/Danielle Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bop11200317090549 Meth Gas Detector _ P P Rams: Annular: Valves: MASP: Well Sign P-- Type Test: [NIT 320-052 320-052 - 250/3500 ' 250/3500 - 755 � Related Insp No: P Number of Failures: 7 Test Results Test Time 30 Remarks: BOPE testing began on 3/3/2020 and ended on 3/5/2020 with 7 failures witnessed. The annular, upper and lower pipe rams, kill HCR and manual valves, #14 CMV and the upper top drive valve a aTi ea- CR a pressure tests^fhe annular element and the upper and lowery ram --body and door seals, kill RCR and manual valves and upper top drive valve were replaced and #14 CMV was greased, cycled and these items were successfully retested. The pit volume totalizer and gas detection alarm systems were tested and operated properly The extended test time was due in part to test equipment freezing problems (-45 deg. F ambient). �i.r� flr;J-�- 62c� Swat 5 tice- festa,,, ZOICI TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank P P System Pressure _2950_ P_ Housekeeping: P Pit Level Indicators P - P Pressure After Closure 1900 _P_ PTD On Location _P Flow Indicator P - P . 200 PSI Attained 29 - P _ Standing Order Posted P Meth Gas Detector _ P P Full Pressure Attained 94 P Well Sign P-- 112S Gas Detector P - P Blind Switch Covers: _ All P Drl. Rig P MS Mise 0 NA Nitgn. Bottles (avg): 4@25000 - P, Hazard Sec. P ACC Mise 0 NA Mise NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 1 FP � Stripper 0 NA No. Valves 14 FP - Lower Kelly 1 P _- Annular Preventer 1.13.625" FP Manual Chokes 1 P Ball Type 2 P #1 Rams 1 Blind/shear- P Hydraulic Chokes _ 1 P Inside BOP 1 P #2 Rams 1 " 2.875x5.5", FP CH Misc 0 _ NA FSV Mise 0 NA #3 Rams 1 ' 4.5" FP #4 Rams 0 NA -- -- #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 "3.125" - P - Quantity P/F HCR Valves 2 -3.125" FP Inside Reel Valves _ 0 NA Kill Line Valves 2 '3.125" FP Check Valve 0 NA BOP Misc 0 NA Number of Failures: 7 Test Results Test Time 30 Remarks: BOPE testing began on 3/3/2020 and ended on 3/5/2020 with 7 failures witnessed. The annular, upper and lower pipe rams, kill HCR and manual valves, #14 CMV and the upper top drive valve a aTi ea- CR a pressure tests^fhe annular element and the upper and lowery ram --body and door seals, kill RCR and manual valves and upper top drive valve were replaced and #14 CMV was greased, cycled and these items were successfully retested. The pit volume totalizer and gas detection alarm systems were tested and operated properly The extended test time was due in part to test equipment freezing problems (-45 deg. F ambient). �i.r� flr;J-�- 62c� Swat 5 tice- festa,,, ZOICI Nordic-Calista Scr%ices 9.0 NORDIC RIG 4 BOPE TEST 13 5/8" STACK LEGEND DATE 3j _24) Test Pressure 250 Low 3 Start time O 7oc 4 Vaso Finish WELL &05-0(10 Actual test time TEST# I n dAw)E, =: ✓��uC 11 Shell test, Annular, Dart Valve, Top Drive HydrauHevalve, Cm # 11,12;13,14, 5 and 10 Zyy 3'^^MM 5 -kill line valve, N"�l-iV i.Ju' } LDWQ.4. RAM VBR, Top FOSV, Top Dive manual valve, Kill HCR, Safety valve #1 --)VBR, 10, 8 VBR, Lower FOSV, Inside manual kill, CM# 7, 3, 9 Safes i3 (P VBR, Lower FOSV, Inside manual kill, CM#2, 6 VBR, Lower FOSV, Inside manual kill, CM#1 ?p VBR, Lower FOSV, Inside manual kill, Choke HCR '7 Lower Pipe Rams, Lower FOSV, Inside manual choke valve tt if Blinds, Inside manaal-kill, CM# 2, 9, 6 �Z Bleed down manual choke (CM# 15) from 2000psi to 1000psi in 1-2 minute �3 Bleed down Remote choke (CM# 16) from 1000psi to Opsi in 1-2 minutes �J VBR (smallest) VBR (largest) #I Annular (smallest).jaFeyy VKc.JE*FZ Annular (largest) i Other zao A1TE,n,P7 o4 ToP bu%X HYOVl 'cS Accumulator Test System Pressure 2L?-�D Draw Down Pressure 1900 200 PSI Full Recovery 29 SVGS 941 acs Four Bottles @ Z J Z --S' '131--,--o Comments: Test witnessed by j 1 - r- Jp Test witness waived �ysc. 1, SAM &L-. f4" Rig#4 — BOPE TEST Procedure ' Page 7 PAPER COPIES ARE UNCONTROLLED. NORDIC RIG 4 BOPS TEST 13 5/8" STACK LEGEND DATE 3 -2 i . Test Pressure 250 Low 3500 Start time _L7v- 31ild — TEST# `/ 7 Inside manual kill, Finish / 9 Kill HCR M % 9 TD manual valve (lower in DBS) fi, -4 o TD manual valve (lower in DBS) Comments: WELL n P V . - Actual test time Nordic-Calista Services 10.0 FUNCTION TEST WORKSHEET Rig44 — BOPE TEST Procedure Page 8 PAPER COPIES ARE UNCONTROLLED. 13 5/8 Shaffer / Hydril CLOSE OPEN FUNCTION TIME/SEC VOL/GAL TIME/SEC VOL/GAL ANNULAR ACL /17.98 J 14.16 BSR's 1 [ _ ✓ 12.22 I ( 11.90 UPPER VBRs S�V 5.14 4.86 LOWER VBRs Jr 5.14s� . �! 4.86 KILL HCR �� ✓ .61 _ .61 CHOKE HCR (`� ✓ .61 8 .61 Rig44 — BOPE TEST Procedure Page 8 PAPER COPIES ARE UNCONTROLLED. 60 0 14500- �\ _4000 _:5500 A\ � / / � � � � � -.4500 f _ � � � � - �•� � V `5f ti o �� • 'bio .� -! �� (ll/ lir�j i�O'• Lrq�hw (iaW�Js �� `t �, 1�1�� 11f ' ,111�1 I �i� �� 1� �"' o � � CHART N0. MC MP-60 -IiiR �\`V, 1�' I(J r r)r TER �� II CHART PUT ON _ 7,4XEN OFF !li I II I� EornrwNIJ/,ate 1o, REMARKS '< 7 ri n .' }T �� - % -i•-� 001.�' —Doss.: i I �364 ooS 3/3 \ L / 31w1k "' 1 A i ' 'I' I'll I h li\'i P• � u l c, I � � - - 1 1 i cn Iu l 1 1 , Ito %49Ptc4 NilttJuz/.oPas� (PPo 2-loc��od ) 3/3 - 3'sl eew 31u'�ZO� NN�G4— /JIY.ct,tle`,l(y� dPGs-c�, �� z10Ogoo, 313— 3i y 1 zo Z,: r Sop��- ids A)oivt(c 4 — tJ kcu pFos_�� (Pit ZkO06m) 31'3 `31�-/2t)z<; 02 TV- ;&1 zn� i I � i it IN 00, IN Olo IN r r ♦ - / / I / �A �� \ Ailt IA zo r •I I .� +/ \/,,(`1hC..;,60U_ "1` I��` , Ill„'I' �� ,, i Ic 'o l i 1 1 1 l Ili l ,M1 1L,,;f.N t( c' In II cn �/ol IIRti I I I I I OU+A C I I f�� o DP�dlll 1 I 1 1 � 0� ' �- U - v� / l r 1 1 • �:: ` \ AO; IN i IN 43(0 fD�'K 'gyp -ll -..�__ _ _�{ •/� CPTh zAoo8,) 31��fu�z” 313- 3/�lu,zy �6(t- 'ter ({� D Z C)OBOO) 3�3- 31s�?(rLo -. o� I / 611 !� SOO MV.c,oUo 1. ( �� i'4 1-146 / omss 1 fps' j ; \0.00 ^opo + NQfdt�4 — Ajiv-4 c�-c,"-tj QPOS-C(o w' (PSD ZA906o) V-5-3j517oz, ov fSw 3,we", i C;t 3 / ro t ti• �\ // � (,CS'• ITT"-J`inq.�/ \� r _ PIA I � n �r, Ii to i 6) ,a I1 '�_ o (':l �' �� ,err �1 1Cl 100 lil I - of , f rrvt��' \ l Poll it J/ Xf i "0009 .' US- I I WAW 4_ k)lV4Adwf otos-c4 S� -' - ---- � 3-- 31 7,onui t> nn ! Vjo 1 I � va 1 4_ 1- X\\ r � ,rel lrl /i i / it I �1II��'I iI`'1{ IIiI` II. !I' I!; I n it � IqV IV is 1 Ibr IIII IIII I I II !'ill I t l 4,I,t1 fd l I l p I r, iI I �:O 1 . t GCII.I I I 1 Icl'!) .-8n„uo�Hl �AIff f(1 i IiWnhhrcbi' o Ik�f , j 000v , 1r. t DOGS I . 6 / _f 1_ . Illnrdic4- OvAttria1 21006co) 313— 3/ s /ZoZu 3�3 - 3� S�zoza VIEVA -13"-I 122.5" 1-13" -1 I --118.5" I 22 23 ScaleDate Description 2' N.T.S MARCH 01 2016 3-1/8" 5000# NACE Drawn by RAVI MANI Dw NC1125150 TRIM SINGLE GUT •� CHOKE 8 KILL L VIEW AA VIEW BB by 00 MANIFOLD SYSTEM PACIFIC VALVE SERu CES llC WEIGHT 7400 LBS 4 1/2" Test Joint IBOP 7502 52 FOSV Side entry pump in sub LOW TORQUE XO x4.51BT Test joint 4.5 IBT x NC50on 3 1/2" Test Joint 4 1502 � S� FOSV Side entry pump in sub LOW TORQUE est joint etw blanking plugtool Nordic Rig #4 RKB 2-28-8 WELL: O P05-06 6)'tka +� GES C�1OS -06) THE STATE °fALASKA GOVERNOR MIRE DUNLEAVY Stefano Pierfelici Well Operations Project Manager Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Pool, OP05-06 Permit to Drill Number: 210-080 Sundry Number: 320-052 Dear Mr. Pierfelici: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.claska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, g Price DATED this ✓V day of January, 2020. 'BDMS � JA%f 3 12020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECED CEO JAN 2 8 020 6v3 ��3r> zo AOGGO 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❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Eni US Operating Co. Inc. Exploratory ❑ Development ❑� - Stratigraphic El Service El 210-080 - 3. Address: 6. API Number: 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 99503 50-029-23427-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 2 1 OP05-06 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): - 355024, 373301, 390615, 355023 Nikaitchuq Schrader Bluff Pool ' it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 17,035 3994 17,015 4,001 755 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 2416 13.375 2416 2188 5,210 2,480 Intermediate 8671 9.625 8671 3831 6,890 4,790 Production Liner 1 8424 5.5 1 16918 4001 1 slotted slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8709-17035 3830-3994 4-1/2" L-80 1 8,061 Packers and SSSV Type: Twin seal packer with PGV Gas Vent Flapper Packers and SSSV MD (ft) and TVD (ft): 2,053' MD/1,932' TVD valve TR-SCSV 2.81"X Profile 1997' MD/1,886' TVD 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑Q BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development ❑� • Service ❑ 14. Estimated Date for February 10th, 202 5PIg 15. Well Status after proposed work: Commencing Operations: OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stefano Pierfelici Contact Name: Amjad Chaudhry Authorized Title: Well Operations Project Man a er Contact Email: amiad.chaudh eni.com Contact Phone: 907-865-3379 � � Authorized Signature: ' '� Date: a - � COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Sao -o5 Plug Integrity ❑ BOP Test &2-� Mechanical Integrity Test ❑ Location Clearance ❑ Other: 113DMSjL6✓JAN 3 12020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes No Subsequent Form Required: 16 -ya y APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: r j V f1, (� A' A' I i!{7%K�/�j1/'' Submit Form and Form 10-403 Re n Approved applica o i I 1 t^�r<j`n the date of approval: Attachments in Duplicate * Cinii fttirollauum eni 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.pierfelici@eni.com January 27, 2020 Alaska Oil and Gas Conservation Commission 333 West 7' Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP05-06 Rig Workover Dear Commissioners, OP05-06 was originally completed on September 9th, 2010 with a Through Tubing Conveyed ESP pump set at depth of 8,255' MD/3,770' TVD. A new lateral was added in December, and completed on December 16th, 2014. The well had high GOR and a new completion was planned with a conventional ESP designed with gas handling capability. Work over was performed in May 2014 and new completion had a TR-SCSSV and a packer with surface controlled vent valve to test for possible natural flow due to high GOR during pump operation. Plan is to POOH the existing completion and run an upgraded conventional ESP on 4-1/2" tubing to enhance production. The estimated date for beginning this work is February 1 Oth, 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 Amjad Chaudhry at 907-865-3379. Sincerely, Stefano Pierfelici Well Operations Project Manager OP05-06 Workover — Summary Page OP05-06 Rig Workover PTD#:210-080 Current Status Well OP05-06 is currently in production. Scope of Work Scope of this workover is to pull the current conventional ESP completion and run in with a new upgraded conventional ESP system. General Well info Reservoir Pressure/TVD: Reservoir depth is 3830'TVD. This well is expected to have a static maximum bottom hole pressure of approximately 1200 psi 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/2-7/8" x 5" VBR/blind/ 4-1/2" Pipe TIFL/MIT-IA/MIT-OA: Due to the completion design these tests were not performed. Intermediate csg 9 5/8" was tested prior to drill out on November 2010. Well type: Producer Estimated start date: February 10th, 2020 Drilling rig: Nordic 4 Completion Engineer: Carlos Monteiro: carlos.monteiro@eni.com Work 907-865-3345 Sr. Drilling Engineer: Amjad Chaudhry: Amiad.chaudhry_geni.com Work 907-865-3379 Well Operations Manager: Stefano Pierfelici: Stefano. nierfelicipeni.com Work: 907-865-3320 Procedure: 1. MIRU Nordic 4. 2. R/U on x -tree to pump down tubing. 3. Perform well killing by pumping down tubing with 8.6 ppg brine. 4. Ensure well is killed. S. Set BPV. Nipple down X-mas tree and Nipple up BOP and test to 3500 psi. 6. Apply tubing over pull to release packer. 7. Pull tubing hanger and circulate annulus volume with 8.6 ppg brine. 8. Pull tubing and lay down TRSSV assembly. 9. Continue to pull tubing and lay down packer assembly. 10. Continue to pull tubing and lay down ESP pump assembly. 11. PU scrapper assembly and perform clean out run 12. CO to the top of SLZXP packer, POOH and LD CO assembly. 13. PU retrievomatic and set packer at 8,156'. Perform MIT to 1500 psi for 30 minutes and chart it. 14. POOH with packer and LD the same. 15. MU new ESP assembly and RIH to depth. 16. Land hanger, and test it. 17. Install BPV and nipple down BOP. 18. Nipple up tubing adapter and tree. 19. Pull BPV, install test plug and test tree (5000 psi test) 20. Circulate Freeze protect through tree down annulus A. 21. Shut in well. 22. RDMO. Current schematic of the well: at 3-1h' 9.2 ppf Production Tubing, IBTM W;* 3-h' x-cplg cable clamps, for ESP Power Cable, 3/8" Chem /�^�� Inj Line. W hyd. Control line eni petroleum 1.997' MO, 1,886' TVD - TR-SCSV, 2.61"X Profile, r' SS hyd. Control line OP05-06 2,053'MD, 1.932'TVD 37' Inc. Twine Seal Packer with Dual Lateral Producer _ PGV Gas Vent Flapper Valve.'/.' SS hyd. Control line 2,143'MO.2.002'TVO-X-nipple2.81^ 31/2" Completion 3-'/r'x-cplg cable clamps, for ESP As Completed Power Cable, (1) 3/8" Chem Inj Line 5/ompl4 e.033'MD,3.720'TV027/8"ADVValve Tracer September 2010 6,061' MD, 3,728' TVD – Discharge Gauge Sub 8.147' MD, 3,746' TVD, 77' Inc., Bottom of Motor Centralizer Centrilift ESP, 116 stages P18SXD +25 stages G42. GSB3-DB seals, Liner, Li $lotted gas separator 380GSVTHV, 210 HP MSPt motor 6-h" d Li ppf 8,172' D. 3,752' TVD - Bottom of Motor Shroud VA' Silver Bullet Ecc. 17,015' MD, 4,053' 8,3874tng E 606' MD, HAL 5-h' 011 Swell Nose Guide Shoe with TVD /CaainB ;It Window Prker ` Bent Joint\ 89- Inc. a f \\ 8,208' MD. 3,758'7TVD–L1-Baker SLXP Liner `M,N Hanger/Packer 1f _.__ 3W5 -h- Silver Bullet EccNose Guide Shoe 8,3,- BPLiner/ — Slotted Liner, \ Interm. Casing t17 pp/ 8.618", 479 HAL 5-'h" 18,920' MD, 4,001' TVD 8,884' M0, Oil Swell Pecker 92° Inc. 3,831' TVD Rosman Oil/Water uq No liktok Point 90° Inc' Tracer Sub Planned schematic of the well: 4-1h' 12.6 ppf LBO W563 Production Tubing OP05-06 4-W X -Coupling Clamps for ESP Power Cable, (1) 3/8"Chem lnj Line Dual Lateral Producer With ESP Lift Planned 23 -Jan -2020 Tracer September 2010 8.147' MD. 3,746' ND, 77' Inc,. Bottom of Centrilift ESP Pump Motor Centralize 8,172' MD, 3,752' ND - Bottom of Motor Shroud 5-K" Silver Bullet Ecc. 6-'/," 15.5 ppf Slotted 8,387.8,404' MD, 5-K' Oil Swell Packer Nose Guide Shoe with Liner, 17,016' MD, Casing Exit Window 4 \114, Bent Joint 4.053'ND, 89° Inc. 8,208' MD. 3,759 ND - Li. 93/8"SLXP in.Hanger ^' 4W System i. S -K- Silver Bullet Ecc Nose Guide Shoe MAE AL 5,494' MD, 3,815' ND, 9-618" SLXP Liner Hangar System 93/8", 47# Intermediate 6-K" 17 ppf Slotted Nlkaachup Roq-0ilkak Point Casing &884' MD, 3,831' 5=b- 011 Swell Packer Rosman Oi11VJater Lina', VD, 91' lnc N0, 90- Inc. 'TVD, 92° Inc. Tracer Sub N 4-0 r. v a E fC tko E 4-0 v .c � 3 00 c, Ei a O c 0 U 10- 0 O Z Z bb Ln U N + 0 -� (0 V O � m Ln E — UPS 00 ix a M LU ^W i..L Ln z_ Ln w x Z N J N00 Ln A, A N LL E V N Ln — UPS 00 ix a LU ^W i..L Ln z_ w x Z LL J N00 = J rl J f°- w i � Y N o 2 I q• A, A N E N Nm Of UPS co / ^W i..L Ln w x Z N00 J rl J � Y N 00 r -I i 06 N d) O (0 L 0 Vete®Gray MB -247 SURFACE COMPLETION SYSTEM PRP 10161, NC Gc irlaginabun c: work 10 OF 10 23 JANUARY 2009 • • 0 0 a O C On M O N 0 r 1 O m O N mN P N r n 0 m W m N. ra . MN '- r • N j v etch U kV cd 2 n r Ip 11co IO� co COMImp N m COC) COCIco q N N N N M N N O N N OMD 0 N V t09 C7 l w W cr) gat IrrLa to € 5 y o O N 0) nV N O M N CO 0) M O m m CO h 0) CO CO m m n m V) CO a N N N :711' C`"- El V r C . ci U) C 0 CO 0/ 0 v n Ip M 0 CO N N CO V) Q N V) N M 0 N M M M V v M V v 6 e w k 6 ti m 0) CD m O) CA 0 CA m m m n C) n n co co 0) n n n CD CO n O 0) n y Q N N . 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Inc. 0 f0 — (Y1-°3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP05-06 Sundry Number: 314-267 Dear Mr. Wright: 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, , --777(- 1 _ Cathy P. ' oerster Chair DATED this(.---1 day of April, 2014. Encl. i $ @'n ';,. ,1.::„4 Y • , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 'i 277 7.,� APPLICATION FOR SUNDRY APPROVALS w ` " '� 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program El Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 • Time Extension El Operations Shutdown El Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ Other: _Change Out ESP_ El• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Eni US Operating Co.Inc. Exploratory ❑ Development Q• 210-080 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23427-00-00 ' 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require a spacing exception? Yes ❑ No El OP05-06 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): 355024, 373301, 390615, 355023 ' Nikaitchuq Schrader Bluff Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MDigt): Effective Depth TVN): Plugs(measured): Junk(measured): - 17,035 - 3994 l GI I g 1.7035 LIoOl �1b-3994 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 2416 13.375 2416 2188 5,210 2,480 Intermediate 8671 9.625 8671 3831 6,890 4,790 Production Liner 8424 5.5 16918 4001 slotted slotted Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8709-17035 • 3830-3994 4 1/2 L80 8,166 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development El• Service ❑ 14.Estimated Date for 7-May-14 15.Well Status after proposed work: Commencing Operations: Oil Q. Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG El Abandoned ❑ Commission Representative: GSTOR El SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Michele Cesari Email giuseppe@maugeri@enipetroleum.com Printed Name James Wright Title Drilling&Completions Engineering Manager j'A i Signature Phone Contac 907-865-3338 Date 4/24/2014 / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\L&-219''t Plug Integrity ❑ BOP Test L.17 Mechanical Integrity Test ❑ Location Clearance ❑ Other: 14 3SDD rs:, vniO `In7T -t- .,,� � � RBDMS- MAY 0 8 2014 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /d — y a y / p APPROVED BY Approved by: / �y /� COMMISSIONER THE COMMISSION Date: 4 _2,5 -/(i. I•,z tAp 1 I RillaG F t t �Id�aP 00,05 Submit Form and Form 10-403(Revised 10/ 12) Appr onths from the date of approv /Attachments in Duplicate 4 • • Ilk: fri* Enii 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 James Wright Phone(907)865-3321 Email: James.wright@enipetroleum.com April 24th,2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP05-06 Rig Workover Dear Commissioners, ENI US Operating Co. Inc.hereby applies for a Workover Sundry for well OP05-06. • OP05-06 was originally completed on September 9th, 2010 with a Through Tubing Conveyed ESP pump set at depth of 8,255' MD/3,770' TVD. A new lateral was added in December, and completed on December 16th, 2014. The well has high GOR and a new completion is planned with a conventional ESP designed with gas handling capability. The completion will have a TR-SCSSV and a packer with surface controlled vent valve to test for possible natural flow due to high GOR during pump operation. Due to vent valve, it is not possible to pressure up on the packer to test from surface. The estimated date for beginning this work is May 7th, 2014. 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 907-865-3338. Sinerel , James Wright Dulling&Completions Engineering Manager OP05-06 Workover— Summary Page OP05-06 Rig Workover PTD#:210-080 Current Status Well OP05-06 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 and packer. ----E— 'au.F/•w r At General Well info Reservoir Pressure/TVD: The ESP downhole gauge is reading 995 psi at 8,049'MD/3,724'TVD on April 24 , with ESP in running. Reservoir depth is 8,709'MD/3830'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. 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 on November 2010. Well type: Producer Estimated start date: May 7st 2014 Drilling rig: Nabors 245 RWO Engineer: Marc Kuck: Marc.Kuck@enipetroleum.com Work: 907-865-3322 Procedure: 1. MIRU Nabors 245. 2. Shear lower GLM valve and circulate 9.1 ppg hot water with 3 % KC1 kill fluid through tree. 3. Set BPV. ND tree and NU BOP and test to 3500 psi.• 4. Pull tubing to lower GLM. Rig up wireline and pull tubing stop check valve. 5. Circulate out remaining production fluid. 6. Continue POOH and lay down ESP assembly. 7. MU new ESP assembly and RIH to setting depth. 8. Land hanger, and test it. Set packer. 9. Install BPV and nipple down BOP. 10. NU tubing adapter and tree. 11. Pull BPV, install test plug and test tree.( 5000 psi test) 12. Circulate Freeze protect through tree down IA. 13. Shut in well. 14. RDMO. Current schematic of the well: ■ 4-W 12.6 opt Production Tubing /i' 2,168'MD.2,021'TVD 42°Inc-GLM,KBMG, 4-72"x 1",with eni petroleum 2.000 psi STS-1 SOV installed r 4-WNE x-cplg cable clamps.for ESP OP05-06 Power Cable,(1)3/8"Chem lnj Line Dual Lateral Producer I7.947'MD,3700'TVD 77°Inc-GLM,KBMG. 4-'r:'x I",with with ESP Lift 3.100 psi STS-1 SOV installed As Completed 8,049'MD,3,724'ND-Discharge Gauge Sub 11/16/2013 8,151'MD,3,747'TVD.77°Inc-Bottom of Motor Centralizer Centrllift,TTC-ESP,116-stage 380P 18SXD pump.513 GSB3 seals, 150 HP MSP325 motor Surf.Casm, 4 A 8,166'MD 32#Shroud Assembly with cable and 13.318".68# chemical injection line teed-ihlUS Slotted Liner, 2.416'MD.2.189' 5-w Silver Billet Ecc. 5-12"15.5 ppf ND 8,387-8,404'MD. HAL 5-'S 00 Swell �/ Nose Guide shoe with 17.015'MD.4.053' 51°Inc. ` Casing Exit Window Packer Bent JointTVD D 8.206'MD.3.159' i \� 89°Inc. TVD-L1-Baker SLXP Liner • Hanger/Packer - -- Item(Upper Lateral) MD((1) - � --� 5 1/2"Oil Swell Pck 81 8,421 - - - - - - - - - '4"Silver Bullet ECC. 51/2"Oil Swell Pck 82 9,356 \ - - -.. - __ -_ _ Nose Guide Shoe8.494'MD. ' 51/2"Oil Swell Pelt 83 11,999 3,816'ND- 51/2"Oil Swell Pck 84 13,558 Baker SLXP I it I 1 '�� ' 51/2"oil Swell Pck aS 15,117 Liner Hanger+ \41111001....„ 999 51/2"Oil Swell Pck B6 16.421 Packer -- - -- - - - .. kern(Lower Lateral) MD{ft) ___..-1. Slotted Liner, Resman Trace rSub 81 ROS 20/RWS 158 8734.6 Interm.Casing item(Lower Lateral) MOM) t3-'le"17 ppf Resman Tracer Sub 82 ROS 148/RW5160 11798.39.5/8".47# 51/2"Oil Swell Pck 81 8X19..5 HAL 51'2 " 16,920'MD,4,001'TVD Resman Tracer Sub OROS 149/RIS 159 13666.8 8,684'MD, 51/2"Oil Swell Pck 82 117729 `-III Swell Packer 92°Inc. Resman Tracer Sub 84 ROS 147/RWS 157 15111.8 3,831'ND 51/2"Oil Swell Pck#3 13640.8 Resman()Mater NI _l=2,1- i'^1',DM 90="Inc. 51/2"Oil Swell Pck 84 15085.7 Tracer Sub • • Planned schematic of the well: 3-W 9.2 ppf Production Tubing,IBTM 3-Yz"x-cplg cable damps,for ESP Power Cable,3/8"Chem eni r� Inj Line,W hyd.Control line petroleum OP05-06 TR-SCSV,2 81"'X'Profile,Y:SS hyd.Control line Dual Lateral Producer +/-2013'MD,1900'TVD 35°Inc.Twine Seal Packer with 3 1/2" Completion ,O s PGV Gas Vent Flapper Valve,W SS hyd.Control line X-nipple As Plan' 3-W x-cplg cable damps,for ESP v2 Power Cable,(1)3/8"Chem Inj Line 2 7/8"ADV Valve +1-8,155'MD,3748'TVD,77°Inc.,Bottom of Conventional ESP Slotted Liner. 5-WSilver .Bullet Ecc- 5-'2"15.5 ppf • 8.367.8.404'MD. HAL 5-W Oil Swell Nose Guide Shoe with 17,015'MD.4.053' CasingExit Window Packer �j \4b. Bent Joint TVD 89°Inc. 8.206'MD.3.759' TVD-L1-Baker SLXP Liner Hanger/Packer _ - _ _ 544"Silver Bullet Ecc Nose Guide Shoe 8.494'MD. -Tv/ I I 3.816'TVD- Baker SLXP Liner Hanger/ J Packer . r Slotted Liner. Interm.Casing 5-' "17 ppf 9-5/8".47# HAL 5-V. 16.920'MD.4.001'TVD 8.684'MD. Oil Swell Packer 92°Inc. 3.831'TVD 90°Inc. Resman OiLWater Nikaltchuq Field-OI,ktok Point Tracer Sub VetcoGray MB-247 SURFACE COMPLETION SYSTEM � -tAAIN /CL r------- `3.50 �" ---15' 37.19 a o' 1,4 1 /11111A,Iii.lip 811;11, � sit n44. 111E4° 1 011 . . = t Si�� a�IONt=1, 4 �� T.O.S. EL 26' 5-3/4" . rl ;i:k 11 1.062 OFFSET C/L 1 B.O.S. EL 25' 7-1/4" 5.00" EL 25' 2-1/4` O TOP OF WELLHEAD Z / 1 01. _ d ` PFT �' ELECICAL Y c ! FEEOTHRVTR21.81 1lki, /: 13 MN I3-VG5/518'77 50CW00 PSIAP 6��. w 8r ;4 1 11 4-1/ • r ao 5000 16 _,_..... ic illiigr'IL' I I 1 i.■ `: ___�� '0 ___ G-�as 111 1I III.3.437 OFFSET 1080 6.50•- III IU ,11 z I► 'n 5000 PSI_.1 .7._I:==' 1=C BjI�1'_ 2-1/16• M - OU T '1 �..C� �- ;t�,1' 66.71 POSITION •i I j� 13. 5000 PSI 52.96' �.iiiIk l, mu VG 134 MOO. 280• _'1 :��1 !•'II 34.00' 50c• PSI.1 i I i - 1' OUT 0• 24.2 r- - ' 15.25' POSmON .CII 1=. TCP OF GRADING III1 EL 16'TOG 1-1/4' L t.ao i PROPRIETARY NOTICE ei tz- v09ray• 20' OD 1331 K-55 l� LL"'- •••01111.1.6•••a11r1.r 13-3/8' OD 68# L-80 °"""` ENI ALASKA ON V. LVARADO 9-5/8- OD 53.51 L-80 I I I dm in HORI OXN 13-3/BTAL TI 9-5/OWL SYSTEM 24-1/2" OD WITH 6-5/B VT L DORAN x 4-1/2 WITH 6-5/8 MT AND ESP FLAT CABLE 2.1,vt1 m ,. ..t''...........a 1=s. H173370-1 Ir......- .0 � w op ON as XXX am.,1 % l. 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E+ ' in E I 0 F"" 0 U CZ O cs 6 i CL co c W W cn Z w co m °' I Z > aU CU a o Z o Q ' R N C J o. z 'r o 5 T E a. c., o co o O Za a u c 0 J it o o ;I C� a N N r,to G 0 m H CO H U H H V) ~ o Q z °. H Q °zo_ o tI 'a, U Z D 3 M •• rn o M r oF z O > w H , m N m 0 'I d E co t0 CO -J M N Z �• d o $ o o Z �' c a U o U %a E Q. p — a, O — a w E E ao 3 a 3 0 <c , 0 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ?/i� 4114 DATE: 3/28/2011 P. I. Supervisor FROM: Bob Noble SUBJECT: No-Flow Petroleum Inspector ENI Petroleum Nikaitchuq OP05-06 PTD 2100800 March 28, 2011 I met with ENI Petroleum Rep Delton Carol and I signed in at the control room. We went over what I wanted to do on the No-Flow Test. Delton told me that the well had , been flowing to atmosphere for over 24 hours. I observed the following: Time Status Flow Tubing psi IA psi 11:00 S/I 0 0 psi 1 psi 11:30 S/I 0 7.6 psi 3 psi 12:00 Open well 1500 scf 13.2 psi 7 psi 12:15 Open well 100 scf 2 psi 2 psi 13:00 Open well 0 scf 0 psi 1.5 psi ' Well had what I would call a strong whisper of gas out of a half inch hose. 13:01 S/I 0 0 psi 1.5 psi 14:00 Open well 1200 scf 11.2 psi 7.7 psi 15:00 Open well 0 scf 0.2 psi 1.6 psi Well had what I would call a strong whisper of gas out of a half inch hose again. - At no time did I see any trace of fluid at surface. At this time I feel the well will keep producing the strong whisper of gas. Delton told me that he felt this was the strongest well that they had No-flowed so far. Attachments: none No-flow ENI OPO-506 3-28-11 bn.doc Scblumberger Drilling &Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Christine Shartzer Well No OP05-06/0P05-06PB1/0P05-06PB2 Date Dispatched: 24-Sep-10 Installation/Rig Nabors 245E Dispatched By: Paul Wyman Data No Of Prints No of CDs OP05-06-Logs: 2 in MD 1 2 in TVD 1 5 in MD 1 5 in TVD 1 OP05-06PB1 -Logs: 2 in MD 1 2inTVD 1 5 in MD 1 5inTVD 1 OP05-06PB2-Logs: 2 in MD 1 2inTVD 1 5inMD 1 5 in TVD 1 OP05-0610P05-06PB1/0P05-06PB2-Digital Data 1 Received By: Please sign and return one copy to: D&M,2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 ✓�� pwvman@slb.com Paul Wyman (0 037 Fax:907-561-8317 LWD Log Delivery V2.1,03-06-06 EININP- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 Gas Ill Plugged❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory❑ GINJ❑ WINJ❑ WDSPL❑ WAG❑ Other❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: -5.Date Comp.,Susp.,or 12.Permit to Drill Number: ENI US Operating Co Inc Aband.: 9/19/2010 210-080 3.Address: '6.Date Spudded: 13.API Number: 3800 Centerpoint Drive Suite 300,Anchorage 99503 8/10/2010 50-029-23427-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 3212.4 FSL 1547.6 FEL S5 T13N R9E UM 9/6/2010 OP05-06 Top of Productive Horizon: 8.KB(ft above MSL): 53.2 15.Field/Pool(s): 931'FSL, 1425'FEL,S33 T14N R9E UM Ground(ft MSL): 12 Nikaitchuq Total Depth: 9.Plug Back Depth(MD+TVD): 3700 FSL 1656 FEL 28 T14N R9EUM 16918 MD/4001 TVD 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.T. - •-- • •.• TVD): 16.Property Designation: Surface: x- 516732.25 y- 6036565.72 Zone- 4 17035 MD/3993 TVD 355024,373301,390615 TPI: x- 522119.1731 y- 6039576.297 Zone- 4 11. ' II epth(MD+TVD): 17.Land Use Permit: Total Depth: x- 521844.99 y- 6047626.04 Zone- 4 none ADL 417493 18.Directional Survey: Yes El No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) (ft MSL) 1879 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 ND I 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 2416 SURFACE 2188 16 444 bbls 10.7#ASL,75 bbls 12#Crete 9-5/8" 47 L-80 SURFACE 8671 ✓ SURFACE 3831 12.25 157 bbls 12.5#Deeperete 5.5" 17 L-80 8494 16918 3816 4001 8.5 slotted liner 1- 23.Open to production or injection? Yes 0 No❑ If Yes,list each 24. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD) slotted liner 4.5 3982 NA/ESP completion G MITE I 25. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 'ION to DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED t• er 26. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): NA(to be Jan 1,2011) ESP Comoleti n Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: NA NA Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - 27. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No If Yes to either question,list formations and intervals cored(MD+ND 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. RECENED- nir0SZHi RBDMS OCT O'8, 20 Oil ties Ceons.rye : n ateh9tsh!� 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ 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 1879 1785 OA sand top 8423 3804 Formation at total depth: OA sand 17035 3993 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 Title: Well Operation Project Manager Signature: Phone: Yj (o S- 330° Date: 6l 3 0 /0 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. 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Schematic -Actual 0 34 34 0.1 36 36 0.1 I , 37 37 0.1 $8 40 40 0.1 43 43 0.1 00 P 124 124 0.2 r „.., r 2,092 1 ,963 38.2 100 2106 1 ,973 38.7 0 2,328 2,133 49.9 i 0 i„ , ,,„ j' 4 ,,, ..,,,,1 2,372 2,161 50.9 1 2,415 2,188 50.9 r MP CASING,13 3/8, 0,2,415.6 2,425 2,195 50.9 8,151 3,747 77.2 0 iiIIIM 01 6,159 3,749 77.1 or smon 8,208 3,760 77.0 0 CU= 8,228 3,764 76.9 8,242 3,767 76.9 8,255 3,770 77.0 0 0 8, -_ y 8,494 3,816 81 .1 8,516 3,820 81 .7 0 1 8,523 3,821 81.9 / 8,585 3,827 85.3 �Ii 8,627 3,830 87.7 8,671 3,831 89.6 I.� FA CASING, 95J8, 8.681 , 0, 8,671.1 8,686 3,831 90.3 I 8,731 3,831 92.2 8,743 3,830 92.1 11,795 3,848 86.5 1 r 11,806 3,849 86.6 13,662 3,892 89.3 13,667 3,893 89.1 i i 13,675 3,893 88.8 15,107 3,952 86.3 15,112 3,953 86.3 15,120 3,953 86.2 16,918 4,001 92.5 J l.. LINER, 81 14, 8,494, 8,426.1 17,035 3,994 94.0 , Wel__lbore Job Date I0P05-06 :_7.1 EDRILLING, <now> ■ II III h H 01 Well type HORIZONTAL-OP05-06,1011/2010 1:25:56 PM ftKB(MD) Schematic-Actual 32 -11.RImDEPTH,t12,3958,0,318.013/16.395832,19 Y �'" 12 VG-LIB247 TUBING HANG ER.I :1';': � _� 2-1 R KB.,956 N. 1 0 35.4 38 ..;....:.t.�....s.:.+._._t.ti,ua �/, �� W. R a• r'' -,,orrAr 66 %/ /// /��/, JI - A , 1J,X-OVER PUP JT.(fiTS�PIN%IBTpPIN),i1d,3993,3t,9.1 ll ' 2J,CASING PUP JT,956,B5.52,36,25 1 24 1-3I JT(OUT),1318,12.115,10 1-3,CASING PUP JT,1316,12.415,37,2-4 i 165 WI 1-4,VIT JOINT.4S%5S RTS3 B X 3,512,395843,735 1S,X-OVER PUP JT.QBTLI PIN%RTS 13 BOX),4 12,3958,121.23 U 0 /1,741 li';li�i i 1-9,TUBING PUP JT-,412,3993,2199,58 2,174 I p 1S,CASING 37,1316,12.415,10,2246.3 1.6,CASING JT(STOP-RING&CENTR@ 111 ABOVE FC),1336,12.415,2285,4211 Al 1-7,FLOAT CO LIAR,1336,12.415,2,35,19 2503 / V I 1-3.CASING Jr,1316,1z.41s,2110.418 I�A 1-9,CASING JT(STOP-RING&CENTR(§S&V ABOVE FS),1336,12.415.2372,41Z 2,334 I �• "' 1-10,FLOAT SHOE,1336,2,411,19 1-10,TU B ING JO INT,l 12,3958,2,105,6046.1 '"%, k ( /` 1-11,X-OVER PUP JT.(EUE PIN I10TL180)C),4 2,3958,8,151,6.1 2,414 ` �•;. ! 1-12,PRE95URE DISC HRRGESUB(DG 49 S7�6,3968,8,157,2.1 y 1-13,X-OVER P UP JT.QBTLI P IN EUE BOX)412,3958,8,160,611 } �_ l ,i 1-1 l TUNING JOINT,412,3.98 3,166,4211 6,003 1 t, -- 1l, 1-15,X-OVER PUP JT.(NSCT P IN x IBTLI B0)0 412,3953.3213,99 � t 1 16 TTC X-OVER 11649CREEN INTRI(E,5 8217,105 6,854 / •!i 1-17,UPP ER TANDEM SEAL,GSB3D B,5.130,8233,69 1 1-18,LOWER TAN D ELI SEAL,G513-D B,5.130,8235,59 �� ( ° 1 11 1-1 9, HP LISP 1-250 J2300V,5Z1,8242,1111 6,954 .i„.. ,:,Y 1-211,GAUGE MOUSING,412.8253,L7 I . 1-21,LITR.C ENTRALZER,5891,8254.23 l' 3-1,SIZXP LINER TOP PCIWI NASD SLIPS,3114,4,332,8,494,21.1 7,036 4' 3-2,X-OVER r VT-HT%5 VI HYD- ,7,4,832,8515,1.4 x 4 ��i 3-3.SEAL BORE EXT.,6114,4 ,8576,1.4 6,159 / ''",,mom ivi.�' I 3-4,X-OVER,5 I2,7332,8521,2.1 irriui�)' 2-4,CSG,956,8581,39,8,5655 .°...� ia��" A B O V E CASING 8,242 • I�&S 1 2-7,CASING JT,9 S6,8581,8586,403 p 2-3,CASING JT(@TOP-RING&CENTER @ S&B ABOVE FS),966,8.681,81627,12,1 8,494 ;!/' %/�` 2-9,FLOATSHOE,966,8.681,8,669,19 ' l /�jh 35,B LAN KLIN ER JT.,512,1,892,8,523,1665 6,523 ;,'+�i� , �� 3-6,BL4NKLIN ER JT.W6WELL PCI'3.,82m,4562.N ,41,7 11412i 37,PUP JT.NYDS21,512,4 ,8,731,3.1 '�� 38,94 RESNAN TRAC ER SNP ROS-20,636,4862,8,735,52 •vii�� 8 596 I 39,SLATTED JT.,512,4892,8,743,3111011 I� li 3-10,B LANK LIN ER JT.SL JELL PCP:R.,8210,489211,753,418 I! i 311,PUP JT.MYD-621,512,4192,11,795,35 8,656 I/ II''� 3-12,LOR ESOAN TRACER SNP ROS-148,636,4,332,11,798,82 I t / //A ''" 3-13,SLOTTED JT.,512,4�2,11,187,18112 r,. 8,686 t._-_..__...._.... ................... .__.__�_-_ . 314,ELAN K LIN ER JT.NL 4siNELL PC KR.,512,1,33,13521,413 � 315,PUP JT.MYDfi21,512,4332,131862,3.7 316,X-OVER(MC PIN X HVD-521 BO)57,6 Vt,4.892,13586,1D 11,795 3-17,92 R ESOAN TRACER SNP 005-149,635,4562,131867,75 318,X-OVER(HYDS21 PIN%D WC 110)9.6 1,6,4.332,13574,0.6 319,SLOTTED JT.,512,4592,13,675,13905 13,667 3211,B LANK LINER JT.W5INELL PC 164„82m,4592,15136,415 3-21,PUP JOINT HVD-621.512,4.392,15.137.3.6 11. 3-22,X-OVER(DWG PIN X HYD-621 B0)1,6 I6,4.332,15,111,1 D 15,111 323,P1 R ESDAN TRAC ER SNP ROS-147 6 36,1,332,15,112,7 S 324,X-OVER(1YD-621 PIN X DWG lox),5in.433,15,119,06 16,441 is ■ IB is 3-25,SLOTTED JT.,512,4292,15.12.1,156.7 16,917 R I, f326,X-OVER,512,4892,16511,15 - 327,SILVER 8ULLETSHOE,616,16918,19 16,983 17,009 17,028 Eni ESP Division Well Name: OP05-06 ENI Petroleum Daily Report Well Code: 23985 • CO. Inc. Field Name: Nikatchuq 2 ^ Date:8/10/2010 - Report#: 1 APUUWI: (� page 1 of 1 Wellbore name: OP05-06 Well Header PermitlConcession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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(Nlhr) DFS(days) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 -1.06 Daily Information Depth End(RKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftlhr) POB Temperature(°F) Weather Wind 79.0 36.3 OC,Lt Rain,WC 28°NNE @ 13.4 27.9° mph Daily summary operation 24h Summary PREP NEW LOCATION,MOVE SUB&UTILITY MODULE'S INTO PLACE.R/U ALL SERVICE LINE'S,R/U&TEST STARTING HEAD,RISERS AND SPACERS.CLEAN OP12-01 LOCATION.PICK UP D/P&BEGIN BUILDING SPUD MUD. Operation at 07.00 PICKING UP DRILL PIPE&MIXING SPUD MUD. 24h Forecast COMPLETE P/U&STAPPING D/P&BHA.FINISH BUILDING MUD VOLUME.ALIGN AND SPOT CCB UNIT AND CUTTINGS TANK WITH CRANE. LIthology Shows MAASP Pressure(psi) Mud Weight(Iblgal) Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase ; Opr. Act. Plan Oper.Descr. 03:00 13:00 10.00 10.00 MOB 'A 2 P DEMOBILIZATION OF RIG,R/D SERVICE LINE'S&INTERCONNECT'S.PREP SITE.SET RIG MATS INTO PLACE FOR SUB MODULE&UTILITY MODULE.TRANSPORT&SPOT SUB MODULE OVER HOLE.TRANSPORT&SPOT UTILITY MODULE. 13:00 17:00 4.00. 14.00 MOB A 2 P R/U SERVICE LINE'S HAND RAIL'S&LANDING'S.REMOVE HATCH COVER FOR OP05-06.CLEAN OP12-01 SITE. 17:00 00:00 7.00. 21.00 MOB 'A 5 P NIU RISER&SPACER SPOOLS.INSTALL STARTING HEAD&TEST TO 500PSI FOR 10 MIN.OK.MODIFY FLOW LINE TO CORRECT LENGTH.N/U&TEST QDC.RISER,500PSI FOR 10 MIN.OK.INSTALL FLOW LINE&HOOK UP TURNBUCKLE'S.LOAD D/P INTO PIPE SHED&STRAP.BEGIN WORK WITH CRANE TO SPOT CCB UNIT, CUTTINGS TANK AND CHUTE'S 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 / Eni representative Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 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 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 0041 Eni E&P Division Well Name: 0P05.06 EN!Petroleum Daily Report Well Code: 23985 • Field Name: Nikatchuq n Co. Inc. Date:8/11/2010 - Report 2 API/UWI: 2 n II -_ -- _ page 1 of 1 Wellbore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 -0.06 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 90.0 38.8 OC,Fog,WC 30.2° 74°ENE @ 14.7 mph Daily summary operation 24h Summary RIG PREPARATION&TESTING.BUILDING REMAINING SPUD MUD.P/U DIP,HWDP,JARS&BHA.CONDUCT PRE SPUD MEETING. Operation at 07.00 DRILLING AHEAD 24h Forecast CLEAN OUT 160'CONDUCTOR PIPE.DRILL TO+/-2,409'MD/2,173'TVD Uthology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 8.80 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act Plan Oper.Descr. 00:00 01:30 1.50 1.50 MOB E 1 P SERVICE RIG&STRAP D/P IN PIPE SHED 01:30 08:30 7.00 8.50 MOB E 1 P P/U 117 JTS D/P&RACK IN DERRICK.MIX SPUD MUD. 08:30 10:00 1.50 10.00 MOB E 1 P CHANGE OUT SAVER SUB ON TOP DRIVE.CALIBRATE H2S/LEL ALARMS @ BELL NIPPLE.LOAD PIPE SHED& STRAP PIPE. 10:00 19:00 9.00 19.00 MOB E 1 P P/U D/P&RACK IN DERRICK FOR A TOTAL 86 STANDS.STD BACK 5 STDS HWDP W/JARS.TEST AUDIBLE ALARMS,H2S,METHANE,FIRE&HIGH LEVEL DIESEL @ 16:00 HRS 19:00 20:30 - 1.50 20.50 MOB E 1 P P/U BHA&PREP REMAINING COMPONENTS IN PIPE SHED. TEST AUDIBLE ALARMS AGAIN FOR CREW CHANGE @ 20:00HRS 20:30 21:30 1.00 21.50 MOB E 1 P CHECK CIRCULATING STSTEM&FILL CONDUCTOR.NO LEAKS.TEST HIGH PRESSURE MUD LINE TO 2,000PSI. NO LEAKS 21:30 00:00 2.50 24.00 MOB E 1 P CALIBRATE CANRIG&ANADIL BLOCK HIGHT.FIX PARAMETERS ON RIG PVT.MODIFY WELDED BRACE ON CUTTINGS CHUTE.MI SWACO ALIGNING&TESTING CCB UNIT.CONDUCT PRESPUD MEETING WITH ALL PERSONNEL.STRESSING SAFETY,COMMUNICATIONS&COMMITMENT TO MEET OR EXCEED EXPECTATIONS. 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 Eni representative Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 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 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date ■ 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) Iiiiiji* Eni E&P Division Well Name: 0P05-06 ENI Petroleum Daily Report Well Code: 23985 • Field Name: Nikatchuq n Co. Inc. Date:8/12/2010 - Report#: 3 API/UWI: 2 n II - Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Data Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 0.94 Daily Information Depth End(RKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POE Temperature(°F) Weather Wind 938.0 930.9 938.00 11.15 84.1 91.0 49.5 Partly Cloudy,Lt 163°SSE @ 6.8 Rain,WC 46.6° mph Daily summary operation 24h Summary CLEANOUT CONDUCTOR,DRILL&SLIDE TO 938'MD.MUD WT 8.8/VIS 97.LOAD PIPE SHED W/60 JOINTS OF13 3/8"CASING,DRIFT&STRAP. Operation at 07.00 DRILLING AHEAD @ 1164'MD at 0400 Hours 24h Forecast DRILL SURFACE HOLE TO CASING POINT OF 2,409' Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.00 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 20 P PREP RIG FLOOR&FINISH R/U OF CCB UNIT 01:30 02:30 1.00 2.50 DRILL E 3 P DRILL OUT CONDUCTOR TO 160'-450 GPM @ 400PSI,RPM 15 j 02:30 06:00 3.50 6.00 DRILL E '4 P POOH,P/U SCHLUMBERGER BHA/GYRO DATA TOOLS&M/U.ORIENT TOOL FACE PER DD. t 06:00 10:00 4.00 10.00 DRILL E '3 P DRILL SURFACE ROTATING&SLIDING F/160'TO 240'MD.GPM=500/PSI ON BTM=650/ PSI OFF BTM=570/ WOB=15K/RPM=40/TQ.ON BTM=1.5K/TO OFF BTM1.2K/DIFF PSI=80/MUD WT=8.8 PPG/VIS=97. OFFICIAL SPUD TIME 06:00HRS. 10:00 '10:30 0.50 10.50 DRILL E '4 U POOH INTO CONDUCTOR&REPAIR EPOCH RIGWATCH 10:30 11:30 1.00 11.50 DRILL E 4 P RIH DRILLING&SLIDING FROM 240'TO 342'MD.GPM=500/PSI ON BTM=680/PSI OFF BTM=600/WOB=20K /RPM=40/TQON BTM=1.5K/TQ OFF BTM=1.2K/DIFFPSI=80 MUDWT=8.9/VIS=97 11:30 12:30 1.00 12.50 DRILL E 4 P POOH P/U DRILL COLLAR&1 STD W/JARS HOOK LOAD 70K 12:30 00:00 11.50 24.00 DRILL E '3 P RIH DRILLING&SLIDING F/342'TO 938'MD,928'TVD/UP WT 92K/DN.WT.90K/ROT.WT.92K/40 RPM TO 2-3K/ 490 GPM @ 900PSI/WOB 18-20K/ROP 150'FPH/ECD 10.00PPG ART.63 AST 6.13 JAR HRS 59.4 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 Eni representative Sach Bowe ENI Drilling Spvr. 907-670.8623 907-299-0531 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 Last Casing seat Cas.Type OD(in) ID(in) Grads Top(RKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(MB) TVD(fIKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni ESP Division Well Name: OP05-06 ENI Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq •n CO. Inc. Date:8/13/2010 - Report#: 4 API/UWI: 2 n 11 Welibore name: OP05-06 page i of 1 Well Header PermitConcession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job information Welibore Job Phase Spud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ftihr) DFS(days) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 1.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 2,425.0 2,194.6 1,487.00 15.42 96.4 91.0 45.9 Cloudy,Lt Rain,WC 102°ESE @ 7.4 41.7° mph Daily summary operation 24h Summary Directional Drill(slide&rotate)f/938'-1/2021'\Check shot survey revealed 6.1°dogleg-rack back one stand&ream section to 5.56°dogleg-M/U stand\continue to Directional Drill f/2021'-t/2425' T/D surface hole. Operation at 07.00 Short trip,backream to 5"HWDP. 24h Forecast Pump sweep#1&CBU 4x until clean\Short trip back ream to 5"HWDP @ 691'-RIH to TD on elevators-Pump sweep#2 &CBU 4x until clean-Monitor well,POOH on elevators(SLM)-L/D BHA- Hanger run-R/U GBR for 13 3/8" Uthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.25 Time Log 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 Directional Slide/Rotary f/938'-1/1660'as per Schlumberger DD with pump rate of 600 gpm @ 1185 psi\40 RPM @ 2-3K torque\WOB 10-25K\Up wt.=105K-Dn wt.=95K-Rot wt.=91K.Started using Schlumberger MWD survey @ 984.33 survey depth.\Ream/wiping 90'before connection.\AST=7.26 hrs.\ART=1.45 hrs.ADT=8.71 hrs. 12:00 16:00 4.00 16.00 DRILL 'E 3 P Directional Slide/Rotary f/1660'-1/2021'as per Schlumberger DD with pump rate of 650 gpm @ 1358 psi\45 RPM @ 3-5K torque\WOB 15-22K\Up wt.=118K-Dn wt.=98K-Rot wt=106K.\9.4 MW-9.88 ECD. 16:00 17:30 1.50 17.50 DRILL 'E 6 U Check shot survey revealed 6.1°dogleg\rack back one stand OP\ream out to @ 5.56°dogleg\RIH one stand DP. 17:30 00:00 6.50 24.00 DRILL E 3 P Directional Slide/Rotary f/2021'-U 2425'(T/D)as per Schlumberger DD with pump rate of 657 gpm @ 1458 psi\40 RPM @ 5K torque\WOB 10-20K\Up wt.=128K-Dn wt.=100K-Rot wt=110K.AST=4.03 hrs.\ART=2.68 hrs.ADT=6.71 hrs. Total drilling=25.57 hrs. Total slide=20.56 hrs. Total rotary=5.01 hrs. Total Jar=77.6 hrs. 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 Eni representative David Smith ENI Drilling Spur. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @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 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) "' j Eni E&P Division Well Name: OP05-06 ENI Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq n • CO. Inc. Date:8/14/2010 - Report#: 5 APIIUWI: lC n II Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 2.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr)'POB Temperature(°F) Weather Wind 2,425.0 2,194.6 0.00 92.0 42.1 Cloudy,Rain,WC 93°E @ 14.7 mph 34.9° Daily summary operation 24h Summary Circulated&reciprocate pipe Pump sweep#1&CBU 2x\Ream&wash f/2375'-U 2425'-Continue circulating&reciprocate CBU 2x-POOH short trip Back ream f/2425'-V 683'. RIH to 2425'T/D on elevators\Circulate wash fill f/2420'-U 2425'-Pump sweep#2&CBU 4x\POOH on elevators\LID BHA\Dummy run hanger with Vetco Gray rep.\R/U GBR-PJSM&P/U 13318'-fitlM-taBC� csg. Operation at 07.00 R/U Schlumberger for Cementing 13 3/8"Casing 24h Forecast P/U 13 3/8"-68.0#-L-80 casing to 2415'\Circulate&condition for cement\R/U Schlumberger-mix&pump cement-R/D I Wash-up&N/D drill nipple-N/U BOPE I Test BOPE I Clean pits&Prep for new LSND mud.I P/U BHA. Uthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.60 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 7 P Circulate-pump sweep#1(40 bbls @ 10.9 ppg)&CBU 2x I reciprocate string while pumping @ 800 gpm with 1700 psi.\ 80 rpm @ 3-5K torque\Upwt=120K-Dn wt.=-95-Rot wt.=105K Started to taking wt.@ 2375'. 01:00 01:30 0.50 1.50 DRILL E 6 U Ream&wash f/2375'-U 2425'pumping 450 gpm @ 1350 psi.\50 rpm @ 3-4k torque I 5K weight 01:30 02:30 1.00 2.50 DRILL E 7 P Circulate&reciprocate pipe-CBU 2x until clean with 800 gpm @ 1680 psi.I 80 rpm @ 3K torque.I Up wt.=120K-Dn wt.=95K-Rot wt.=105K. ✓// 02:30 09:00 6.50 9.00 DRILL E 6 P POOH short trip-Back reaming f/2425'-U 683'with 800 gpm @ 1680 psi.1 80 rpm @ 3-4K torque I pull speed 10+fpm- Rot wt.=90K @ 683'I Torque f/2074-U 2025'(5-8K)I 1500'back down pumps to 600 gpm @ 1210 psi.I Max gas=1000 units.\SLM good. 09:00 10:00 1.00 10.00 DRILL E 4 P RIH on elevators f/683'-U 2420'I tag with 5'fill-break circulation 500 gpm @ 920 psi. 10:00 13:30 3.50 13.50 DRILL E 7 P Circulation&condition-wash f/2420'-U 2425'I Pump sweep#2(30bbls.@ 11.0 ppg)&CBU 4x-reciprocating pipe with 800 gpm @ 1860 psi.150 rpm @ 4K torque I Up wt.=120K-Dn wt.=95K-Rot wt.=105K.\Max gas=188 units.I Cycle pumps for Gyro Data tool info.\Flow check well-Static I pi mn slug, 13:30 15:30 2.00 15.50 DRILL E 4 P POOH on elevators f/2425'-V 122'to Schlumberger-No tight spots encountered. 15:30 18:00 2.50 18.00 DRILL E 4 P UD BHA tools as per Schlumberger Reps.. 18:00 19:30 1.50 19.50 DRILL G 1 P _Clean&clear floor-perform dummy run with 13 3/8"hanger as per Vetco Gray rep. 19:30 21:00 1.50 21.00 DRILL G 1 P R/U GBR 133/8"csg.equipment&Franks tool\Held PJSM for running surface csg. 21:00 00:00 3.00 24.00 DRILL G 4 P P/U 13 3/8"-68#-L-80 surface casing U 1670'1 Check float equipment I Centralizer as per procedure I Franks tool to fill pipe&top every 10 joints.I Up wt.140K-Dn wt.122K Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-6704623 907-841-8759 Eni representative David Smith ENI Drilling Spvr. 907-6704623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @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 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415L80 0.0 2,415.6 8/14/2010 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) Eni E&P Division Well Name: OP05-06 - Daily Report ENI Petroleum Y p Well Code: 23985 Prn• Field Name: Nikatchuq n CO. Inc. Date:8/15/2010 - Report#: 6 APIIUWI: 2 n 11 Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information 1 Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 3.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 2,425.0 2,194.6 0.00 85.0 42.6 PC,WC 37.9° 98°E@ 7.9 mph Daily summary operation 24h Summary P/U 13 3/8"-684-L-80 casing V 2415'\Circulate&condition mud\Schlumberger pumped Mud Push II 106 bbls#10.1.-Lead slurry 444 bbls.@ 10.7 ppg.-Tail slurry 75 bbls.@ 12.0 ppg\Rig displace with 348 bbls.&bump plug,check floats-holding\R/D&wash out stack-N/D flow riser&starting head,N/U well head&test to 5000 psi.continue N/U riser&BOP stack-inspect 4"x 7" variable ram&replace packer element&re-fabricate flow nipple. Operation at 07.00 Test BOPE 250/3500 psi witness by AOGCC John Crisp. 24h Forecast 1 Test BOPE\P/U BHA#3\RIH t/+/-2250'test 13 3/8"csg to 2500 psi\Drill out float equipment&25'+new hole\Displace to LSND mud\Performed LOT/FIT\Drill ahead 12 1/4"section as Schlumberger. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.60 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 ` 2.00 2.00 DRILL G 4 P P/U 13 3/8"-68#-L-80 surface casing f/1670'-U 2375'\Fill with Franks tool-break circulation @ 1796'with 230 gpm @ 7 230 psi.\P/U landing joint&hanger\Up wt.=190K-Dn wt.=145K. 02:00 04:00 2.00 4.00 DRILL G 7 P Circulate&condition mud for cement job as per mud engineer-stage pump rate to 251 gpm @ 310 psi.\Reciprocate casing 15'.\Up wt.=185K-Dn wt.=150K. 04:00 04:30 0.50 4.50 DRILL G 7 P L/D Franks tool&M/U cement head on land joint-R/U cement lines to Schlumberger. 04:30 05:00 0.50 5.00.DRILL G 7 P Break circulation through cement head-stage rate 330 gpm @ 410 psi.\Up wt.=190K-Dn wt.=150K. 05:00 09:00 4.00 9.00 DRILL H 7 P Schlumberger pump 3 bbls.H2O&test lines to 3000 psi.\Pump 106 bbls.of 10.1 ppg.Mud Push II @ 5.5 bpm w/425 psi.\Drop bottom plug\Schlumberger mix&pump 444 bbls.of 10.7 ppg.Lead slurry cement(2.33 Yield)1007 sks;@ 5.3 bpm;ICP @ 390 psi.-FCP @ 405 psi.-Mix H2O-10.37 gal/sk.\Mix&pump 75 bbls,12 ppg Tail Slurry(1.63 Yield) 258 sks @ 4.8 bpm.-ICP @ 480 psi.FCP @ 520 psi.-Mix H2O-5.043 gal/sk.\Drop top plug\Schlumberger pump 5 � 1 --- bbls.H2O for wash-up\Rig pump displace cement with 347 bbls.of 9.5 ppg mud @ 8 bpm,ICP 380 psi.-At 324 bbls. ./ away slow pump rate to 2 bpm,FCP @ 345 psi.-Bump plug on strokes to 500 psi over FCP.Hold 845 psi.for 3 minutes. and bleed off-one bbl back,floats holding.Cement in place @ 0830.2`5 bbls.cement back to surface.Up wt.190K-Dn wt.150K. 09:00 10:30 ' 1.50 10.50 DRILL H 1 P R/D cement lines&blow down\L/D cement head&landing joint.\R/D GBR casing elevators. P/U 5"elevators. 10:30 12:00 1.50 12.00.DRILL H 1 P MN Johnny Wacker wash tool on 5"drill pipe flush out riser-L/D same.\Clear floor of cement&casing equipment. 12:00 15:00 I 3.00 15.00 DRILL E 1 P Wash out&remove Katch-can&containment.-N/D flow riser&Vetco Gray starting head. 15:00 18:00 3.00 18.00 DRILL E 1 P Install Vetco Gray wellhead-Test Multi-bowl/hanger neck connection to 5000 psi for 10 minutes.-Install well head valves. -N/U riser&BQP stack.,„ 18:00 00:00 6.00 24.00 DRILL E 1 P Open&inspect upper 4 1/2"x 7"variable rams,packer element bad-remove&install new-Spot flow nipple-to tall, remove for fabrication work-install aluminum hatch cover on well house-install spill containment skirt around riser-load floor w/BHA items. 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 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @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 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(RKB) Run Date CASING 13 3/8, 12.415 L80 0.0 2,415.6 8/14/2010 Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type Fluid Density(Ib/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) ''" 3 Eni E&P Division Well Name: 0P05-06 ENI Petroleum Daily Report Well Code: 23985 • CO. Inc. Field Name: Nikatchuq Date:8/16/2010 - Report#: 7 API/UWI: III Wellbore name: OP05-06 page 1 of 1 Well Header _ Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 1 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(ftlbr) DFS(days) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 4.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 2,425.0 2,194.6 0.00 86.0 40.6 Partly Cloudy,WC 46°NE @ 15.4 mph 32.7° Daily summary operation 24h Summary N/U re-fabricate flow nipple&Katch-Can\Test BOPE to AOGCC requirements and witness by John Crisp\P/U BHA#3 as per Schlumberger DD/MWD,surface test tools\RIH to 2244',break circulation&test 13 3/8'csg to 2500 psi for 30 minutes.\RIH&tag @ 2320'-Drilling on plugs&float equipment. Operation at 07.00 Performing LOT 24h Forecast Drill out float equipment&25'new hole t/2450'\CBU-clean&displace with new LSND mud\Pull into 13 3/8"csg.&perform LOT/FIT\Perform PWD baseline\Drill ahead as per Schlumberger DD. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log crap Start End Dur Dm Time Time (hr.) (mss) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 1 P Install re-fabricated bell nipple-connect flow&fill-up lines-Katch-Can on bell nipple. 03:30 -04:00 0.50 4.00 DRILL E 12 P P/U test tools&install test plug-fill BOP stack with H20. 04:00 09:00 5.00 9.00 DRILL E 12 P Test BOPE equipment-Annular 250 psi.Low/2500 psi.High\Rams,manifolds,TD&floor valves 250 psi.Low/350 psi.High-all test chart record for 5+minutes each.Performed accumulate test.Test witness by John Crisp AOGCC.. ` 09:00 10:30 1.50 10.50 DRILL E 12 P R/D test equipment&pull test plug-Blow down equipment-line choke manifold for drilling operation. 10:30 _11:00 0.50 11.00 DRILL E 1 P Install wear bushing as per Vetco Gray rep.\ID 12.312" 11:00 14:30 3.50 14.50 DRILL E 4 P P/U BHA#3 Rotary Steerable assembly as per Schlumberger DD/MWD reps.-RIH w/HWDP V 651'. fl 14:30 15:30 1.00 15.50 DRILL E 4 P RIH f/651'-V 1040'\P/U ghost reamer\Up wt.=90k-Dn wt.=90K. 15:30 16:00 0.50 16.00 DRILL E 7 P Circulate to shallow test Schlumberger MWD tool,OK-800 gpm @ 1250 psi. 16:00 18:00 2.00 18.00 DRILL E 20 P PJSM-Performed stripping drill with crew:M/U TIW&Dart valve in string-close annular&pressure up 200 psi on back side-Strip in hole letting crew members take turns operating choke-good job maintaining casing pressure.POOH 3 stands V 1140'-UD TIW&dart valves. 18:00 _19:30 1.50 19.50 DRILL E 20 P Slip&Cut drilling line-63'.\Service rig. 19:30 20:30 1.00 20.50 DRILL E 4 P RIH f/1140'-t/2251'\Up wt.=120K-Dn wt.=90K. 20:30 22:00 1.50 22.00 DRILL E 12 P R/U to test 13 3/8"csg.-Break circulate&pump drill pipe volume-jest 13 3/8"csg./68#/L-80 to 2500 psi for 30 minutes-chart record. 22:00 22:30 0.50 22.50 DRILL E 4 P RIH f/2251'-t/2320'-Tao too of cem9n1 2320'12ith 8K.\Up wt.=120K-Dn wt.=90K. 22:30 00:00 1.50 24.00 DRILL E 3 P Rotary drill f/2320'-U 2323'on cement plugs as per Weatherford float drilling guidelines&procedures\550gpm©750 psi\60 rpm @ 3-5k torque\Up wt.=120K-Dr)wt.=90K 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 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @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 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,415.6 8/14/2010 Last Leakoff Test Depth(ftKB) TVD(fIKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 - iriiii Eni E&P Division Well Name: OP05-06 ENI Petroleum Daily Report Well Code: 23985 • Field Name: Nikatchuq n Co. Inc. Date:8/17/2010 - Report#: 8 APNUWI: c�n II Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 5.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftlhr) POB Temperature(°F) Weather Wind 4,388.0 2,809.1 1,963.00 11.68 168.1 87.0 50.4 Mostly Cloudy,WC 213°SSW @ 7.8 50.4° mph Daily summary operation 24h Summary Drill remaining float equipment-wash old hole U 2425'&25'new hole U 2450'with spud mud\Displace well bore with LSND mud\Perform LOT on 13 3/8"csg.to 11.0 ppg EMW\Perform ECD baseline parameters\Drill ahead to well procedure as per Schlumberger DD f/2425'-t/4410'. Operation at 07.00 Drill Rotary Steerable as per Schlumberger-transporting cuttings to BP G&I.Off line activity load pipe shed with 9 5/8"csg&prep to run. 24h Forecast Drill Rotary Steerable as per Schlumberger DD following well plan.Load 9 5/8"csg.in pipe shed&prep. Uthology Shows MAASP Pressure(psl) Mud Weight(Ib/gal) 9.00 Time Log Cum Start End Dur Our Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 3 P Rotary Drill float equipment&cement as per Weatherford guidelines-f/2323'-t/2415'-wash old hole 2415'-U2425'\ 560 gpm @ 760 psi.\60-70 rpm with 3-7K torque\WOB=2-8K\Up wt.=125K-Dn wt.=90K-Rot wt.=110K 02:00 02:30 0.50 2.50 DRILL E 3 P Drill Rotary Steerable f/2425'-U 2450'pumping 560 gpm @ 820 psi.\70 rpm @ 4-5K torque\WOB=4-6K\Up wt.= 125K-Dn wt.=90K-Rot wt.=110K. 02:30 03:00 0.50 3.00 DRILL E '7 -P Circulate bottoms-up&clean-Rotate&reciprocate pump rate 660 gpm @ 1080 psi.\70rpm @ 4-5k torque\Up wt.= 125K-Dn wt.=90K-Rot wt.=110K. 03:00 04:00 1.00 4.00 DRILL E 7' P Circulate/displace well-pump 20 bbls.Hi-vis spacer sweep followed with new 8.9 ppg LSND mud-pump rate 900 gpm CO 630 psi.\rotate&reciprocate string with 70 rpm @ 4K torque\Up wt.=110K-Dn wt.=100K-Rot wt.=105K. 04:00 '05:30 1.50 5.50 DRILL E 19 P `Perform LOT on 13 3/8"shoe to 11 ppg EMW-broke down @ 233 psi.with mud wt.8.9 ppg. 05:30 '06:00 0.50 6.00 DRILL E 7 P Circulated&establish base line ECD data. 06:00 -12:00 6.00 12.00 DRILL E 3 P Drill Rotary Steerable f/2450'-U 2921'as per Schlumberger DD with 650 gpm @ 800 psi.\90 rpm @ 3-4k torque\WOB =8-12k\Up wt.=120K-Dn wt.=95K-Rot wt.=105K.9.0 ppg mud wt.-ECD=9.40 ppg.ADT=4.20 hrs.\Jars=79.01 hrs. 12:00 '00:00 12.00 24.00 DRILL E 3 P Drill Rotary Steerable f/2921'-11 4388'as per Schlumberger DD with 900 gpm @ 1630 psi.\140 rpm @ 8-9k torque\ WOB=10-15k\Up wt.=120K-Dn wt.=85K-Rot wt.=102K.\9.0+ppg mud wt.\ECD=9.67 ppg.\ADT=7.29 hrs.\Jars =86.3 hrs. Total ADT=11.68 hrs. Total Jar=86.3 hrs. Daily Contacts Position Contact Name Company Title E-maN 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 Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @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 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,415.6 8/14/2010 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) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 arost Eni E&P Division Well Name: OP05-06 ENI Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq • n�n Co. Inc. Date:8/18/2010 - Report#: 9 API/UWI: lC ill II _ page i of 1 Wellbore name: OP05-06 Well Header PermlUConcession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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(fllhr) DFS(days) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 6.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 6,250.0 3,214.9 1,862.00 16.61 112.1 85.0 43.0 Partly Cloudy,WC 46°NE @ 7.1 mph 38.5° Daily summary operation 24h Summary Drilling Rotary Steerable f/4388'-1/6250'as per Schlumberger DD-Pumping weight sweep+/-800'\Back ream connection&wash down @ reduce pump rate with no rotary. Operation at 07.00 Drill ahead-transporting cuttings to BP G&I. 24h Forecast Drill ahead intermediate section to T/D-Pumping weighted sweep-Continue to transporting cutting to BP G&I Lithology Shows 'MAASP Pressure(psi) Mud Weight(1b/gal) I / 9.20 �/ Time Log 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/4388'-t/5346(TVD 3016')as per Schlumberger DD with 900 gpm @ 1980 psi.\130 rpm @ 7-8k torque\WOB=10-15k\Up wt.=135K-Dn wt.=85K-Rot wt.=105K.\9.2 ppg mud wt.\ECD=9.8 ppg.\Pumped 30 bbls. weight sweep(10.1 ppg)@ 4963'with 35%increase in cutting\ADT=7.53 hrs.\Jars=93.8 hrs. 12:00 00:00 12.00 24.00 DRILL E 3 P Drill Rotary Steerable f/5348-t/6250'(TVD 3214')as per Schlumberger with 900 gpm @ 2175 psi.\120 rpm @ 9-10k torque\WOB=10-15k\Up wt.=142K-Dn wt.=85K-Rot wt.=110K.\9.2 ppg mud wt.\ECD=9.79 ppg.\Pumped two weighted sweep-#1 @ 5380'-(40 bbls.@ 10.2 ppg)with no increase in cuttings-#2 @ 6120'-(35 bbls.@ 10.2 ppg) with 20%increase in cuttings.\ADT=9.08 hrs.\Jars=102.9 hrs. Total ADT=28.29 hrs. Total Jar=102.9 hrs. 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 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @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 Project Advisor 907-865-3337 907-952-7880 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(fIKB) Bottom(t1KB) Run Date CASING 13 3/8 12.415 L80 0.0 2,415.6 8/14/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(poi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 Vol Eni E&P Division Well Name: OP05-06 ENI Petroleum Daily Report Well Code: 23985 • CO. Inc. Field Name: Nikatchuq 2 ^ Date:8/19/2010 - Report#: 10 API/UWI: (nl ii page 1 of 1 Wellbore name: OP05-06 Well Header Permlt/Concesslon N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 7.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 6,878.0 3,430.6 628.00 8.71 72.1 83.0 39.0 Mostly Clear,WC 327°NNW @ 7.5 33.8° mph Daily summary operation 24h Summary Drilling Rotary Steerable f/6250'-116878'per Schlumberger DD\SLB Xceed tool trouble not responding to directional down link commands-Pumping 35 bbl weight sweep&circulate bottoms-up 2x\ POOH f/6878'-V 4000'-over pull started @ 4760'and continue to increase\RIH 11 4192'CBU 1 1/2x-\POOH f/4192-V 3336'which steadily increased\back ream out f/3336'-V 2415'(13 3/8' shoe). Operation at 07.00 Working BHA#3 and P/U BHA#4 24h Forecast Work BHA-change out Schlumberger Xceed tool&bit-P/U new tools&RIH U 6878'\Drill ahead to T/D Llthoiogy Shows MAASP Pressure(psi) Mud Weight(1b/gal) 9.05 Time Log 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 2 P Drill Rotary Steerable f/6250'-1/6830'(TVD 3368')as per Schlumberger DD with 700 gpm @ 1440 psi.\80 rpm @ 8-9k torque\WOB=15-20k\Up wt.=150K-Dn wt.=85K-Rot wt.=110K.\9.0 ppg mud wt.\ECD=9.49 ppg.\Hole started taking fluid @ 6717'-total 45 bbls in 3 hrs.-add Saf-Carb @ 2 lbs./bbl.(Total in system 3 Ibs./bbls.)\ADT=8.43 hrs.\ Jars=111.33 hrs. 12:00 13:30 1.50 13.50 DRILL E 3 U Drill Rotary Steerable f/6830'-1/6878'(TVD 3380')survey every+/-30'as per Schlumberger DD due to trouble with Xceed tool not respond to directional turn in well plan-pumping 700 gpm @ 1475 psi.\80 rpm @ 7-8K torque\WOB= 2-5k\Up wt.=148K-Dn wt.=88K-Rot wt.=110K.\9.0+ppg mud wt.\ECD=9.47 ppg.\ADT=0.28 hrs.\Jars=0.28 hrs. Total ADT=37.0 hrs. Total Jar=111.61 hrs. 13:30 16:30 3.00 16.50 DRILL E 7 U 'Circulating-working on top drive link-tilt function\Decision to POOH from town was made due to Xceed not being able to turn.\Pump 35 bbls.weight sweep CBU 3x-Reciprocate pipe-back ream up&wash down with no rotary\pump rate 900 gpm @ 2200 psi.\120 rpm @ 8K torque\Up wt.=155K-Dn wt.=85K-Rot wt.=110K.\Monitor well-static. 16:30 20:00 3.50 20.00 DRILL E 4 U POOH f/6878'-V 4000'\Tight f/4760'-4000'with 15-30K over pull&working through areas-free going down.\RIH back to 4192'to break circulate. 20:00 21:00 1.00 21.00 DRILL E 7 P 'Circulate CBU 1 1/2x until cleaned-up,lots of finds with 20%increase in cuttings\Reciprocate pipe-back ream up& wash down with no rotary pumping 500 gpm @ 640 psi\50 rpm @ 5K torque\Up wt=125K-Dn wt.=85K-Rot wt.= 100K.\Check shot Schlumberger tools-good. 21:00 00:00 3.00 24.00 DRILL E 4 U Continue to POOH on elevators f/4192'-V 3336'-Pulled three stands&drag steadily increased @ 3910'15-25K over pull\back ream 3336'to shoe(2415')@10+fpm\pump rate 500 gpm @ 650 psi\55 rpm @ 5-6K torque. 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 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @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 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,415.6 8/14/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psl) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 1r 11* Eni E&P Division Well Name: 0P0506 ENI Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq • Co. Inc. Date:8/20/2010 - Report#: 11 APIIUWI: ?n II page l of l Wellbore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 1220 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 8.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 6,944.0 3,450.9 66.00 1.14 57.9 82.0 39.6 Cloudy,WC 33.1° 63°ENE @ 10.1 mph Daily summary operation 24h Summary POOH f/2415'-V 652'HWDP\Work BHA#3-L/D all stabilizers out of gauge-L/D Power Drive,Arc 825,Xceed 900&bit.\Clean floor&service rig-load floor with BHA components\P/U BHA#4\ RIH shallow test @ 650'\Continue RIH V 6876'-Tag bridges @ 3400'&5200'\Circulate&condition mud\Drill rotary steerable f/6878-V 6894'\Circulating-Schlumberger Xceed 900&Power Pulse MWD tool troubles,(Non-productive time)\Drill f/6894'-t/6944' Operation at 07.00 POOH to change BHA for motor assembly to side track well. 24h Forecast POOH to UD BHA#4 I P/U motor assembly to side track @+/-6250'and get back on planned well procedure. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.10 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act Plan Oper.Desar. 00:00 01:00 1.00 1.00 DRILL E 7 U Circulate bottoms-up 2x with 700 gpm @ 1100 psi.\40 rpm @ 3K torque\Up wt.=110K-Dn wt.=100K-Rot wt.=105K- monitor well-static. 01:00 02:00 1.00 2.00 DRILL E 4 U POOH f/2415'-V 957'BHA(HWDP)-L/D ghost reamer 1/8"out of gauge(damage to bottom of blades). 02:00 05:30 3.50 5.50 DRILL E 4 U Work BHA 3#as per Schlumberger-Top NM stab 7/8"out,Bottom NM Stab=7/8"out,Stab's on Xceed 900 in gauge with wear on leading edges of blades\(UD last 90'of BHA)-Power Pulse MWD,ARC 825,Xceed,stab&bit. 05:30 06:30 1.00 6.50 DRILL E 1 U Clean&clear floor of BHA components-Down load data from tool string&program tools to be P/U.\Load rig floor with new stab&bit. 06:30 07:00 0.50 7.00 DRILL E 25 P Service Rig-Top drive,crown and draw-works. 07:00 10:00 3.00 10.00 DRILL E 4 U P/U BHA#4 as per Schlumberger-New Hycalog 12"bit,Xceed 900&Arc 825 tools-with Power Pulse MWD\RIH wit DC,Jars,&HWDP V 650'\MWD swallow hole test-pumping 575 gpm @ 610 psi. 10:00 11:30 1.50 11.50 DRILL E 4 U RIH f/650'-V 237T-screen down due to returns running over\Up wt.=110K-Dn wL=100K. _ 11:30 13:30 2.00 13.50 DRILL E 7 U Circulate&condition mud,surface to surface pumping 315 gpm @ 270 psi.-CBU 2 x 13:30 17:00 3.50 17.00 DRILL E 4 U 'RIH f/2377'-V 6876'\Tag brides @ 3400'&5200'1 Up wt.=152K-Dn wt.=88K 17:00 20:00 3.00 20.00 DRILL E 7 U Circulate&condition mud-could not circulate @ drilling due to losing fluid over shakers. 20:00 '21:00 1.00 21.00 DRILL E 3 P Drill Rotary Steerable f/6878'-U 6894'as per Schlumberger DD-(survey every 30')pumping 750 gpm @ 1750 psi.1 100 rpm @ 10K torque\WOB=2-5k\Up wt.=152K-Dn wt.=88K-Rot wt.=112K.19.1+ppg mud wt.\ECD=9.65 ppg.\ ADT=.29 hrs.\Jars=111.9 hrs. 21:00 23:00 2.00 23.00 DRILL E 7 U Circulated&Schlumberger check shot-down linking to Power Pulse&Xceed 900 not getting the same data on directional orientation-Schlumberger consult with town to find a solution-fixed. 23:00 00:00 1.00 24.00 DRILL E 3 P Drill Rotary Steerable f/6894'-V 6944'(TVD 3380')as per Schlumberger DD-(survey every 30')pumping 750 gpm @ 1 1760 psi.\80 rpm @ 10K torque\WOB=2-15k\Up wt.=152K-Dn wt.=88K-Rot wt.=112K.\9.1 ppg mud wt.\ECD= 9.65 ppg.\ADT=.85 hrs.\Jars=112.75 hrs. Total ADT=1.14 hrs. Total Jar=112.75 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 Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @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 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 2,415.6 8/14/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P(Surf)(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 1P11141 Eni ESP Division Well Name: OP05-06 ENI Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq en IS Co. Inc. Date:8/21/2010 - Report#: 12 APIIUWI: page 1 of 1 Welibore name: OP05-06 Well Header Permit/Concession N° Operator 'ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 9.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftlhr) POB Temperature(°F) Weather Wind 7,036.0 3,476.2 92.00 1.86 49.5 85.0 39.7 Cloudy,WC 33.6° 15°NNE @ 10.8 mph Daily summary operation 24h Summary Drill f/6944'-U 7036'\Pump weight sweep&CBU 2x\POOH f/7036'-U 656'HWDP\Work BHA#4-UD Power Pulse,Arc 825,Xceed 900&PDC bit.\Service rig\Prep floor with BHA components\ P/U BHA#5-RIH P/U ghost reamer and shallow test same\RIH U 2400'\Circulate bottoms-up-stage up to drilling rate\RIH f/2400'-U 4387'-Schlumberger check shot survey @ 2755',3516', 4380'. Operation at 07.00 Side tracking well with mud motor @ 6207' 24h Forecast Side track well @ 6207'with r'\-35'trough with tool face 160L\Time drill to depart from well bore&conitnue to drill ahead to original well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.00 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL E 3 P Drill Rotary Steerable f/6944'-U 7036'(TVD 3424')as per Schlumberger DD-(survey every 30')pumping 760 gpm @ 1770 psi.\120 rpm @ 10-11K torque\WOB=10-22K\Up wt.=155K-Dn wt.=80K-Rot wt.=115K.\9.2 ppg mud wt.\ ECD=9.61 ppg.\ADT=1.83 hrs.\Jars=115.3 hrs. Total ADT=3.00 hrs. Total Jar=115.3 hrs 02:30 05:30 3.00 5.50 DRILL E 7 U Circulate-pump 40 bbls weighted sweep(10.2 ppg)&2x with 835 gpm @ 2010 psi.\120 rpm @ 9-10K torque\Up wt.= 152K-Dn wt.=80K-Rot wt.=115K-monitor well-static. 05:30 11:00 5.50 11.00 DRILL E 4 U POOH f/7036'-U 656'-Pump slug @ 6110'-had 30K over pull @ 5380'-work through same. �,,/ 11:00 14:00 3.00 14.00 DRILL E 4 U LID BHA#4 as per Schlumberger-8"Power Pulse MWD,IBS stab,ARC 825,Xceed 900&PDC bit. 14:00 15:00 1.00 15.00 DRILL E 25 P Service rig-Clean&clear floor. 15:00 20:00 5.00 20.00 DRILL E 4 U P/U BHA#5 Side track assembly as per Schlumberger-Hughes MX-1 L 12"bit,PDM 1.5 bend mud motor,Arc 825, Power Pulse MWD&Stab.\Continue RIH from derrick with DC,Jars,&HWDP U 650' 20:00 21:30 1.50 21.50 DRILL E 4 U RIH f/650'-U 2400'\P/U ghost reamer\Swallow test MWD tools-pumping 575 gpm @ 610 psi.\Up wt.=112K-Dn wt=98K. 21:30 22:00 0.50 22.00 DRILL E 7 U Circulate bottoms-up @ shoe-stage pumps f/315 gpm @ 270 psi.-U 815 gpm @ 1620 psi 22:00 00:00 2.00 24.00 DRILL E 4 U RIH f/2400'-U 4387'\Schlumberger required survey check shot @ 2755',3516'4380'-pumping 760 gpm @ 1450 psi.\ Up wt.=120K-Dn wt.=70K. 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 Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @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 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,415.6 8/14/2010 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(ib/gal) Leak Off Pressure(psi) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 Eni E&P Division los W Name: OP05-06 ENI Petroleum Daily Report ell Well Code: 23985 Field Name: Nikalchuq • n n Co. Inc. Date:8/22/2010 - Report#: 13 API/UWI: 211 II I) Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 10.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftlhr) POB Temperature(°F) Weather Wind 6,143.0 3,192.9 -893.00 85.0 40.1 Cloudy,AM Fog,WC 32°NNE @ 91.mph 34.2° Daily summary operation 24h Summary RIH f/4387'-1/6143'\Break circulation&orientate mud motor(160L tool face)@ 6207'-trough f/6207'-V 6239'\Time drill f/6239'-U 6258'\Drill rotary/slide f/6258'-6840'back to the original well bore. Operation at 07.00 Drill rotary/slide as per Schlumberger to well plan. 24h Forecast Fix electrical problems on rig(brown out on rig floor)\Continue to drill Rotary/Slide per Schlumberger to original well plan. Uthology Shows MAASP Pressure(pal) Mud Weight(lb/gal) 9.05 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 3 U RIH f/4387'-V 6143'-Tag @ 5560'orientate,pass through\Up wt.=140K-Dn wt.=85K 01:30 03:30 2.00 3.50 DRILL E 2 U Slide/trough hole @ 130L-160L(side track)f/6207'-U 6239'(TVD 3211')-per Schlumberger-pumping 800 gpm @ 2070 psi.-reduce to 666 gpm @ 1465 psi.\WOB=4-6K\Up wL=145K-Dn wt.=85K\9.1 ppg mud wt.\ECD=9.54 PP9. 03:30 10:30 7.00 10.50 DRILL E 3 U Time drill f/6239-V 6258'-Tool face @ 160L per Schlumberger DD-(f/6239'-U6245'@ 1"/3 mins.)-(f/6248'-06253 @ 2"/3 mins.)-(f/6253'-t/6258'@ 6'/3 mins.)/Continue to slide f/6258'-V 6303'\pumping 716 gpm @ 1600 psi.\WOB= t-' 10-12K\9.1 ppg mud wt.\ECD=9.52 ppg. / 10:30 12:00 1.50 12.00 DRILL 'E 3 U Drill Rotary f/6303'-U 6368'(TVD 3251')per Schlumberger DD\620 gpm @ 1380 psi.\50 rpm @ 7-8K torque\WOB= 7 18K\Up wt.=145K-Dn wt.=80K-Rot wt.=110K.\9.1 ppg mud wt.\ECD=9.58 ppg.\ART=1.85 hrs.\AST=7.5 hrs.\ Jars=124.65 hrs. 12:00 00:00 12.00' 24.00 DRILL E 3 U Drill Rotary/Slide f/6368'-U 6840'(TVD 3395')per Schlumberger DD\700 gpm @ 1690 psi.\40 rpm @ 8-9K torque\ WOB=10-25K\Up wt.=162K-Dn wt.=80K-Rot wt.=115K.\9.1 ppg mud wt.\ECD=9.45 ppg.\ART=2.2 hrs.\AST= 4.1 hrs.\Jars=130.95 hrs. Total ADT=15.65 hrs. Total AST=11.6 hrs. Total ART=4.05 hrs. Total Jar=130.95 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 Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @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 Last Casing seat Cas.Type OD(In) ID(in) Grads Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 2,415.6 8/14/2010 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) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 Eni S&P Division Well Name: OP05-06 ENI Petroleum Daily Report Weil Code: 23985 Field Name: Nikatchuq • �wok Co. Inc, Date:8/23/2010 - Report#: 14 API/UWI: 21III I n I page l of i Wellbore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 11.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 7,612.0 3,623.8 772.00 6.40 120.6 85.0 39.7 Partly Cloudy,AM 27°NNE @ 5.8 mph Fog,WC 35.6° Daily summary operation 24h Summary Drill Rotary/Slide 1/6840'-U 6852'\Lost power to electronic components&monitors on rig floor-Nabors UPS problems\Drill Rotary/Slide f/6852'-U 7164'\Pump weight sweep&circulated around\ Drill Rotate/Slide f/7164'-U 7260'\Short trip/back ream f/7260'-1/5820'\RIH V 7260'with no problems\Drill Rotary/Slide f/7260'-U 7550'\Service rig Top drive\Rotary/Slide f/7550'-1/7612' Operation at 07.00 Drill ahead Rotary/Slide to well plan. 24h Forecast Drill with mud motor assembly to T/D of 9 5/8°rsg. Uthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 3 U Drill Rotary/Slide f/6840'-t/6852'per Schlumberger DD\700 gpm @ 1690 psi.\40 rpm @ 8-9K torque\WOB=18-20K \Up wt.=160K-Dn wt.=80K-Rot wt.=115K\9.0 ppg mud wt.\ECD=9.45 ppg.\AST=0.38 hrs.\Jars=131.33 hrs. 00:30 01:30 1.00 1.50 DRILL E 25 U Down time due to loss of power to electronic components&monitors for drilling package on rig floor,Nabors UPS problems,by-pass sytem. / 01:30 06:30 5.00 6.50 DRILL E 3 P Drill Rotary/Slide f/6852'-t/7164'per Schlumberger DD\700 gpm @ 1740 psi.\50 rpm @ 8-9K torque\WOB=20K\ ✓ Up wt.=165K-Dn wt.=85K-Rot wt.=115K\9.0 ppg mud wt.\ECD=9.67 ppg.\ART=0.63 hrs.\AST=1.54 hrs.\Jars= 133.5 hrs. 06:30 07:30 1.00 7.50 DRILL E 7 P Circulate-pump weight sweep 20 bbls.(10.0 ppg)-700 gpm©1640 psi.\50 rpm @ 8K torque\no increase in cutting. 07:30 10:30 3.00 10.50 DRILL E 3 P Drill Rotary/Slide f/7164'-V 7260'(TVD 3535')per Schlumberger DD\700 gpm @ 1720 psi.\50 rpm @ 10-11K torque\ WOB=18-22K\Up wt.=165K-Dn wt.=85K-Rot wt.=115K\9.1 ppg mud wt.\ECD=9.74 ppg.\ART=0.15 hrs.\AST= 0.57 hrs.\Jars=134.22 hrs. 10:30 15:30 5.00 15.50 DRILL E 4 P Short trip-badr ream f/7260'-t/5820'pumping 900 gpm @ 2400 psi.\80 rpm @ 8-9K Torque\Up wt.=170K-Dn wt.= 102K-Rot wt.=110K. 15:30 17:00 1.50 17.00 DRILL E 4 P RIH f/5820'-V 7260-Schlumberger check shots©6200'&6400'\Up wt.=158K-Dn wt.=70K. 17:00 22:30 5.50 22.50 DRILL E 3 P Drill Rotary/Slide f/7260'-V 7550'per Schlumberger DD\800 gpm @ 2250 psi.\40 rpm©9-9.4K torque\WOB=25K\ Up wt.=168K-Dn wt.=80K-Rot wt.=112K\9.1 ppg mud wit ECD=9.84 ppg. 22:30 23:00 0.50 23.00 DRILL E 25 P Service rig-Top Drive. 23:00 00:00 1.00 24.00 DRILL E 3 P Drill Rotary/Slide f/7550'-V 7612'(TVD 3604')per Schlumberger DD\800 gpm©2250 psi.\40 rpm @ 9-9.4K torque\ WOB=25K\Up wt.=168K-Dn wt.=80K-Rot wt.=112K.\9.1 ppg mud wt.\ECD=9.84 ppg.\ART=0.72 hrs.\AST= 2.41 hrs.\Jam=137.35 hrs. Total ADT=22.05 hrs. Total AST=4.90 hrs. Total ART=1.50 hrs. Total Jar=137.35 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 Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @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 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,415.6 8/14/2010 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) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 itooks Eni E&P Division Well Name: OP05-06 ENI Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq • Co. Inc. Date:8/24/2010 - Report#: 15 APUUWI: 2 n 11 - page 1 of 1 Wellbore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Data Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) 0P05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 12.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 8,408.0 3,801.9 796.00 8.09 98.4 85.0 38.8 Cloudy,Rain,Fog, 51°NE @ 5.3 mph WC 35.1° Daily summary operation 24h Summary Drill Rotary/Slide f/7612'-V 8217'\Short trip/back ream f/8217'-t/7260'\RIH V 8217'with no problems\Pump weight sweep&circulated around\ Drill Rotate/Slide f/8217'-V 8408'\Rig down time due to Top Drive rails(two sheared bolts) Operation at 07.00 Drill ahead rotary/slide as per Schlumberger DD&Geologist to T/D Intermediate Section. 24h Forecast Finish repairs to Top drive rails\T/D well as per Geologist+/-8630'\3x CBU with weight sweep\Back ream to shoe @ 2415'\CBU\RIH to T/D\Pump weighted sweep&CBU 3x\POOH&L/D BHA #5\Prep&run 9 5/&csg. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 11:30 11.50 11.50 DRILL E 2 'P Drill Rotary/Slide f/7612'-1/8217'(TVD 3762)per Schlumberger DD\800 gpm @ 2270 psi.\50 rpm @ 9-11K torque\ WOB=18-22K\Up wt.=170K-Dn wt.=80K-Rot wt.=115K\9.1 ppg mud wt.\ECD=9.99 ppg.\ART=2.99 hrs.\AST= 2.68 hrs.\Jars=142.97 hrs. 11:30 '16:00 ' 4.50 16.00 DRILL E 4 P Short trip-back ream f/8217'-V 7260'pumping 900 gpm @ 2590 psi.\60 rpm @ 10-11K Torque\Up wt.=180K-Dn wt.=75K-Rot wt.=115K. 16:00 '17:00 1.00 17.00 DRILL E 4 P RIH f/7260'-V 8217'\Pump weight sweep washing last stand\Up wt.=180K-Dn wt.=75K. 17:00 21:00 -4.00 21.00•DRILL E 3 P Drill Rotary/Slide f/8217'-V 8408'(TVD 3802')per Schlumberger DD\800 gpm @ 2350 psi.\40 rpm @ 10-11 torque\ WOB=25K\Up wt.=180K-Dn wt.=80K-Rot wt.=112K.\9.1+ppg mud wt.\ECD=9.84 ppg.‘ART=1.75 hrs.\AST= 0.67 hrs.\Jars=145.4 hrs. Total ADT=30.14 hrs. Total AST=19.85 hrs. Total ART=10.29 hrs. Total Jar=145.4 hrs 21:00 00:00 3.00 24.00.DRILL E 25 U Rig down time due to two sheared bolts on Top drive rails-replace with new rail&bolts,torque to spec.and safety wired same. 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 Drilling Spar. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @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 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(NCB) Run Dab CASING 13 3/8 12.4151L80 0.0 2,415.6 8/14/2010 Last Leakoff Test Depth(ftKB) TVD(11KB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 j� Well Name: OP05-06 111R� Eni E&P Division ENI Petroleum Daily Report Well Code: 23985 • Field Name: Nikatchuq � Co. InC. Date:8/25/2010 - Report#: 16 API/UWI: 21III page 1 of 1 Wellbore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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(fflhr) DFS(days) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 13.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftlhr) POB Temperature(°F) Weather Wind 8,686.0 3,833.0 278.00 2.22 125.2 86.0 38.5 Low Clouds,Fog, 77°ENE Variable @ WC 32° 10.5 mph Daily summary operation 24h Summary Finished repairs on Top Drive rail-Check remaining bolts on guide rails-torque to spec.\Drill Rotary/Slide f/8408'-If 8686'T/D intermediate section for 9 5/8'cso.\Circulate 32 bbl.weight sweep& CBU 3x-monitor well.\Back ream f/8686'-t/5345'. Operation at 07.00 POOH back reaming. 24h Forecast POOH-back ream t/2037'\CBU 2x\Cut drilling line\RIH to T/D @ 8686'\Circulate weighted sweep&CBU 2x\POOH on elevators&L/D BHA#5\P/U BHA#6 hole opener\RIH to 8686'T/D\ Pump weighted sweep&CBU 3x. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.35 Time Log Cum Start End Dur Dur Time Time (hrs) (hill) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 25 U Rig down time:Finished repair of guide rail for top drive-check torque on remaining guide rail bolts to spec&safety wire. 01:30 06:00 4.50 6.00 DRILL E 3 P Drill Rntary/Slid•f/8408'-t/8686'(TVn 4R4q'1 oar Schliimhcrnar nn\800 npm @ 2300 psi.\50 rpm @ 12-13K torque\ WOB=20K\Up wt.=175K-Dn wt.=85K-Rot wt.=115K\9.2 ppg mud wt.\ECD=9.87 ppg.\ART=0.53 hrs.\AST= 1.69 hrs.\Jars=147.7 hrs. Total ADT=32.36 hrs. f� Total AST=21.54 hrs. Total ART=10.82 hrs. Total Jar=147.7 hrs. 06:00 10:00 4.00 10.00 DRILL E 7 P Circulate&reciprocate/rotate pipe-Pump 32 bbl.weight sweep(10.0 ppg)&CBU 3x-900 gpm-2780 psi.\80 rpm @ 13-14K torque\Up wt.=175K-Dn wt.=85K-Rot wt.=115K.\MW 9.1+\ECD 9.76 ppg\Monitor well 10 minutes. 10:00 21:00 11.00 21.00-DRILL E 4 P Back ream f/8686'-U 6200'-pumping 900 gpm @ 2500 psi.\60 rpm @ 12.5K Torque\Up wt.=170K-Dn wt.=80K- Rot wt.=110K. 21:00 00:00 3.00 24.00 DRILL E 4 P Back ream f/6200'-t/5345'pumping 900 gpm @ 2300 psi.\80 rpm @ 8K Torque\Up wt.=140K-Dn wt.=80K-Rot wt.=100K. Daily Contacts Position _ Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Sr.Drilling Spa. Jack.Keener @ enipetroleum.com -907-670-8623 907-715-6434 Eni representative David Smith ENI Drilling Spvr. 907.670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907.685-1227 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 Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,415.6 8/14/2010 Last Leakoff Test Depth(ftKB) ND(MB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 Pm Eni E&P Division Well Name: OP05-06 Daily Report Well Code: 23985 ENI Petroleum Field Name: Nikatchuq � • Co. Inc. Date:8/26/2010 - Report#: 17 API/UWI: 211 11 page 1 of i Wellbore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) {RKB-Base Flange(ft) RKB•Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 14.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftlhr) POB Temperature(°F) Weather Wind 8,686.0 3,833.0 0.00 86.0 41.4 Low Clouds,Fog. 42°NE @ 8.3 mph WC 32.5° Daily summary operation 24h Summary Back ream f/5345'-V 1995'\Circulate&reciprocate/rotate-CBU 2x\Cut drilling line\Change out saver/valve sub(first failed pressure testing)\RIH U 8686'(No fill)\Circulate&reciprocate/rotate- pump weighted sweep&CBU 3x. Operation at 07.00 POOH with BHA#5 24h Forecast Circulate&condition mud-CBU 3x,until clean\POOH on elevators&LID BHA#5(Schlumberger tools)\Make a hole opener wiper trip or run 9 5/8'csg. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gai) 9.20 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 08:30 8.50 8.50 DRILL E 6 P Back ream f/5345'-t/3017'pumping 900 gpm @ 1840 psi.\80 rpm @ 5-6K Torque\Up wt.=140K-Dn wt.=90K-Rot wt.=100K. 08:30 10:00 1.50 10.00 DRILL E 6 P -Back ream f/3017'-t/2415'pumping 900 gpm @ 1740 psi.\60 rpm @ 3-5K Torque\Up wt.=105K-Dn wt.=95K-Rot wt.=100K. 10:00 11:30 1.50' 11.50 DRILL E 6 P Back ream f/2415'-t/1995'pumping 900 gpm @ 1690 psi.\40 rpm @ 1-3K Torque\Up wt.=105K-Dn wt.=95K-Rot wt.=100K. 11:30 13:00 1.50 13.00 DRILL E 7 P Circulate&reciprocate/rotate pipe-900 gpm-1700 psi.\40 rpm @ 1-3K torque\Up wt.=105K-Dn wt.=95K-Rot wt.= 100K.\MW 9.1+\ECD 9.59 ppg\Monitor well 10 minutes. 13:00 15:00 2.00' 15.00 DRILL E 25 :P 'Cut drilling&inspect draw-works. 15:00 17:00 2.00 17.00 DRILL E 25 U Service Rig:Change saverNalve sub;first did not test-change out again to spare saver/valve sub&tested good.\ Service crown. 17:00 22:00 5.00 22.00 DRILL E 4 P RIH f/1995'-U 8686'(SLM)-break circulation every 2000'\record data:slack off every 5 stands&pick-up every 10 stands\No fill on bottom-tag with 10K-No Fill\Up wt.=170K-Dn wt.=80K-Rot wt.=118K. 22:00 00:00 2.00 24.00 DRILL E 7 P Circulate&reciprocate/rotate pipe-875 gpm-2375 psi.\60 rpm @ 11K torque\Up wt.=170K-Dn wt.=80K-Rot wt.= 118K.\MW 9.2/ECD 9.76ppg. 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 Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 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 Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,415.6 8/14/2010 LastLeakoff Test Depth(ftKB) TVD(fIKB) Fluid Type Fluid Density(Iblgal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 Eni E&P Division Well Name: 0P05-06 ENI Petroleum Daily Report Well Code: 23985 If*• Field Name: Nikatchuq n Co. Inc. Date:8/27/2010 - Report#: 18 API/UWI: 2 n 11 _ Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 15.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftlhr) POB Temperature('F) Weather Wind 8,686.0 3,833.0 0.00 87.0 37.8 Low Clouds.Fog. 95°E @ 12 mph WC 30° Daily summary operation 24h Summary Circulate&condition hole.CBU 3X.POOH L/D BHA#5.Change rams to 9 5/8"&test to 250/3,500 PSI&record.Hold PJSM&rig up for casing run.Run in hole W/9 5/8"casing. Operation at 07.00 / RIH W/9 5/8"casing.Filling pipe every JT&topping off every 10.Break circulation @ 2,410" I✓ 24h Forecast Complete casing run&rig D/N GBR casing tools&rig up&prep for cementing Llthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 7 P Circulate&condition hole,CBU 3X,reciprocate/rotate pipe-900 GPM-2,360 PSI 60 RPM @ 11 KTO.UP WT.170K- DN WT.80K-ROT WT.120-SPR 1&2 SPM=35/40 -PSI=230/270 MD=8,686'TVD=3,839 MW.=9.2 Monitor well for 10 min. 03:00 15:00 12.00 15.00 DRILL E 4 P POOH F/8,686'T/656' LD Ghost reamer,wear on top side of reamer blades.Lay DN remaining BHA components& remove all 12 1/4"equipment from rig floor. � 5 15:00 20:00 5.00 20.00 DRILL E 12 P Hold JSA for changing rams.Change out top set of rams for 9 5/8"&funtion test same.pull wear ring&set test plug,test rap,,,,o)snn coo per gr.chart recorder.UD test JT&P/U landing JT for dummy run,mark&L/D landing JT.Hold PJSM for casing run. 4,-- 20:00 00:00 4.00 24.00 DRILL G 4 P RIH W/9 5/8"casino to 1 R71'AO centrilizers per well plan.Fill every JT&top off every 10.Record UP WT=110K-DN WT=100K 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 Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 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) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2,415.6 8/14/2010 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) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 Eni E&P Division Well Name: 0P05-06 Yr An ENI Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq e CO. Inc. Date:8/28/2010 - Report#: 19 API/UWI: en n II page 1 of 1 Welibore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 __ 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA _ _ NABORS 245 E LAND RIG Job Information Welibore Job Phase Spud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 16.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(Mr) POB Temperature(°F) Weather Wind 8,686.0 3,833.0 0.00 87.0 38.5 Clear.WC 37.9° 28°NNE @ 2.1 mph Daily summary operation 24h Summary Circulating and conditioning hole CBU.P/U 9 5/8"casing and run in hole following ENI fill procedure.SLB pumped Mudpush II 75 bbls @ 10.5 ppg.followed by 157 bbls of DeepCrete @ 12.5 ppg.Rig displaced with 629 bbls OBM @ 8.9 ppg.Rig down cement head&casing elevators. Operation at 07.00 Laying down D/P&cleaning mud tanks. 24h Forecast Set pack off&test.Freeze protect with Little Red.Install wear ring&LID drill pipe&pick up replacement pipe.Clean all pits and shakers. Uthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.10 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act Plan Oper.Descr. 00:00 01:30 1.50 1.50.DRILL G 4 P RIH W/9 5/8"Casing 47#L-80.F/1,871 1/2,410' MU/TO 9,5000P WT 145K DN WT 110K.Fill every JT.&top off every 10. 01:30 02:00 0.50 2.00 DRILL G 7 P Circulate&condition hole.Reciprocate pipe CBU @ 6 BPM 450 PSI 02:00 04:30 2.50 4.50 DRILL G 4 P Continue to RIH W/9 5/8"Casing to 4,300'.UP WT180K DN WT 115K Follow same hole fill procedures. 04:30 05:00 0.50 5.00 DRILL G 7 P Circulate&condition hole.Reciprocate pipe CBU @ 6 BPM 450 PSI 05:00 08:30 3.50 8.50 DRILL G 4 P RIH W/9 5/8"Casing T/6,420' UP WT 235K DN WT 115K Continue to follow hole fill prcedures. 08:30 09:00 0.50 9.00 DRILL G 7 P Circulate&condition hole.Reciprocate pipe CBU 6.5 BPM 500PSI 09:00 12:00 3.00 12.00 DRILL G 4 P RIH W/9 5/8"Casing&Landing JT.T/8,671'No drag on pipe.Same fill procedure.UP WT 345K DN WT 100K 12:00 13:00 1.00 13.00 DRILL G 7 P Circulate&condition 250 GPM 500 PSI.First CBU 4,850 Strokes/350 GPM 620 PSI.UP WT 300K DN WT 100K 13:00 16:30 3.50 16.50.DRILL G 1 P Swap out Franks fill up tool.M/U SLB Cement head,RID GBR equipment&clean rig floor. 16:30 18:30 2.00 18.50 DRILL G 20 P R/U SLB Cementers&pumps.R/U CH2MHILL trucks for displacement. .A ( 18:30 21:30 3.00 21.50 DRILL G 9 P PJSM W/all personnel!.SLB pumps 5 bbls H2O to test lines to 4,000psi OK/pump 75 bbls Mudpush II 10.5 ppg.@ 5.1 a,- .-( bpm with 435 psi./Release bottom plug/mix&pump J57 bbls 571 sacks of DeepCrete A 12.5 ppg./ 1.53 ft3/sk/5.130 ( t.1 I gal/sk @ 5bpm.Drop the top plug&pumped 5 bbls of water.Switched to rig pumps&displace with 629 bbls of 8.9 ppg OBM @ 5 bpm with 450 psi.Slowing down to 3 bpm @ 400 psi for last 15 bbls./Plug did not land on calculated strokes of 6125,total strokes 6,290.FCP 361 psi.Cement in place @ 22:10.Floats holding 21:30 22:30 1.00 22.50 DRILL G 20 P Rig down cement head/blow down lines/rig down GBR casing elevators.Rig down SLB&mud lines for OBM. 22:30 00:00 1.50 24.00 DRILL G 5 P Land the landing joint/Drain stack.Pick up Vetco M/U tool for casing pack off.Prepare for freeze protect. 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 Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 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) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 0.0 8,671.1,8/28/2010 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 Eni ESP Division Well Name: OP05-06 Daily Report ENI Petroleum Y p Well Code: 23985 • Field Name: Nikatchuq p CO. Inc. Date:8/29/2010 - Report#: 20 APIIUWI: 2 n II Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 17.94 Daily information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftlhr) POB Temperature(°F) Weather Wind 8,686.0 3,833.0 0.00 87.0 38.7 Cloudy.WC 34° 304°NW©6.3 mph Daily summary operation 24h Summary Test pack off to 5,000 psi.Change out upper pipe rams to 4 1/2"X 7"variables.Clean pits for OBM,prep new BHA,UD drill pipe&pick up replacement pipe.Change out mud pump#1 liners to 5 1/2". Operation at 07.00 P/U 5"drill pipe&running in hole 24h Forecast RIH with remaining 5"drill pipe.POOH&rack back in derrick.Test BOPE.Pick up 5"drill pipe with titanium hard banding&RIH,POOH&rack back in derrick.P/U BHA&RIH. 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 01:30 1.50 1.50 DRILL C 12 P M/U Vetco Gray running tool for pack off.Install 13 3/8"&9/5/8"Pack off.Test to 5,000 psi for 10 min.OK.UD Pack off running tool&install wear ring. 01:30 04:00 2.50 4.00 DRILL C 12 P Change out upper pipe rams with 4 1/2"X 7"variables.Riq up Little Red pump service&freeze protect outer annulus with i 148 bbls diesel.Pump 1-2 bbls per min.@ 550 psi. P 04:00 05:00 1.00 5.00 DRILL E 20 P Clean rig floor.Lay down remaining casing tools&cement equipment 05:00 06:30 1.50 6.50 DRILL E 4 P RIH with 24 stands of 5"drill pipe from derrick. 06:30 10:00 ' 3.50 10.00 DRILL E 4 P POOH&lay down 72 JTS.5"drill pipe with bad hard band. 10:00 12:00 2.00 12.00 DRILL E 25 P Service top drive&draw works.Load pipe shed with 5"drill pipe.Continue cleaning pits. 12:00 16:00 ' 4.00 16.00 DRILL E 20 P Load out previous BHA&unload new BHA.Electrical service in SCR room,Swap mud pump#1 over to 5 1/2"liners& continue work in pits and shakers. 16:00 22:00 6.00 22.00 DRILL E 4 P RIH with 4 stands HWDP from derrick&2.3'mule shoe,P/U&RIH with 121 JTS 5"drill pipe. 22:00 00:00 2.00 24.00 DRILL E 25 TR99 Down time repair power wrench. 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 Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 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) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 0.0 8,671.1 8/28/2010 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) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 Vigil Well Name: OP05-06 Eni E&P Division Daily Report ENI Petroleum Well Code: 23985 Field Name: Nikatchuq • Co. Inc. Date:8/30/2010 - Report#: 21 API/UWI: 2 n 0 Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(To) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(it) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 18.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 8,686.0 3,833.0 0.00 85.0 37.8 Cloudy.WC 33.1° 318°NW @ 6.3 mph Daily summary operation 24h Summary P/U Drill pipe and stand back in derrick for a total of 180 stands.Service top drive. Test BOPE to 250 psi low/3,500 psi high. BOPE test witness waived by Bob Noble AOGCC. Operation at 07.00 Picking up BHA#6 as per Schlumberger. 24h Forecast Surface test casing to 3,000 psi.hold for 30 min.P/U BHA#6 per Schlumberger/RIH with HWDP&drill pipe as per Eni well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 04:30 4.50 4.50 DRILL E 4 P P/U&RIH with 96 JTS.5"Drill pipe. 04:30 05:30 1.00 5.50 DRILL E 7 P Load OBM into pits. Circulate pipe volume at 9 BPM and 550 PSI to clean scale from pipe. 05:30 08:00 2.50 8.00 DRILL E 4 P POOH,Rack back 63 stands of 5"drill pipe in derrick 08:00 10:00 2.00 10.00 DRILL E 4 P P/U&RIH with 21 JTS.5"Drill Pipe. 10:00 10:30 0.50 10.50 DRILL E 25 TS99 Down time to repair hydraulic hose on Iron Ruffneck, 10:30 16:30 6.00 16.50 DRILL E 4 P P/U&RIH with 165 JTS 5"Drill Pipe 16:30 17:00 0.50 17.00 DRILL E 7 P Circulate&condition hole.Pump 900 strokes drill pipe volume. Pumped at 400 GPM and 120 PSI. 17:00 20:00 3.00 20.00 DRILL E 4 P POOH,Rack back 55 stands of 5"drill pipe in derrick. 20:00 21:00 1.00 21.00 DRILL E 20 P Remove wear bushing&set test plug. 21:00 00:00 3.00 24.00 DRILL E 12 P R/U Test eauioment for BOPE test Test annular/alt rams/choke manifold valves/kill&choke valves/IBOP's Demco/ all floor valves to 250 psi low/3500 psi high for 5 min.each test/Chart recorded test. BOPE test witness waived by Bob Noble AOGCC. Daily Contacts Ub f 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 Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 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) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 0.0 8,671.1 8/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,415.0 2,188.33 LSND mud(new) 8.95 233.0 11.00 1,250.4 %II Eni E&P Division Well Name: 0P05-06 ENI Petroleum Daily Report Well Code: 23985 • Field Name: Nikatchuq ��• CO. Inc. Date:8/31/2010 - Report#: 22 APIIUWI: page 1 of 1 Wellbore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(it) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 19.94 Daily Information Depth End(RKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 8,686.0 3,833.0 0.00 88.0 37.6 Overcast.WC 35.6° 59°ENE @ 3 mph Daily summary operation 24h Summary Complete BOPE test,Koomey draw down,blinds,choke manifold,upper pipe rams.Test casing to 3,000 psi&hold for 30 min.OK.P/U BHA#6&run in hole.P/U 3 stands HWDP and run in hole, Surface test equipment OK.Work on top drive,iron ruffneck&air tugger.RIH Filling pipe every 2,000'. Tag cement©7,418'. Drill up top wiper plug&cement stringers.Continue to drill out to 8,380'. Operation at 07.00 Pressure testing casing @ the float collar to 3,000 psi holding for 30 minutes&recording on chart.Plot casing pressure test on the pressure LOT form. 24h Forecast Upon successful completion of the casing test,drill out the float collar&shoe.Drill 20'of new hole&pull back up into the casing&perform an LOT.Will not pump more than 1/2 bbl after leak off is determined. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.70 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL E '12 P Complete BOPE test,manual choke,blinds,upper pipe rams&Koomey draw down. 02:30 04:00 1.50 4.00 DRILL E 12 P %urface test casing with the blind rams to 3,000 psi&hold for 30 min.OK.Plot casing pressure test on the pressure LOT form. Drain stack&blow down equipment.Clean rig floor&prep to P/U BHA. 04:00 08:00 4.00+ 8.00 DRILL E 20 P Hold PJSM with all personnel/.Pick up Schlumberger BHA#6&3 stands HWDP&circulate to perform surface test of equipment. 08:00 10:00 2.00 10.00 DRILL E 25 P Change out gripper dies in Top Drive&service.Change out dies in Iron Ruffneck&service. Adjust brakes&service Air Tugger. 10:00 14:30 4.50 14.50 DRILL E 4 P TIH Filling pipe every 2,000'.Tagged cement @ 7,418'/135K UP WT/90K DN WT 14:30 00:00 9.50 24.00 DRILL E '19 TP05 Drill up too wiper plus and cement strinaers from 7 418'to It 980'/WOR,2QK/185 SPM/650 GPM/2,850 psi/9,500 TO /158K UP WT/105 K DN WT/ ROT=40 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 Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 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) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 0.0 8,671.1 8/28/2010 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) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 V� Eni E&P Division Well Name: OP05-06 ENI Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq • Co. Inc. Date:9/1/2010 - Report#: 23 API!UWe en page 1 of 1 Wellbore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 , 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 fir) DFS(days) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 20.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftihr) POB Temperature(°F) Weather Wind 9,540.0 3,858.8 854.00 8.38 101.9 87.0 39.0 Overcast.WC 32.r 44°NE @ 9 mph Daily summary operation 24h Summary Drill out cement stringers to the float collar @ 8,584',CBU&pressure test casing to 3,000 psi holding for 30 min.OK.Drill out float collar&shoe along with 20'feet of new hole to 8,706'.Pull back into the casing&perform an LOT/FIT 8.7 ppg MW. Formation leaked off @ 12 ppg EMW 673 psi. Directionally drill ahead to 9,540'. Operation at 07.00 Directionally drilling ahead at 9,830'per Eni well plan. 24h Forecast Continue to directionally drill ahead as per Schlumberger DD.and ENI well program.Maintain mud properties and suffcient flow rates as required. Llthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.75 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 3 P Drilling cement stringers F/8,380'T/8,584 Float collar. 650 GPM/185/SPM/2,970 psi/ON 52k TO./OFF 9k TO/40 RPM/158k UP WT/98k DN WT 02:00 03:00 1.00 3.00 DRILL E 7 'P Circulate&condition hole @ 650 GPM/185 SPM/2,900 psi Reciprocate pipe 138k UP WT/90k DN WT 03:00 04:00 1.00 4.00 DRILL E 12 P Pressure test 9 5/8'casino lob Float collar to 3.000 osi&hold for 30 min.recorded nn chart Test nK 04:00 05:00 1.00 5.00 DRILL E 25 P R/D test equipment.Replace valve on pump manifod. 05:00 09:00 4.00 9.00 DRILL E 3 P Drill out the float collar&shoe F/8,584'T/8,686'&20'of new hole T/8,706 650 GPM/185 SPM/5-9 TO ON/5 TO OFF/40 RPM/6-20 WOB/155k UP WT/98k DN WT 09:00 10:00 1.00 10.00 DRILL E 7 P Rack back 1 STD drill pipe T/8,570'CBU @ 650 GPM/2,850 psi/40 RPM/8.7 MWT OBM 10:00 11:00 1.00 11.00 DRILL E 12 P Perform a LOT/FIT W/8.7 MWT OBM.formation leaked off lob 12 Dna.EMW 673 ns1 _ 11:00 19:00 8.00 19.00 DRILL E 3 P Directionally drilling F/8,706'T/9,540'©WOB 5-15k/192 SPM/680 GPM/2,900 psi /120 RPM/8,000 TO ON/ 6,200 TO OFF/160 UP/95 DN/8.7 MWT/10.90 ECD 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 Sach Bowe ENI Drilling Spvr. 907.670-8623 907-299-0531 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575.9427 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) ID(in) Grade Top(ftKB) Bottom(MB) Run Date CASING 9 5/8 8.681 L-80 0.0 8,671.1 8/28/2010 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) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 ariiiiiis Eni E&P Division Well Name: OP05-06 EN/Petroleum Daily Report Well Code: 23985 • Field Name: Nikatchuq n CO. Inc. Date:9/2/2010 - Report#: 24 API/UWI: 2 n II Wellbore name: OP05-06 page i of i Well Header Permit/Concesslon N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 21.94 Daily information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 11,601.0 3,837.3 2,061.00 14.42 142.9 88.0 39.4 Overcast.WC 31.5° 51°ENE @ 12.5 mph Daily summary operation 24h Summary Rotary drill from 9,540'to 11,601'TVD 3,834'. ADT 14.42 hrs.Maintain drilling parameters per SLB DD. Operation at 07.00 Rotary drilling ahead at 11,976'MD,3,849.6'TVD. 24h Forecast Continue to rotary drill ahead toward TD as per ENI well program Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 8.70 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Deser. 00:00 06:00 6.00 6.00 DRILL E 3 P Rotary drilling F/9,540'MD to 9,970'MD.Back reaming 6-8 min per stand. 680 GPM,192 SPM,3,025 psi on,2990 psi off 130 RPM,8-9k TO ON, 6-7k TO OFF 153 P/U,97 S/O,102 ROT WT'S.WOB 2-6 ECD 10.8,MWT 8.7 ppg 06:00 12:00 ' 6.00 12.00 DRILL E 3 P Rotary drilling F/9,970'MD to 10,500'MD.Back reaming 6-8 min per stand. 680 GPM,193 SPM,3,090 psi on,3,020 psi off 130 RPM,8-9k TO ON, 6-7k TO OFF 157 P/U,90 S/O,100 ROT WTS.WOB 2-15 ECD 10.9,MWT 8.7 ppg,SPR @ 10,300'25/35 215/260 psi. 12:00 18:00 6.00 18.00 DRILL E 3 P Rotary drilling F/10,500'MD to 11,120'MD.Back reaming 6-8 min per stand. 672 GPM,190 SPM,3,138 psi on,3,150 psi off 130 RPM,10k TQ ON, 8.8k TO OFF 168 P/U,85 S/O,100 ROT WTS.WOB 4 ECD 11.01,MWT 8.7 ppg,SPR @ 11,120'35/35 270/340 psi. 18:00 '22:30 4.50 22.50 DRILL E 3 P Rotary drilling F/11,120'MD to 11,530'MD.Back reaming 6-8 min per stand. 672 GPM,190 SPM,3,290 psi on,3,300 psi off 130 RPM,10.4 TO ON, 8.9 TQ OFF 175 P/U,75 S/O,100 ROT WTS.WOB 5k ECD 11.11,MWT 8.7 ppg '22:30 '23:00 ' 0.50 23.00 DRILL E 12 U Schlumberger ADN tool for density&porosity malfunctioned.Cycle pumps&work pipe.Tool is not responding and decision is made to drill ahead without it. 23:00 00:00 ' 1.00 24.00 DRILL E 3 P Rotary drilling F/11,530'MD to 11,601 MD.Back reaming 6-8 min per stand. 672 GPM,190 SPM,3,290 psi on,3,300 psi off 130 RPM,10.4 TO ON, 8.9 TQ OFF 175 P/U,75 S/O,100 ROT WTS.WOB 5k ECD 11.11,MWT 8.7 ppg, SPR @ 11,601'35/45280/300 psi TVD 3,834' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Sr.Drilling Spur. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 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) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 0.0 8,671.1 8/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P(Surf)(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 iiiiiit Eni E&P Division Daily Report Well Name: OP05-06 ENI Petroleum Well Code: 23985 Field Name: Nikatchuq • Co. Inc. Date:9/3/2010 - Report#: 25 API/UWI: 4`- n f Wellbore name: OP05-06 - -- page 1 of 1 Well Header PermltlConcession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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(ftlhr) DFS(days) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 22.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 13,613.0 3,892.5 2,012.00 14.20 141.7 87.0 37.0 Low Clouds.Fog, 59°ENE @ 21.8 WC 2r MPH Daily summary operation 24h Summary Rotary drill from 11,601'to 13,613'TVD 3,890.22'. ADT 14.2 hrs.Maintain drilling parameters per SLB DD.Running solids equipment to knock the fine solids out&adding calcium carbonate to stay in line with the MI mud program. Operation at 07.00 Drilling ahead toward TD as per ENI well plan. 24h Forecast Drill ahead toward TD keeping mud properties in line with the well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.75 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 Rotary drilling F/11,601'MD to 12,200'MD.Back reaming 6-8 min per stand. 675 GPM,191 SPM,3,340 psi on,3,300 psi off 130 RPM,10.8 TO ON, 9 TO OFF 171 P/U,80 S/O,100 ROT WTS.WOB 6-10k ECD 11.10,MWT 8.7 ppg, 06:00 12:00 6.00 12.00 DRILL E 3 P Rotary drilling F/12,200'MD to 12,661'MD.Back reaming 6-8 min per stand. 660 GPM,191 SPM,3,460 psi on,3,440 psi off 130 RPM,10 TQ ON, 8 TO OFF 178 P/U,75 S/O,98 ROT WT'S.WOB 2-10k,TVD-3,889' ECD 11.50,MWT 8.7 ppg, ADT-6.7 hrs,SPR @ 12,500'#1 25/35,330/385,#2 335/390 psi. 12:00 00:00 12.00 24.00 DRILL E 3 P Rotary drilling F/12,661'MD to 13,613'MD.Back reaming 6-8 min per stand. 655 GPM,191 SPM,3,630 psi on,3,600 psi off 130 RPM,12 TQ ON, 10.5 TQ OFF 180 P/U,60 S/O,98 ROT WT'S.WOB 2-10k ECD 11.76,MWT 8.7 ppg, ADT-7.5 hrs,Jar hrs 142.7 Daily Contacts Position _ Contact Name Company Title E-mail Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spar. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Eni representative Torn 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 Joe Longo ENI Drilling Eng. Joe.Longo @enipetroleum.com 907-865-3323 907-947-4323 Last C asing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(f KB) Run Date CASING 9 5/8 8.681 L-80 0.0 8,671.1 8/28/2010 Last Leakoff Test Depth(ftl(B) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 Eni E&P Division Well Name: 0P05-06 ENI Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq • IA� Co. Inc. Date:9/4/2010 - Report#: 26 API/UWI: 211 11 n II page 1 of 1 Wellbore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 23.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 15,433.0 3,971.7 1,820.00 10.75 169.3 87.0 37.2 Low Clouds,WC 39°NE @ 17.4 mph 26.6° Daily summary operation 24h Summary Rotary drill F/13,613'to 15,433',660 GPM,3,800 psi,130 RPM.Drilled through an unmapped fault,the decision was made to BROOH to 14,571'&side track to get back into the correct zone. Operation at 07.00 Side Tracking and drilling ahead as per Eni well plan. 24h Forecast ----- -----BROOH to 14,571'.Pump survey to determine side track point+/-14,603'to get back into more favorable well plan configuration. Llthology Shows MAASP Pressure(pal) Mud Weight(lb/gal) 8.75 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 Rotary drilling F/13,613'MD to 14,110'MD.Back reaming 6-8 min per stand. 670 GPM,190 SPM,3,790 psi on,3,760 psi off 130 RPM,12-13 TO ON, 9-10 TO OFF 190 P/U,55 S/O,95 ROT WTS.WOB 2-10k ECD 11.5,MWT 8.7 ppg, SPR @ 13,804'MD,TVD 3,891'25/35 SPM#1 395/445 psi,#2 390/440 psi '06:00 12:00 6.00 12.00 DRILL E 3 P Rotary drilling F/14,110'MD to 14,580'MD.Back reaming 6-8 min per stand. 675 GPM,192 SPM,3,820 psi on,3,790 psi off 130 RPM,10-14 TO ON, 9-10 TO OFF 190 P/U,60 S/O,93 ROT WTS.WOB 4-15k ECD 11.7,MWT 8.7 ppg, SPR @14,558'MD,TVD 3,930'25/35 SPM#1 400/450 psi,#2 395/445 psi 12:00 20:30 8.50 20.50 DRILL E 3 P Rotary drilling F/14,580'MD to 15,382'MD.Back reaming 6-8 min per stand. 651 GPM,192 SPM,3,825 psi on,3,800 psi off 130 RPM,12-13 TO ON, 12 TQ OFF 190 P/U,55 S/0,100 ROT WTS.WOB 8-15k, ECD 11.93 ppg,MWT 8.7 ppg. Pump weighted sweep @ 15,240'40 bbls of 10.2 ppg. 20:30 21:00 0.50 21.00 DRILL E 7 U Drilled through a fault @ 15,190'.Circulate&condition hole @ 650 GPM,3,800 psi. 21:00 21:30 0.50 21.50 DRILL E 3 P Rotary drilling F/15,382'MD 10 15,433'MD.Back reaming 6-8 min per stand. 651 GPM,192 SPM,3,825 psi on,3,800 psi off 130 RPM,12-13 TQ ON, 12 TQ OFF 190 P/U,55 5/0,100 ROT WTS.WOB 10k, ECD 11.93 ppg,MWT 8.7 ppg ADT 4.76 hrs,JARS 154.1 hrs.Decision made to drill STD.down and take survey. 21:30 22:30 1.00 22.50 DRILL E 7 P CBU @ 650 GPM,192 SPM,3,800 psi 22:30 00:00 1.50 24.00 DRILL E 4 U BROOH to 14,571'. Troughed F/14,571'to/14,603'MD and begin to side track @ this point,TVD 3,931' 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 Eni representative Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 Eni representative Jack Potter ENI HSE Jack.Potter @enipetroleum.com 907-685-1227 Em 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 Joe Longo ENI Drilling Eng. Joe.Longo @enipelroleum.com 907-865-3323 907-947-4323 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 0.0 8,671.1 8/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psl) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 Eni E&P Division Well Name: 0P05-06 EN!Petroleum Daily Report Well Code: 23985 • Field Name: Nikatchuq /� n Co. Inc. Date:9/5/2010 - Report#: 27 API/UWI: lC n II Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 24.94 Daily information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hr.) Average ROP(fflhr) POB Temperature(°F) Weather Wind 16,118.0 3,995.4 1,514.00 10.20 148.4 87.0 37.4 Overcast,WC 32° 13°NNE @ 7 mph Daily summary operation 24h Summary Directional side track/Perform OHST F/14,571'to 14,604'@ 650 GPM,185 SPM,3,650 psi.Rotary drill F/14,604'to 16,118'@ 660 GPM,185 SPM,3,860 psi. Operation at 07.00 Rotary drilling ahead.Depth @ 0400 Hours 16,346'MD. 24h Forecast Rotary drill ahead @ 660 GPM,185 SPM,3,850 psi.Running solids removal equipment&maintaining mud properties per MI well plan. Lithology Shows _ - MAASP Pressure(psi) Mud Weight(lb/gal) 8.70 Time Log Cum Start End Dur Dur Time Time (hr.) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL F 19 P Directional side tracking,perform OHST Troughing F/14,571'to 14,604'Reciprocating pipe per SLB-DD 650 GPM, 185 SPM,3,650 PSI.,97 P/U,95 S/0 02:30 12:00 9.50 12.00 DRILL E 3 P Rotary drilling F/14,604'MD to 15,400'MD.Back reaming 6-8 min per stand. 660 GPM,185 SPM,3,860 psi on,3,790 psi off 130 RPM,13-14TO ON, 11 TO OFF 190 P/U,55 S/0,95 ROT WT'S.WOB 2-10k, ECD 11.93 ppg,MWT 8.7 ppg.ADT 5.2 hrs 12:00 19:00 7.00 19.00 DRILL E 3 P Rotary drilling F/15,400'MD to 15,815'MD.Back reaming 6-8 min per stand. 660 GPM,185 SPM,3,950 psi on,3,800 psi off 130 RPM,14T0 ON, 12-13 TQ OFF 188 P/U,60 5/0,99 ROT WT'S.WOB 2-10k, ECD 12.03ppg,MWT 8.7 ppg. Pump 10.2 ppg.weighted sweep @ 15,433'20%increase in cuttings. 19:00 20:00 1.00 20.00 DRILL E 25 TRO3 Generators failed,resulting in blackout&loss of top drive.Electricians&rig mechanics repaired promptly. 20:00 00:00 4.00 24.00 DRILL E 3 P Rotary drilling F/15,815'MD to 16,118'MD.Back reaming 6-8 min per stand. 660 GPM,185 SPM,3,950 psi on,3,800 psi off 130 RPM,14TQ ON, 12-13 TO OFF,TVD 4,003' 190 P/U,60 S/0,98 ROT WT'S.WOB 4-15k, ECD 12.03ppg,MWT 8.7 ppg. 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 Eni representative Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 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 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 Tool Push Bruce Simonson NAD Tool Pusher _907670-8539 907-355-2278 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Data CASING 9 5/8 8.681 L-80 0.0 8,671.1 8/28/2010 Last Leakoff Test Depth(ftKB) ND(fIKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 Eni E&P Division Well Name: OP05-06 ENI Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq • Co. Inc. Date:9/6/2010 - Report#: 28 API/UWI: ge nn II page 1 of 1 Wellbore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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(lVhr) DFS(days) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 25.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftlhr) P08 Temperature(°F) Weather Wind 17,035.0 3,993.6 917.00 11.05 83.0 91.0 34.9 Partly Cloudy,AM 26°NNE @ 5.2 mph Fog,WC 28.6° Daily summary operation 24h Summary Rotary drill to TD @17,035'MD&3,993.5'TVD.Sondition hole&pump 30 BBL 10.2 PPG weighted sweep @ 660 GPM,4,000PSI.BROOH to 13,709'@ 660 GPM 3,400 PSI.No tight spots or packing off encountered. Operation at 07.00 Continue BROOH @ 660 GPM,3,400 PSI. Depth @ 0400 hours 11,400'MD. 24h Forecast Continue to BROOH to the 9 5/8"casing shoe @ 8,671'.CBU+/-5 X,cut&slip drilling line.Trip back in hole on elevators as far as safely possible,filling pipe&breaking circulation every 20 stands. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.75 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 Rotary drilling F/16,118'MD to 16,420'MD.Back reaming 6-8 min per stand. 660 GPM,188 SPM,3,930 psi on,3,895 psi off 130 RPM,13-15 TO ON, 12 TO OFF, 190 P/U,55 S/O,93 ROT WT'S.WOB 4-18k, ECD 11.8 ppg,MWT 8.7 ppg. 06:00 '12:00 6.00 12.00 DRILL E 3 P Rotary drilling F/16,420'MD to 16,925'MD.Back reaming 6-8 min per stand. 660 GPM,190 SPM,4,000 psi on,3,955 psi off 130 RPM,14-16 TO ON, 13-14 TQ OFF, 195 P/U,50 S/O,95 ROT WT'S.WOB 6-18k, ECD 11.9 ppg,MWT 8.7 ppg. 12:00 13:30 1.50 13.50 DRILL 'E 3 P Rotary drilling F/16.925'MD to 17.035M0.BacJc reaming 6-8 min per stand. 660 GPM,190 SPM,4,040 psi on,4,030 psi off D tAJJ 130 RPM,14-16 TQ ON, 13-14 TQ OFF,TVD 3,993' 200 P/U,Cannot S/O with out rotating,98 ROT WT'S.WOB 6-18k,ECD 12.23 ppg,MWT 8.75 ppg. 13:30 17:00 3.50 17.00 DRILL E 7 P Circulate 8 condition hole.Take,on bottom survey. SPR @ 17,035'MD/3,993.5'TVD/MWT 8.75 PPG Pump#1 25/35 SPM 420/500 PSI Pump#3 25/35 SPM 420/480 PSI Pump 30 BBL 10.2 PPG weighted sweep.CBU 3X @ 660 GPM 4,000 PSI,140 RPM,14-15 TO 17:00 00:00 7.00 24.00 DRILL E 6 P BROOH F/17,035'to 13,709'No tight spots or packing off encountered. 660 GPM,3,400 PSI,140 RPM,12-13 TO P/U 180,S/O 62 Dally 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 Eni representative Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 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 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 Tool Push Bruce Simonson NAD Tool Pusher 907-670-8539 907-355-2278 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 0.0 8,671.1 8/28/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density pb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 r Eni E&P Division Well Name: OP05-06 Iff* Daily Report p ENI Petroleum Well Code: 23985 Field Name: Nikatchuq n • Co. Inc. Date:9/7/2010 - Report#: 29 APUUWI: lC n fi Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator !ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM , 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 26.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftihr) POB Temperature(°F) Weather Wind 17,035.0 3,993.6 0.00 91.0 47.7 Clear,WC 44.8° 144°SE @ 6.8 mph Daily summary operation 24h Summary BROOH F/13,709'to 8,635'@ 660 GPM,185 SPM,3,500 PSI.140 RPM,9-12k TO no tight spots or pack offs.Pump 40 BBL 10.4 sweep&CBU 5X @ 660 GPM,2,700 PSI.Cut&slip drill line, service pipe skate.TIH F/8,635'to 16,920'Pump 10.75 PPG sweep&CBU 3-4X @ 660 GPM 3,950 PSI.Cleaning pits for displacement with solids free OBM. Operation at 07.00 Finish displacing well with completion fluid._ 24h Forecast Change out mud to solids free OBM&displace wellbore with the completion fluid.Take new slow pump rate when finished displacing.POOH on elevators to the casing shoe @ 8,671',lay down 84 stands of 5"D/P&the BHA. Uthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.85 Time Log Cum Start End Dur Dur Time Time (hr) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 08:30 8.50 8.50 DRILL E 6 P BROOH F/13,709'to 8,635'@ 660 GPM,185 SPM,3,500 PSI,140 RPM,9-12k TO. No tight spots or packing off encountered. 08:30 11:00 2.50 11.00 DRILL E 7 P Circulate and condition hole.CBU 5 X @ 8,635',660 GPM,2,700 PSI. Reciprocate pipe @ 30 RPM,4k TO.Pump 40 BBL 10.4 PPG sweep. 11:00 13:30 2.50 13.50 DRILL E 25 P Cut and slip drilling line,recalibrate block height.Prep pipe shed for liner run,service&inspect pipe skate.Begin transporting Versa Pro LS from the rig to Ugnu pad for storage. 13:30 20:00 6.50 20.00 DRILL E 4 P TIH F/8,635'to 16,920'filling pipe and breaking circulation every 20 stands. Wash and ream F/16,198'to 16,920'@ 660 GPM,140 RPM P/U 200,S/O None,ROT WT100. 20:00 00:00 4.00 24.00 DRILL E 7 P Circulate and condition hole.Reciprocate pipe @ 16,920'140 RPM,15k TO.Pump 30 BBL 10.75 PPG sweep.CBU 3-4 X @ 660 GPM,3,950 PSI.Begin cleaning out mud pits in preparation for displacement with solids free OBM. 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 Eni representative Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 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 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 Tool Push Bruce Simonson NAD Tool Pusher 907-670-8539 907-355-2278 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 0.0 8,671.1 8/28/2010 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) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 trokit Eni E&P Division Well Name: OP05.06 ENI Petroleum Daily Report Well Code: 23985 • CO, Inc. Field Name: Nikatchuq • - Date:9/8/2010 - Report#: 30 APIIUWI: efi Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OPO5-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 27.94 Daily information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftihr) POB Temperature(°F) Weather Wind 17,035.0 3,993.6 0.00 86.0 44.6 Cloudy,Rain,WC 246°WSW @ 7.5 40.5° mph Daily summary operation 24h Summary Circulate&condition hole clean,finish cleaning pits&displace with SF-OBM 8.8PPG.POOH F/16,920'to 16,288'.Pipe trying to swab,small flow @ flow check.Wash&ream back to 16,920'@ 542 GPM, 2,770 PSI,70 RPM,22-24 K TQ,Well flow back @ 7.8 BPH.Circulate&condition hole while weighting up completion fluid to 9.0+PPG with calcium chloride.POOH F/16,920'to 11,988' P/U 190 K,NO Rotation,Pump out 250/300GPM,Drag 520 K all the way.While ctcuiating @542 gpm experienced 10 BPH losses after SF-OBM displaced,before displacement losses at 7 BPH. Operation at 07.00 POOH @ 9,080 pumping out of the hole,250 GPM,No rotating,watching pipe displacement very closely,pipe displacement correct. 24h Forecast Continue POOH to the casing shoe @ 8,671',Lay down 252 JTS of D/P,stand back the HWDP in the derrick&lay down the BHA Prep for the liner run. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.00 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 7 P Circulate&condition hole clean @ 650 GPM,185 SPM,3,750 PSI,140 RPM,15 K TO Finish cleaning pits for SF-OBM displacement.Losses at 7 BPH 01:30 06:30 5.00 6.50 DRILL E 9 P Displace well bore to SF-013M nn,,5 BPM,700 PSI,60 RPM,13 K TO Reciprocate pipe-TO builds to 22 K,B/R 2 STDS,rack back in derrick&finish displacement. SPR#2 @ 16,765',25/35 SPM,130200 PSI.Flow-Static=No Flow From Wellbore.Drop rabbit,STD#169 06:30 07:30 1.00 7.50 DRILL E 4 P POOH F/16,765'to 16,288'Pull 1 STD,pipe trying to swab,pump out 4 more STDS @ 270 GPM,760 PSI,P/U 225 K. Small amount of flow observed during flow check. 07:30 08:30 ' 1.00 8.50 DRILL E 6 U Ream&wash back in hole F/16,288'to 16,920'@ 542 GPM,2,770 PSI,70 RPM,22-24 K TO. 5.5 BBL loss on trip. 08:30 10:30 2.00 10.50 DRILL E 7 U Circulate 1 full circulation @ 540 GPM,70 RPM 17 K TQ Flow check for 20 minutes-Well flow @ 7.8 BPH.While circulating at 540 gpm,experience 10 BPH losses. 10:30 16:30 6.00 16.50 DRILL E 7 U Circulate&reciprocate pipe while weighting up completion fluid with calcium chloride F/8.8 PPG to 9.0+PPG,540-650 GPM,Losses consistant @10 BPH while circulating at 540-650 pgm. 2,880 PSI,70 RPM,17 K TO.New SPR#1 25/35 SPM,120/215 PSI.#2 25/35 SPM,125/215 PSI 16:30 00:00 7.50 24.00 DRILL E 4 P POOH F/16,920'to 11,988'Pump out @ 250 GPM,880 PSI,No rotating.Drag 5/20 K all the way.P/U 190 K,no losses, pipe displacement correct. 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 Eni representative Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 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 Tool Push Bruce Simonson NAD Tool Pusher 907-670-8539 907-355-2278 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(fIKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 0.0 8,671.1 8/28/2010 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) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 i. t Eni S&P Division Well Name: OP05-06 EN!Petroleum Daily Report Well Code: 23985 • Field Name: Nikatchuq n Co. Inc. Date:9/9/2010 - Report#: 31 APIIUWI: a°�- n II Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° /Operator ENI Share(%) Well Configuration type 2100800 IENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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(ftAu) DFS(days) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 28.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 17,035.0 3,993.6 0.00 87.0 ■ Daily summary operation 24h Summary POOH F/11,988'to 8,635'.pumping out @ 300 GPM,850 PSI.correct pipe displacement observed on trip out. Lay down 5"drill pipe F/8,635'to 3,647'.Rack back remaining 30 stands in derrick,lay down the Jar,BHA,&break Bit. P/U 48 Jts HWDP&rack in derrick.Rig up GBR tools,hold PJSM for liner run. Run slotted liner to 1,718' Operation at 07.00 RIH with slotted liner F/1,718'to 3,750' _ 24h Forecast Finish running slotted liner.Record P/U&S/O Wts.P/U Hanger/Packer assembly,add Palmix.trip in hole 1 STD drill pipe&circulate 200 strokes.Record P/U&S/O Wts.RIH with liner assembly on drill pipe&HWDP recording P/U,S/O&ROTWts.every 5 stands Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.00 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 DRILL E '4 P Pump out of hole F/11,988'to 8,635'@ 300 GPM,850 PSI,correct pipe displacement while tripping out of hole.Hold PJSM with all rig personnel prior to laying down drill pipe. 05:00 12:00 7.00 12.00 DRILL E 4 P Lay down drill pipe F/8,635'to 3,64T No swabbing,correct pipe displacement observed while laying down drill pipe. 12:00 13:30 1.50 13.50 DRILL E 4 P POOH&rack back last 30 stands of drill pipe in the derrick.Correct pipe displacement. i 13:30 16:00 2.50 16.00 DRILL E '4 P Flow check @ BHA 593'No flow of fluids from well bore Stand back 4 STDS.HWDP.Lay down the jars,the BHA and break bit.Jar hrs.174.0 All 3 stabilizers in gauge(8.38"on Exceed,8.25"on LWD,&8.38"above LWD)Bit also in gauge. 16:00 17:30 1.50 17.50 DRILL E 20 P Cleaning rig floor from trip out of hole,lay down bit and tools from rig floor. 17:30 20:00 2.50 20.00 DRILL E '20 P Pick up 48 jts.HWDP and rack back in derrick 20:00 21:00 1.00 21.00 DRILL E 20 P Rig up GBR tools&hold PJSM with all pesonnel involved with liner run. 21:00 00:00 3.00 24.00 DRILL E 4 P Run 5 1/2"slotted liner in hole to 1,718'.Bakerlok silver bullet shoe and X/O to JT#1 TO.521 Hydril coon.to 14 K ft lbs. P/U WT.62K,S/O WT 62K Daily Contacts Position Contact Name Company Title E-rnall Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative Sach Bowe ENI Drilling Spvr. 907-670-8623 907-299-0531 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 Tool Push Bruce Simonson NAD Tool Pusher 907-670-8539 907-355-2278 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 4.892 L-80 8,493.9 16,920.0 9/9/2010 Last Leakoff Test Depth(fIKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psl) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 Eni E&P Division Well Name: OP05-06 rrn ENI Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq • Co. Inc. Date:9/10/2010 - Report#: 32 APINWI: an "0 - page 1 of 1 Wellbore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 29.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(I) Weather Wind 17,035.0 3,993.6 0.00 94.0 37.9 Low Clouds,Fog, 28°NNE @ 7 mph WC 32.7° Daily summary operation _ __ 24h Summary RIH picking up slotted liner Hydril 521,L-80,17 ppf from 1,718'to 8,397'. Take PU and SO weights every 10 joints. Pick up SLZXP liner top packer as per BOT Rep. Inspect same. Mix and pour Baker Pal-Mix into liner tie-back sleeve. Wait 30 minutes for Pal-Mix to set up.Good set. Make up first stand of drill pipe and record PU WT=130K,SO WT=65K,Rotate WT =85K,TQ at 30 Rpm= 4,000 ft/lbs.,TO at 4-RPM=4,200 ft/lbs.Fluid losses at 1 BPH while RIH with liner.RIH with slotted liner on drill pipe F/8,437'T/12,456'. Run out of hookload. Record PU,SO,and Rot weights and torques every 10 stands. Rotate liner in hole on 5"drill pipe from 12,456'to 16,920'. Final torque 20K @ 45 RPM. UP WT=250K,DN WT=no hook load,ROT WT=140K. Record parameters every 5 stands&break circulation every 10 stands. Final friction factor torque at 0.18 while reaming. SLM(strap)drill pipe and HWDP. Circulate 1.2 drill pipe volume-4 BPM@ 415 PSI.Shut down,drop ball&pump down to set @ 106 bbls.away. Continue to pressure to 3,000 psi as per BOT Rep. Test packer. Close Hydril and pressure up to 1,500 psi. Hold for 10+minutes and chart record. Operation at 07.00 L/D 5"HWDP and 5"drill pipe. 24h Forecast POOH L/D 5"HWDP&DP. RN and perform USIT log with Schlumberger Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.00 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 10:00 10.00 10.00 DRILL G 4 P P/U 5%",17 4,L-80 slotted liner with GBR f/1718'-t/8397'-Record Uo&D.n w@9hj5 every 10 joints. jf_- 10:00 12:00 2.00 12.00 DRILL G 4 P P/U SLZXP liner top packer as per BOT rep.Mix&pour Baker Pal-mix into liner tie-back sleeve(wait'hr.to set up)- N`" - good.R/D GBR equipment&remove from floor.Make up first stand drill pipe @ 8437'and record parameters Up wt.= E-4-,.4-Av 130K,Dn wt=65K,Rot wt.=85K-Torque @ 30 RPM=4000 ft/lbs;Torque @ 40 RPM=4200 ft/lbs.-Fluid loses @ 1 BPH while RIH with liner. 12:00 15:30 3.50 15.50 DRILL G '4 P Continue RIH with 5'4",17#,L-80 slotted liner on 5'drill pipe f/8437'-t/12456'. Run out of hook load. Record Up,DN, Rot weight every 5 stands and fill pipe every 10 stands.SLM(strap)drill pipe stands while RIH. 15:30 22:00 6.50 22.00 DRILL G '4 P Rotate liner in hole on 5"drill pipe and 5"HWDP f/12456'-V16920'-Final torque 20K @ 45 RPM,Up wt.=255K,Dn wt.= No hook load,Rot wt.=140K.-Record parameters every 5 stands&break circulation every 10 stands.Final 0.3 friction factor torque and 0.18 while reaming.SLM(strap)drill pipe&HWDP. 22:00 00:00 2.00 24.00 DRILL G "4 P Circulate 1.2 drill pipe volume-4 bpm @ 415 psi.-shut down,drop ball&pump down to set @ 106 bbls.away continue to pressure to 3000 psi-set packer as per BOT Rep.-Test packer-Close Hydril and pressure up to 1500 psi.-hold for 10+minutes&chart record. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. ScottBeauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Tool Push Bruce Simonson NAD Tool Pusher 907-670-8539 907-355-2278 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 4.892 L-80 8,493.9 16,920.0 9/9/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 0.00701 Eni E&P Division Well Name: OP05-06 ENI Petroleum Daily Report Well Code: 23985 • Field Name: Nikatchuq � n Co. Inc. Date:9/11/2010 - Report#: 33 API/UWI: cP n II Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) 0P05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 30.94 Daily Information Depth End(ftKB) Depth End(ND)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 17,035.0 3,993.6 0.00 88.0 50.2 Overcast.WC 50.2° 144°SE @ 9.6 mph Daily summary operation 24h Summary Finished liner packer test\Release from liner as per BOT Rep.\Circulate bottoms-up\POOH UD 5"HWDP&DP f/8431'-t2375'\POOH(rack back in derrick)f/2375'-to BOT tools&UD same as per Rep.\Held PJSM w/Schlumberger&Well Tech-P/U lubricator&tools string\RIH,started using tracker @ 3000'to 6500'@ 2400 hrs.Total fluid lose 13 bbls. Operation at 07.00 Schlumberger E-line USIT/CBL. 24h Forecast Running USIT/CBL with Schlumberger and evaluate logs on TOC for AOGCC-UD remaining drill pipe-P/U completion string. Uthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.00 Time Log Cum Start End Dur Dur Time Time (hrs) (hra) Phase Opr. Act Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL G 12 P Test on liner packer.good-bleed off&open Hydril-Release running tool from liner as per BOT Rep @ 8494',Up wt.= 207K.POOH U 8431'.Dn wt.=110K. 00:30 02:30 2.00 2.50 DRILL E 7 P 'Circulate bottoms-up @ 8431'pumping 194 gpm @ 370 psi.-monitor well for 15 minutes-Up wt=205K,Dn wt.110K. 02:30 12:00 9.50 12.00 DRILL E 4 P POOH-UD 5"HWDP and DP f/8431'-t/3636',vac out OBM residue from pipe-Up wt.=100K,Dn wt.=85K-Fluid to well 5 bbls. 12:00 12:30 0.50 12.50 DRILL E 25 P Service rig-Top drive,blocks,draw-works. 12:30 14:30 2.00 14.50 DRILL E 4 P Continue UD 5"drill pipe f/3636'-t/2375'-Up wL=100K,Dn wt.=85K 14:30 15:30 1.00 15.50 DRILL E 4 U POOH f2375'to Baker liner running tools-(stand back 25 std in derrick). 15:30 16:00 0.50 16.00 DRILL E 4 P UD Baker liner running tools as per BOT Rep. 16:00 16:30 0.50 16.50 DRILL J 1 P Held PJSM with Schlumberger to run USIT/CLB log. 16:30 20:00 3.50 20.00 DRILL J 5 P R/U Schlumberger E-line-P/U lubricator strip trough same-P/U&M/U logging tools string as per Schlumberger. 20:00 00:00 4.00 24.00 DRILL J -4 P RIH with USIT/CBL on E-line-started using @ f/3000'-U 6500'@ midnight.Tractor speed 30-35 fpm.Total fluid to well 13 bbls.for 24 hrs. Daily Contacts Position Contact Name Company Title E-mail Office MOWN Eni representative Scott Beauchamp ENI Sr.Drilling Sow. Scott.Beauchamp @enipetroleum.com 907-670-8623 X907-841-8759 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bemie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Tool Push Bruce Simonson NAD Tool Pusher 907-670-8539 907-355-2278 Last Casing seat Cos.Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 _ 4.892 L-80 8,493.9 16,920.0 9/9/2010 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(Ib/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 - Eni S&P Division Well Name: 0P05-06 EN!Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq • CO. Inc. Date:9/12/2010 - Report#: 34 API/UWI: en II n page 1 of 1 Wellbore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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(ftlhr) DFS(days) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 31.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 17,035.0 3,993.6 0.00 86.0 44.2 Mostly Clear.WC 173°S @ 3.6 mph 42.1° Daily summary operation 24h Summary Schlumberaer&Well Tech performed USJT/CBL on 9 5/8"csa TOC tSr 8150' L/D SLB tool string&lubricator&R/D same. Service rig-Change out saver sub,grease&inspect gripper/pipe handler, re-torque guide rail bolt&safety wire.Waited for AOGCC to looked over USIT/CBL logs&make a decision.OK.Permission to proceed with ESP Completion. RIH w/5"HWDP/DP to 3990'\POOH L/D same\RIH w/5"DP t/3896'\POOH f/3896'-t/1040'. Operation at 07.00 R/U and P/U 4 1/2"ESP completion assembly. 24h Forecast Finish UD 5"drill pipe. R/U Centrilift&Halliburton for ESP completion. P/U&run 4 1/2"ESP Completion Assembly as per Centrilift Rep. Uthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.00 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 06:30 6.50 6.50 DRILL J '19 P Schlumberger/Well Tech performed USIT/CBI on 9 5/8"csg.-RIH f/6515'-t/8450',Log out f/8450'-t/6900'with repeat& main logs-TOC @ 8150'as per logs-POOH f/6900'to surface with check @ 3300'. 06:30 08:30 2.00 8.50 DRILL J "5 P L/D Schlumberger E-line tool string&lubricator-R/D and Gear floor,blow down choke manifold&lines.Prep and send log data to town. 08:30 09:30 1.00 9.50 DRILL E .25 P Rig service of top drive,crown,draw-works-(Wait on AOGCC to look over CBL logs). 09:30 12:00 2.50 12.00 DRILL E '25 P Change out saver sub on top drive quill shaft,grease gripper/pipe handler,re-torque guide rails bolt and safety wire. (While waiting on AOGCC decision-OK). 12:00 14:30 2.50 14.50 DRILL E 4 P Held PJSM-RIH with 5"drill pipe from derrick 1/3990'to be L/D-Up wt.=105K,Dn wt=80K. 14:30 19:30 5.00 19.50 DRILL E 4 P Held PJSM-POOH-L/D 5"Drill Pipe f/3990'-t/surface,vacuum out OBM residue from pipe. 79:30 21:00 1.50 21.00 DRILL E '4 P RIH with 5"drill pipe from derrick 1/3896',Up wt.=102K,Dn wt.=82K. 21:00 00:00 3.00 24.00 DRILL E 4 P POOH-UD 5"Drill Pipe f/3896'-U1040',vacuum out OBM residue from pipe. Daily Contacts Position Contact Name Company Title Email 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 Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Tool Push Bruce Simonson NAD Tool Pusher 907-670-8539 907-355-2278 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(f1KB) Bottom(ftKB) Run Date LINER 51/2 4.892 L-80 8,493.9 16,920.0 9/9/2010 Last Leakoff Test Depth(ftKB) TVD(PKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 Eni E&P Division Well Name: OP05-06 ENI Petroleum Daily Report Well Code: 23985 • Field Name: Nikatchuq n Co. Inc. Date:9/13/2010 - Report#: 35 APIIUWI: 2 n II Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 1 Water Depth(ft) - - - RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 I 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 32.94 Daily Information Depth End(ftKB) Depth End(ND)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftlhr) POB Temperature(°F) Weather Wind 17,035.0 3,993.6 17,076.00 86.0 37.4 Overcast.WC 25.5° 51°NE @ 26.7 mph Daily summary operation 24h Summary POOH-UD 5"DP f/3896'-t/1040'\R/U GBR,Centrilift&Halliburton-P/U TTC&load pump,pack-off&test tool.Test to 1000 psi f/15 mins(chart record).Remove test tool&install tbg.stop into TTC\R/D Halliburton slick line.Load floor with Centrilift equipment and R/U ESP&injection line sheaves. Decision to make clean-out run. R/D Centrilift tool&equipment. R/U test BOPE to AOGCC regulation(AOGCC witness waived by Chuck Scheve). R/D test equipment&install wear ring. P/U Baker RCJB BHA. P/U 5 drill pipe to 80T. Operation at 07.00 P/U 5"drill pipe with Baker fishing/clean out assembly. 24h Forecast P/U DP with Baker reversing,junk baskets,and magnets to liner top.Make a clean out run\POOH stand back drill pipe&check results of clean out run.. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) • 9.10 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL E 4 P POOH-UD 5"Drill Pipe f/1040'-t/surface,Vacuum out OBM residue from pipe. 02:30 03:00 0.50 3.00 DRILL C 20 P Pull wear bushing with Vetco Gray Rep. 03:00 03:30 0.50 3.50 DRILL E 1 P Clean rig floor after L/D Drill pipe. 03:30 08:00 4.50 8.00 DRILL K 5 P Held PJSM\RJU GBR eauipment for 4 12"trio,\P/U Centrilift TTC&components to rig floor,MN pup&first joint to TTC \R/U Halliburton slick line-P/U&set pump,pack-off&test plug in TTC-test to 1000 f/1500 psi.\Remove test tool&set tbg.stop.\R/D Halliburton Slick line. 08:00 10:30 2.50 10.50 DRILL K 5 P Load floor with Centrilift tools&iewelry for ESP comoletjgp"Spot injection line spooler on floor\R/U&hang Centrilift sheaves for ESP cable&injection line. 10:30 12:00 1.50 12.00 DRILL K 5 U R/D Centrilift cable&injection sheaves-clear floor of tools&jewelry for ESP completion assembly.Total fluids lose for tour 1 bbl. 12:00 13:30 1.50 13.50 DRILL K 5 U MN 4 1/2"tbg.(1 joint)to TTC,pup&joint-stand back in derrick as per Centrilift.\R/D GBR tongs&remove from floor. 13:30 14:30 1.00 14.50 DRILL E 7 P Function BOPE to clear metal cuttings out of cavities and circulate to flush stack with Johnny Wacker. ///111 14:30 16:00 1.56 16.00 DRILL E 5 P MN 4 12 18 "X 5"test joint\set test plug\flood stack&choke with H2O 0 e 16:00 20:30 4.50 20.50 DRILL E 12 P RN List BOPE to AOGCC reaulation-250 psi low/2500 psi high on Hydril-250 psi low/3500 psi on rams,choke /� manifold,choke,kill,floor valves&top drive-(chart record)\performed accumulator test.(AOGCC witness waived by Chuck Scheve) d 20:30 21:30 1.00 21.50 DRILL E 5 P Pull test plug and drain stack-blow down BOPE/choke manifold&set wear bushing with Vetco Gray Rep. 7"/3 21:30 23:00 1.50 23.00 DRILL E 4 U Held PJSM-P/U RCJB BHA as per Baker Fishing Tool Rep. 23:00 00:00 1.00 24.00 DRILL E 4 U P/U 5"drill pipe(drift 3.125')f/42'-U807' 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 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Alvin Criswell ENI Expediter AlvinCriswell@enipetroleum.com 907-980-7545 Tool Push Bruce Simonson NAD Tool Pusher 907-670-8539 907-355-2278 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 4.892 L-80 8,493.9 16,920.0 9/9/2010 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(Ib/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 Eni ESP Division Well Name: OP05-06 W ENI Petroleum Daily Report Well Code: 23985 e Field Name: Nikatchuq 2 • Co. Inc. Date:9/14/2010 - Report#: 36 API/UWI: 'I I' Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) 0P05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 33.94 Daily information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature(°F) Weather Wind 17,035.0 3,993.6 8,535.00 86.0 35.4 Overcast.WC 26.2° 54°NE @ 14.5 mph Daily summary operation 24h Summary RIH-P/U 5"Drill Pipe f/807'-V 8083'with BHA#8\Wash/Ream f/8083'-V 8500'TOL(DPM)\POOH f/8500'(DPM)-V BHA @ 42'\Work BHA#8,recovered 12.5 lbs.of metal\Cut drilling line\ Wait tools-Service Rig\P/U BHA#9 as per Baker Rep\RIH t/1009'. Operation at 07.00 Wash/Ream with BHA#9 to TOL 8500'. 24h Forecast RIH with BHA#9(Baker clean out assembly)to TOL @ 8500'\POOH UD 5"drill pipe&BHA#9\R/U&run 4 1/2"Centrilift ESP Completion Assembly. Uthology Shows MAASP Pressure(psi) Mud Weight(1b/gal) 9.10 Time Log Cum Start End Dur Dur Time Time (hrs) (hn) Phase Opr. Act. Plan Oper.Descr. 00:00 08:30 8.50 8.50 DRILL E 4 P RIH-P/U 5"Drill Pipe f/807'-V 8083'with Baker tools,BHA#8(RCJB basket,junk basket&magnets). 08:30 09:30 1.00 9.50 DRILL E 7 U Circulate-Baker drop ball&pump down with 5 bpm @ 550 psi,with 80%drill pipe volume pumped slowed to 84 gpm @ 140 psi.-land ball in seat of RCJB\Established parameters:20 rpm @ 8K torque\Up wt.=150K,Dn wt.=70K,Rot wt.= 112K. 09:30 13:00 3.50 13.00 DRILL E 7 U Wash/Ream f/8083'-V 8467'-390 gpm @ 1660 psi.\20 rpm @ 8.5K torque-stop rotating @ 8467'and continue to wash f/8467'-V 8500'TOL(DPM)\Up wt.=160K,Dn wt.=73K,Rot wt.=115K.Mud wt.@ 9.1 ppg.No fluid loses. 13:00 17:00 4.00 17.00 DRILL E 4 U Monitor well-POOH f/8500'-V BHA @ 42' 17:00 19:00 2.00 19.00 DRILL E 5 U Work BHA-Clean metal off magnets-UD RCJB&junk baskets-total metal recovered 12.5 lbs.-consult with town on forward plan. 19:00 20:30 1.50 20.50 DRILL E '25 U Cut drilling line,inspect draw-works&service rig. 20:30 22:00 1.50 22.00 DRILL E 24 U Service rig-Top Drive,blocks&crown. 22:00 23:00 1.00 23.00 DRILL E 4 U P/U BHA as per Baker Rep.(mule shoe,3 string magnets&9 5/8"csg brush)BHA#9 23:00 00:00 1.00 24.00 DRILL E 4 U RIH f/52'-V 1009'with BHA#9(Baker clean out assembly) Daily Contacts Position Contact Name Company Title E-mail . Mobile Eni representative Scott Beauchamp ENI Sr.Drilling Spvr. Scott.Beauchamp @enipetroleum.com 907-670-8623 907-841-8759 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Tool Push Bruce Simonson NAD Tool Pusher 907-670-8539 907-355-2278 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 4.892 L-80 8,493.9 16,920.0 9/9/2010 Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type Fluid Density(Ib/gal) P(Surf)(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 Eni E&P Division (Well Name: OP05-06 VI* Dail t ENI Petroleum Y Re or p wen Code: 23985 • Field Name: Nikatchuq n Co. Inc. Date:9/15/2010 - Report#: 37 API/UWI: 2 n II Wellbore name: OP05-06 page 1 of 1 Well Header Permlt/Concession N° Operator ENI Share(%) Well Configuration type 2100800 EM PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 34.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(fUhr) POB Temperature(°F) Weather Wind 17,035.0 3,993.6 8,815.00 86.0 42.1 Overcast.WC 41.9° 259°W @ 2.4 mph Daily summary operation 24h Summary RIH f/1009'-U 8029'\Wash/Ream f/8092'-U 8500'(stop rotating @ 8443'&tag TOL @ 8500'w/4K)\POOH L/D 5'DP f/8500'-U 8210'\Down time(Code 8)-Columbian pipe skate broke down- trouble shoot pipe skate/Decided to POOH f/8210'-U BHA @ 52'while Nabors worked on pipe skate\Clean 9 5/8"csg.brush&three magnets(recovered 2.5 lbs of metal shavings)-WU BHA\RIH f/52'-U 8029'\Wash&ream f/8029'-U 8220'. Continue to circulate\Down time(Code 8)-Columbian pipe skate still broke down-Columbia Rep.with Nabors senior field mechanic&electrician on location after 1715 hrs.Hydraulic oil system contaminated with water,due to heat exchanger and faulty ball valves.Water plugging screens on solenoid of hydraulic valves. Operation at 07.00 Working on repairs of Columbian pipe skate. Currently running function tests. 24h Forecast Repair Nabors Columbian pipe skate\L/D 5'drill pipe&Baker fishing BHA\Pull wear bushing\R/U GBR&Centrilift to run 4 1/2"ESP completion. Uthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.10 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 4 U RIH 5"Drill Pipe f/1009'-U 8092'with Baker tools,BHA#9(9 5/8"csg.brush and three magnets). 03:00 05:00 2.00 5.00 DRILL E 6 U Wash/Ream f/8092'-U 8500'-345 gpm @ 710 psi.\30 rpm @ 6-7K torque-stop rotating @ 8443'and wash f/8443'-U 8500'TOL(tag w/4k)\Up wt.=155K,Dn wt.=70K,Rot wt.=110K.Mud wt.@ 9.1 ppg.Monitor well for 15 minutes. 05:00 06:00 1.00 6.00 DRILL E 4 U POOH-LID 5'drill pipe f/8500'-t/8210'-(vacuum OBM from pipe) 06:00 08:30 2.50 8.50 DRILL E 24 U Rig down time(Code 8)due to Nabors Columbia pipe skate stopped working-trouble shoot problem-change out proximity switch which did not resolve problem-Electrician and Mechanics think controls not receiving enough amps to operate hydraulic system. 08:30 13:00 4.50 13.00 DRILL E 4 U POOH with BHA#9-stand back 5"drill pipe in derrick f/8210'-U BHA @ 52'.Nabors continue to trouble shoot&work on Columbia pipe skate system. 13:00 13:30 0.50 13.50 DRILL A 4 U Work BHA\Clean 9 5/8"csg.brush&magnets-recovered 2.5 lbs.of metal shavings on this run(Total recovered 15 Ibs.)\M/U to RIH.Nabors trouble shooting and working on pipe skate. 13:30 16:30 3.00 16.50 DRILL E 4 U RIH f/52'-t/8029'\Up wL=150K,On wt.=75K\Working on pipe skate. 16:30 17:00 0.50 17.00 DRILL E 6 U Wash&ream f/8029'-U 8220'\pumping 415 gpm @ 940 psi.\35 rpm @ 6-8K torque\Up wt.=150K,Dn wt.=75K, Rot wt.=107K. 17:00 00:00 7.00 24.00 DRILL E 24 U Rig down time(Code 8)\Nabors Columbia pipe skate still broken down\Nabors senior field mechanic on location @ 1700 hrs;followed by senior field electrician and Columbia Rep.@ 1715 hrs.Found heat exchanger and ball valve isolating were bad-change hydraulic oil twice.Water in hydraulic oil system is plugging screen on solenoid of hydraulic valves,not allowing system to fully operate. 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 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Tool Push Bruce Simonson NAD Tool Pusher 907-670-8539 907-355-2278 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 4.892 L-80 8,493.9 16,920.0 9/9/2010 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) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 Eni E&P Division Well Name: OP05-06 ENI Petroleum Daily Report Well Code: 23985 • Field Name: Nikatchuq n Co. Inc. Date:9/16/2010 - Report#: 38 APIIUWI: en II Wellbore name: OP05-06 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM _ 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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) OP05-06 DRILLING 8/12/2010 17,080.0 51,685.00 152.28 339.4 35.94 Daily Information Depth End(RKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) FOB Temperature(°F) Weather Wind 17,035.0 3,993.6 8,627.00 86.0 39.9 Overcast.WC 34.9° 184°S @ 7.1 mph Daily summary operation 24h Summary Down time(Code 8)-Columbian pipe stake;Water contaminated hydraulic oil system,change oil and clean plugged screens on solenoid of hydraulic valves,replaced solenoid(broken wire)\ Wash/Ream f/8220'-t/8408';monitor well for 15 mins.\POOH-L/D 5"drill pipe f/8408'-U 3520'\Service rig&inspect pipe skate\POOH-UD 5"drill pipe f/3520'-U BHA @ 52'\Recovered 1 lb. metal,(Total recovered 16 lbs.)clean&LID BHA#10\Pull wear bushing&clear floor\P/U GBR&Baker Centrilift tools&equipment to rig floor,Hang ESP cable sheave in derrick-R/U chemical injection spool. Operation at 07.00 P/U ESP motor&seal assembly as per Baker Centrilift. Switched to Completion Phase AFE#4548 at 0000 hours 09-17-2010. 24h Forecast P/U Baker Centrilift ESP completion assembly&4 1/2"tbg. Uthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.10 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 24 U Rig down time(Code 8)-Columbia pipe skate(Nabors senior mechanic,electrician&Columbia Rep on location)\Third time to change hydraulic oil in tank,clean plugged screens on solenoid of hydraulic valves and repair wire.Function test and operational @ 0550 hrs.\Circulate well pumping at 320 gpm©600 psi. 06:00 07:30 1.50 7.50 DRILL E 6 U W ash/Ream f/8220'-t/8408'-415 gpm @ 990 psi.\35 rpm @ 6-7K torque\Up wt.=150K,Dn wt.=75K,Rot wt.=110K.\ Mud wt.@ 9.1 ppg.Monitor well for 15 minutes. 07:30 15:30 8.00. 15.50 DRILL E 4 U POOH-UD 5'drill pipe f/8408'-t/3520'-(vacuum OBM from pipe)\Up wt=135K,Dn wt.=80K 15:30 16:00 0.50. 16.00 DRILL E 25 U Service rig and inspect pipe skate. 16:00 20:00 4.00' 20.00 DRILL E 4 U POOH-L/D 5'drill pipe f/3520'-tBHA#10-(vacuum OBM from pipe). 20:00 21:00 1.00' 21.00 DRILL E 4 U Work BHA\Clean&L/D 9 5/8"csg.brush&magnets. Recovered 1 lbs.metal(mostly fines)(Total recovered 16 lbs.) 21:00 22:00 1.00 22.00 DRILL E 1 P Pull wear bushing-UD bushing,test plug and clear floor. 22:00 00:00 2.00 24.00 DRILL E 1 P Held PJSM\P/U GBR equipment&Baker Centrilift tools and equipment to rig floor. Hang ESP cable sheave in derrick\ R/U chemical injection spool. Switched to Completion Phase AFE#4548 at 0000 hours on 09-17-2010. 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 Eni representative David Smith ENI Drilling Spvr. 907-670-8623 907-632-3085 Eni representative Pete Adams ENI HSE Peter.Adams @enipetroleum.com 907-685-1227 Eni representative Bernie Leas ENI Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Alvin Criswell ENI Expediter Alvin.Criswell @enipetroleum.com 907-980-7545 Tool Push Bruce Simonson NAD Tool Pusher 907-670-8539 907-355-2278 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 4.892 L-80 8,493.9 16,920.0 9/9/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gal) P(Surf)(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 Eni E&P Division Well Name: OP05-06 fil* — ENI Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq • Co. Inc. Date:9/17/2010 - Report#: 1 APIIUWI: 2 n II Wellbore name: OP05-06 page l of t Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 12.20 0.00 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) OP05-06 COMPLETION 36.94 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 36.0 Fog.WC 33.1° 58°@ 4.4 mph Daily summary operation 24h Summary Finish R/U of Centrilift tools&equipment\P/U motor,tandem seals,TTC,&DGU as per Centrilift and Well Procedure,service/fill w/oil,check free rotation and perform electrical integrity test and WeIILift system check\RIH-P/U 4"ESP completion assembly f/144'-U 5058',checking electrical integrity test every 1000'\Incident damage ESP power cable-Informed town of incident-Prep ESP cable for gator splice&remove spool from house&spooler-Located 8000'reel and transported to rig on location @ 2340 hrs. Operation at 07.00 RIH-P/U 4 1/2"tbg.ESP completion assembly. 24h Forecast Continue RIH with 4 1/2"ESP Completion Asembly\P/U tbg.hanger&land\N/D BOPE&N/U tree Llthology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.10 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 COMP K 5 P Held PJSM\Finish R/U Centrilift equipment&chemical injection spool,load rig floor with clamps. 01:00 03:00 2.00 3.00 COMP K 5 P P/U motor-M/U aauae housina&motor cenirilizer service/fill with oil-check free rotation\P/U lower&upper seals& connect to motor,check free rotation&service/fill @ top of motor with oil. Confirm all fill,vent,and drain plugs properly installed&tightened. 03:00 04:00 1.00 4.00 COMP K 5 P POOH to WeIILift,install tech line to same&injection line to motor centralizer\RIH,connect MLE to motor pot head\ Performed electrical integrity test,motor&MLE(Meg phase to phase),also system check WellLift gauge,good.Installing Cannon&Christolizer clamps as per well procedure. 04:00 06:00 2.00 6.00 COMP K 5 P P/U TTC that standing back in derrick-connect to tandem seals,check free rotation,service/till with oil,confirm oil out of TTC intake vent holes-continue RIH installing clamps as well procedure-UD single used to stand back in derrick\P/U DGU on pups\P/U joint#2 of tally. 06:00 10:00 4.00 10.00 COMP K '5 P Conned tech line to DGU\Prep and make gator splice from MLE to ESP power cable\preformed electrical integrity test on motor/ESP cable-system check WeIILift all good\Install clamps as per well procedure. 10:00 19:00 9.00 19.00 COMP K 4 P P/U 4"tba.\RIH with ESP completion assembly as Per running tally f/144'-t/5058'-perform electrical integrity&WelIL'rft system check,every 1000'\Installing cannon as per running tally. 19:00 '00:00 5.00 24.00 COMP K -24 U Down time-after making electrical integrity&WellLift system test,ESP power cable was damaged @ spool house when starting to RIH. Operator pulled cable onto reel(unit in reverse)as though he was slacking cable to rig\Informed town of incident\Prep end to splice-remove reel from house&prep for new reel\Located another 8000'reel @ Milne Point (Alpha Pad)and transport to rig. On site @ 2340 hrs. Daily Contacts Position Contact Name Company Title E-mall Office Mobile Eni representative Jack Keener Eni Petroleum Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith Eni Petroleum Drilling Spvr. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Pete Adams Eni Petroleum HSE Peter.Adams @enipetroleum.com 907-685-1227 907-440-0806 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor @gmail.com 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(RKB) Bottom(RKB) Run Date LINER 51/2 4.892L-80 8,493.9 16,920.0 9/9/2010 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) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 Eni ESP Division Well Name: OP05-06 jDaily Report ENI Petroleum Y p Well Code: 23985 • Field Name: Nikatchuq �p Co. Inc. Date:9/18/2010 - Report#: 2 API/UWI: 211 11 II page 1 of 1 Wellbore name: OP05-06 Well Header - Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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(fiKB) Target Depth(TV... Depth Dr.(MD)(ft) Drilling Hours(hrs) Average ROP(ft/hr) DFS(days) OP05-06 COMPLETION 37.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ft/hr) POB Temperature("F) Weather Wind 85.0 37.0 Ptly Cloudy.Patchy 227°SW @ 1.8 mph Fog.WC 37° Daily summary operation 24h Summary Finish installing spool in house&connect ESP power cable together to pull to rig floor\RIH-f/5050'-V 5255'with 4.5"tbg.ESP completion\Centrilift gator splice ESP cable and tested @ spool I RIH -f/5336'-V 8132'with 4.5"tbg.ESP completion\P/U 4.5"VIT joints&pups f/8123'-V8213'\P/U hanger&landing joint\Centrilift made penetrator splice,installed in hanger and performed electrical integrity&WellLIft system test-good\Land tbg.-Vetco Gray tested lower&upper tbg.hanger\N/D BOP stack&riser\Stage tree components on rig floor while Centrilift retested penetrator. Operation at 07.00 RN manifold&lines to freeze protect well with Little Red 24h Forecast N/U tree&test\Freeze protect well I clean pits\R/D to move to 0111-01 well. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 Time Log Cum Start End Dur Dur Time Time (hrs) (hre) Phase Opr. Act. Plan _ Oper.Descr. 00:00 01:00 1.00 1.00'COMP K 24 U Finished installing new 8000'reel on spooler and spot in spooler house,connect ESP power cable together to pull to rig floor to make gator splice. 01:00 02:00 1.00 2.00 COMP K 4 U RIH-f/5050'-V 5255'1 P/U 4.5"tbg.with ESP completion assembly to position ESP power cable ends on rig floor for splice. 02:00 04:30 2.50 4.50•COMP K 5 P Centrilift made a gator splice on ESP power cable-splice landed @ 5271'tbg.depth,splice clamp installed-continue RIH to 5336'to put splice in fluid\Performed electrical integrity test&WeIILift system test-good. 04:30 09:30 ' 5.00 9.50 COMP K 4 P RIH-f/5336'-U 8132'1 P/U 4.5"tbg.with ESP completion as per tally-performing electrical integrity and WeIILift system test every 1000'\Installing cannon as per running tally. 09:30 11:00 1.50 11.00 COMP K 4 P R/U&P/U-XO pups&4.5"VIT joints(make-up 5K torque)-f/8123'-V 8213'1 P/U landing joint&tbg.hanger(BPV installed),make-up same to string.\Up wt.=115K,Dn wt.=60K. 11:00 14:30 3.50 14.50•COMP K 5 P Centrilift made penetrator splice&installed in hanger-performed electrical integrity and WeIILift system test-good\ Vetco Gray installed injection line through tbg.hanger\Drain BOP&blow down choke&kill lines,flush stack.R/D GBR tongs,injection line spooler,pull ESP cable back to spooler house&R/D sheave from derrick.\Make accurate account of clamps-2=Splice clamps\102=4.5"Cross collar clamps\5=5.5"clamps 11=4.5"x 5.5"clamps\1•4.5"Half clamp \3=Christolizer clamps\11=Equipment clamps. 14:30 '16:00 1.50 16.00'COMP K 12 P Land tba.hanger-Uo wt.118K.Dn wt.62K\Vetco Gray tested lower&upper seals to 5000 psi for 10 minultes.I MD landing joints\R/D 16:00 23:00 7.00 23.00 COMP K 5 P _ N/D 13 5/8"BOP-choke&kill line,remove bell nipple and set stack on stump\Pull riser&L/D. 23:00 00:00 ' 1.00 24.00 COMP K 5 P Centrilift performed electrical integrity&WeIILift system test-good\Stage Vetco Gray tree components @ rig floor while testing. Daily Contacts Position Contact Name Company Title E-mall Off c. Mock Eni representative Jack Keener Eni Petroleum Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith Eni Petroleum Drilling Spvr. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Pete Adams Eni Petroleum HSE Peter.Adams @enipetroleum.com 907-685-1227 907.440-0806 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor @gmail.com 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 1/2 4.892 L-80 8,493.9 16,920.0 9/9/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P(Surf)(psi) Eq.Mud Weight(113/gal) Leak Off Pressure(psi) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 VItikl Eni E&P Division Well Name: OPoS-06 EN!Petroleum Daily Report Well Code: 23985 Field Name: Nikatchuq (�n• Co. Inc. Date:9/19/2010 - Report#: 3 API/UWI: e n a page 1 of 1 Wellbore name: OP05-06 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 2100800 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.26 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(ftlhr) DFS(days) OP05-06 COMPLETION 38.94 Daily Information Depth End(ftKB) Depth End(TVD)(... Depth Progress(ft) Drilling Hours(hrs) Average ROP(ftlhr) POB Temperature(°F) Weather Wind 83.0 34.9 Overcast.WC 28° 1°N @ 8.4 mph Daily summary operation 24h Summary N/U tree-Test hanger void&tree to 5000 psi.for 10mins.-Centrilift final test on penetrator\R/U U-tube manifold to freeze protect well-pumped 150 bbls.high sulfur diesel-FCP 250 psi\U-tube balance well with 200 psi on tbg.&IA\Bleed back 3 bbls.off to 100 psi.on tubing and IA.\R/U Vetco Gray lubricator&set BPV-R/D lubricator\Blow down lines on the rig.\Release rig @ 1800 hrs.for move to 0111-01 well. Operation at 07.00 24h Forecast Rig move to well 0111-01. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log - _ Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 COMP K 5 P N/U tree as Per Vetco Gray-Test tba harmer void t/5000 psi f/10 minutes\Centrilift performed final test on penetrator\ Data:Intake Psi.=1796 psi.\Discharge Psi.=1790 psi\Intake Temp=80\Discharge Temp=80\Motor Temp=88\ Electrical Temp=80\Vibration X=0.054\vibration Y=0.054\System Current=11.85\System voltage=162\Phase A= 12\Phase 8=6\Phase C=12\4.4 Balance Phase to phase\Meg.=1600 ohms.Cleaning pits. 03:00 04:00 1.00 4.00 COMP K 12 P Vetco Gray remove BPV&install two-way check\Test tree to 5000 psi.f/10 minutes.Witness by ENI Rep.\Remove two-way check\Cleaning pits. 04:00 05:00 1.00 5.00 COMP K 5 P R/U U-tube manifold on tree to freeze protect well.Cleaning pits. r 05:00 09:00 4.00 9.00 COMP K 20 P Continue cleaning pits and circulate-pump Safe Surf-0 to flush all surface lines,mud cleaning equipment,pits,pumps (Mud&centrifugal)and stand pipe/Top drive. 09:00 12:00 3.00 12.00 COMP K 7 P R/U Little Red to freeze protect well\pressure test lines U 3500 psi.1 Sheared STS valve @ 2700 psi.with 1.8 bbls.down tbg.\Switch to annulus-pump 150 bbls.high sulfur diesel to surface.-Pumped 1 bbl/min @ 400 psi.w/return from tbg.- FCP @ 250 psi.ran through U-tube for 1 hr.\Well balanced with 200 psi.on tubing.&200 psi.on annulus. 12:00 14:00 2.00 14.00 COMP K _19 U Bleed back 3 bbls.off to 100 psi.on tubing and IA. 14:00 -16:00 2.00 16.00 COMP K 20 U P/U Vetco Gray lubricator set BPV\L/D lubricator 16:00 18:00 2.00 18.00 COMP A -2 P Blow down lines and freeze protect on rig,finish removing fluid from pits.release rig @ 1800 hrs.Work on stand pipe cut &remove section-weld on 1002 union half to install new section. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener Eni Petroleum Sr.Drilling Spvr. Jack.Keener @enipetroleum.com 907-670-8623 907-715-6434 Eni representative David Smith Eni Petroleum Drilling Spvr. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk Bernie.Leas @enipetroleum.com 907-670-8607 907-575-9427 Eni representative Pete Adams Eni Petroleum HSE Peter.Adams @enipetroleum.com 907-685-1227 907-440-0806 Eni representative Alvin Criswell Eni Petroleum Expediter eniexpeditor @gmail.com 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 L ast Casing seat Cas.Type OD(In) ID(in) Grade Top(fIKB) Bottom(ftKB) Run Date LINER 5 1/2 4.892 L-80 8,493.9 16,920.0 9/9/2010 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P(Surf)(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 8,671.0 3,833.83 VersaPro LS 8.70 673.0 12.08 2,405.7 r p7-I:) Zfc - ogv ENI Petroleum, OP05-06 Following is a brief field analysis of the log. First of all,the top of cement is 8150' determined qualitatively by the USIT MAP image and by CBL amplitude. The amplitude increases above 8150'. Low amplitudes are indicative of good cement. The cement quality is good. The green"microdebonding"effect seen on the USIT MAP image shows up on the bottom side of the pipe throughout the entire logging interval. We know that this effect is on the bottom of the pipe because the relative bearing in the GPIT corrects for tool rotation. The 3`d track on the composite image shows decreased amplitude on the low side of the pipe indicating that the microdebonding is actually on the inside of the pipe— which doesn't make sense. So,we theorized that particles of metal or sand or other debris was disrupting our ultrasonic waveforms. Everything else read well except for that green path. To test the theory we logged 2 passes higher in the well where the well would be most vertical. At 2500',the microdebonding was diminished as the inclination was around 45°versus 75°+. At 1000',with inclination less than 20°,the green had all but disappeared indicating that no debris was on the wall of the pipe. This confirmed that the culprit was most likely debris settling to the low side of the wellbore. In addition, there was a lot of"pepper"in the USIT MAP image and in the VDL image indicating particles floating in the borehole fluid. Finally, when the tool was retrieved,there were quite a bit of metal shavings stuck to our toolstring. So,the top of cement was 8150', and the cement quality below that was good. Josh Rybar Schlumberger. Page 1 of 3 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, September 14, 2010 9:33 AM +i7'—4.) 210— 020 To: 'Brink Jason' Subject: RE: OP05-06 Intermediate Cement Plan Going forward Jason, Thanks for the reply and spreadsheet. I think you have a good plan to mitigate the under-displacement for the upcoming wells as stated in your earlier email. Can you recheck the excess calculation ?? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Brink Jason [mailto:jason.brink @enipetroleum.com] Sent: Monday, September 13, 2010 6:13 PM To: Schwartz, Guy L (DOA) Subject: RE: OP05-06 Intermediate Cement Plan Going forward Guy I believe the plug was under displaced. Either the mud pumps were sucking air at some point or the pump efficiency was lower for some mechanical reason. Or, there was a valve open somewhere on the system and we weren't pumping all the volume down the casing. I cannot be sure which one it was but I am sure we basically under displaced the plug. I do not believe we bypassed the plug. I will attach the spreadsheet I put together to calculate the %washout considering we know the TOC and how much cement was placed in the IA. I calculated roughly 21%washout and assumed only 65 bbls were placed in the IA considering we tagged 1000' cement in the casing. We pumped a total of about 157 bbls cement. Jason Brink Drilling Engineer ENI Alaska Office: 907-865-3321 Cell: 907-947-3790 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz @alaska.gov] Sent: Monday, September 13, 2010 2:37 PM To: Brink Jason Subject: RE: OP05-06 Intermediate Cement Plan Going forward Jason, Can you be a little clearer on what you think actually happened? Do you think the top plug hung up and mud bypassed it or was the cement/plug just under displaced??? The volumes/TOC work out pretty close to what they should be if the plug held and the displacement was just stopped short by the rig pumps. The casing capacity is about .073 bbl/ft and the annular volume is very close to the same with 30% excess..... so if the top plug was tagged 1000' shallow that would explain at least 1000' that TOC was short. The other 500' that the TOC was shallow could be explained by washout. 9/20/2010 ti Page 2 of 3 Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Brink Jason [mailto:jason.brink @enipetroleum.com] Sent: Monday, September 13, 2010 10:46 AM To: Schwartz, Guy L(DOA) Subject: OP05-06 Intermediate Cement Plan Going forward Guy There could be one of two issues which caused our Intermediate Cement to be under displaced as follows: 1. Trucks supplying OBM, which was used to displace, were not fully supplying rig pumps with proper suction 2. Rig pump efficiency was lower than expected Going forward ENI plans to do the fol w ng to mitigate cement fill over the N sand: GN 1. Increase planned cement volume to 1000' over the N sand Ra. 2. Ensure rig pump efficiency by calibrating flow rate into the trip tank 3. Ensure percent excess is accurate (currently 25%) 4. Use Water based drilling mud already in pits to displace cement If there are any more questions please let me know. Jason Brink � „«Q -7-23 c e. 8( ~`b. Drilling Engineer ENI Alaska Gast v s4)f c- V47° MD Office: 907-865-3321 Cell: 907-947-3790 This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any 9/20/2010 Page 3 of 3 statements made or opinions expressed, that are not strictly related to the Company's operations. 9/20/2010 Well OP05-06 Hole Section Intermediate Casing OD Inches 9.625 Open Hole OD Inches 12.25 Actual Casing Depth Feet 8671 Planned Casing Depth Feet 8671 n Actual TOC MD (8150 _j 7b - Actual Cement Volume Behind Pipe bbls 65 r� GBL Actual Cement Height Feet 521 Actual Annular bbl/ft(with washout) bbl/ft 0.124760077 Annular BBL/FT (no washout) bbl/ft 0.055781888 Actual Gauge Hole Annular Volume bbls Planned Gauge Hole Annular Volume bbls Actual Cemented Annular Volume with Washout bbls 65 00 l C Actual Cemented Annular Volume without Washout bbls 29 i Washout Volume bbls 36 Actual Excess (washout%) 124% ` tJ 5,4-N 6 N sand target MD 7200 E__----' 500' Cement over N sand (Cement Volume) BBL 246 1000' Cement over N sand (Cement Volume) BBL 308 Sas a,_, 2r:,-(,- c4.Ic_ _ S"".`."' Page 1 of/ Maunder, Thomas E (DOA) From: Foerster, Catherine P(DOA) Sent: Sunday, September 12, 2010 2:50 PM To: Maunder, Thomas E (DOA) Cc: Schwartz, Guy L(DOA); Aubert, Winton G (DOA); Roby, David S (DOA); Davies, Stephen F (DOA) Subject: Re: ENI well OP05-06 ( PTD 210-080) Intermediate Casing cement I agree but we need to know what they intend to doto prevent recurrence of the problem. Sent from my iPhone On Sep 12, 2010, at 11:19 AM, "Maunder, Thomas E (DOA)" <tom.maunder@alaska.gov>wrote: ENI sent in the log this morning. They did achieve cement coverage over their primary sands, however the TOC is- 1000' below the N sand. What cement could be viewed does show to be good. The ENI engineer is suspecting that there were some pump problems on the rig that they weren't getting the output they thought so the cement was not lifted as high as they thought. Interesting that Nabors did some pump maintenance afterward. The change since Guy's original note is that no cement was placed anywhere near the N sand. I do not believe that alters the original consensus of the engineering staff that through time the solids in the mud will provide a seal. The sand is also marginal and ENI does not(at least now) plan to develop it. This situation is similar to the Qannik at Alpine. The sand was penetrated in the now developed area by a large number of the wells drilled from CD-2 and cement was rarely placed to cover the sand. I recommend that ENI not be required to conduct any remedial cementing operations on this well. Based on Cathy's message, I will notify ENI. Tom From: Foerster, Catherine P(DOA) Sent: Fri 9/10/2010 8:56 AM To: Schwartz, Guy L(DOA) Cc: Aubert, Winton G (DOA); Roby, David S(DOA); Maunder,Thomas E (DOA); Davies, Stephen F (DOA) Subject: RE: ENI well OP05-06 ( PTD 210-080) Intermediate Casing cement Thanks, Guy and friends. Tom, unless the CBL gives radically new information, I'm fine with the group's recommendation. From: Schwartz, Guy L(DOA) Sent: Thursday, September 09, 2010 3:12 PM To: Foerster, Catherine P (DOA) Cc: Aubert, Winton G (DOA); Roby, David S(DOA); Maunder,Thomas E (DOA); Davies, Stephen F (DOA) Subject: ENI well OP05-06 ( PTD 210-080) Intermediate Casing cement 9/13/2010 Page l of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E(DOA) Sent: Friday, September 10, 2010 10:39 AM To: Foerster, Catherine P(DOA); Schwartz, Guy L(DOA) Cc: Aubert,Winton G (DOA); Roby, David S (DOA); Davies, Stephen F (DOA) Subject: RE: ENI well OP05-06 ( PTD 210-080) Intermediate Casing cement Thank you. I have been in contact with the ENI engineer and we will discuss the log when it is available. From: Foerster, Catherine P(DOA) Sent: Friday, September 10, 2010 8:56 AM To: Schwartz, Guy L(DOA) Cc: Aubert, Winton G (DOA); Roby, David S (DOA); Maunder,Thomas E (DOA); Davies, Stephen F(DOA) Subject: RE: ENI well OP05-06 ( PTD 210-080) Intermediate Casing cement Thanks, Guy and friends. Tom, unless the CBL gives radically new information, I'm fine with the group's recommendation. From: Schwartz, Guy L(DOA) Sent: Thursday, September 09, 2010 3:12 PM To: Foerster, Catherine P(DOA) Cc: Aubert, Winton G (DOA); Roby, David S (DOA); Maunder,Thomas E (DOA); Davies, Stephen F(DOA) Subject: ENI well OP05-06 ( PTD 210-080) Intermediate Casing cement Cathy, I talked to Roby about the situation with this well regarding the intermediate casing cement. We all agree(Tom, Winton, Steve, Dave)that perforating the casing to do remedial cement squeezing is not the right thing to do. We would likely end up perforating several different depths in the attempt to circulate cement and end up permanently compromising the casing integrity. Their calculated TOC based on strokes is very close to the"N"sand zone already. Hopefully the TOC is above the"N"and if not we all feel that the Barite/solids in the drilling mud will ( if not already)settle over this zone and permanently pack it off. If by some very small chance the OA saw influx from this zone then a cement shoe could be pumped in the OA to remedy the situation anyway. The West Sak N sand is very marginal here ... only 4-6 ft of pay. We are going to required them to run the cement quality log (USIT and CBL sonic) regardless and use this data to determine TOC and analyze the casing for damage from drilling out the cement sheath. Also this will be useful in case the well is ever considered for injection service. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 9/13/2010 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, September 02, 2010 11:51 AM To: 'Brink Jason' Cc: Davies, Stephen F (DOA) Subject: RE: OP05-06 Intermediate Cement(PTD 210-080) Jason, As the N sand looks like a significant hydrocarbon zone in this well we need to proceed with the bond log. Once we get the cement evaluation log and determine if the N sand is covered we can discuss what steps we may want to pursue. Keep me posted on the progress... Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Brink Jason [mailto:jason.brink @enipetroleum.com] Sent: Thursday, September 02, 2010 10:18 AM To: Schwartz, Guy L(DOA) Subject: OP05-06 Intermediate Cement Guy This is a recap of the current situation for Producer OP05-06. Intermediate cement wiper plug did not bump on calculated strokes and was found +/-1000' above the float collar. The 9-5/8"was tested to 3000 PSI successfully. The LOT was as expected with 12.0 LOT and continuing to increase to 14.0 ppg EMW before shutting down. Worst case is that we have 1100' of cement fill in the annulus and did not cover the N sand hydrocarbon at 7200' MD. Plan forward: Run USIT and CBL on E-line to determine if we have cement at least across the N sand interval. Jason Brink Drilling Engineer ENI Alaska Office: 907-865-3321 Cell: 907-947-3790 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. 9/2/2010 E §.'5§ T O T O t O N O Af O 343 ;I m p ° q C P • E .m O o O o O O o O O o 91 IC s g� P r v O O O O O O O O O O® y v 3 n O Ili? fit E 2 R ■ - f O "TS Pressure(psi) 5 p 3 ,ozo I' < j o V I ; a § i i 1 1 1 1 $N ml, LIw 1 ° xwa o;a 00o a I i N m $ g r1 m m ` o a I g m 6? 7 8 W a Will s o E -Tu 8� {3 3 z b. a Oi N :°3f - 4 m m f p N ��i s O m° ;9,..-.1'11' y E 8 Cl) 3 .9 8.F.; - A 3 C m m Ws m §B§Bey 0 o —I €11§11 N o s m m z v a o '� 2- z c i x rn Fo m O ! , 2 c a :4 <` m 8 $$m P. Ilq, o O i a« m v Z=a N O poq x D m m Ki 0 -4 ac W. w3 v 0 o a a 2 a py q , �Bmm.iww.wN-°mE.-48 ° . ,m0,. o3 .. o co 2. E. N y &itt.°$Do"�", FF'k' 6{.�UaimrNLIVLIG3'="dmm.�mw.uN-°mmNO.w.wN,0 aa C -3 0 I0 0 y N w w w w w w-;:w w w .n4';Iaw w w w w w w w° m_ y g3 Nikaitchuq enn em us O erralinng OP05-06 Date: I Sep 1110 Report Time: i 04:00 Report 1t 21 API# 50-029-23427-00-00 I Spud Date: 8/12/2010 Planned TD: 17,046'MD/4,088'TVD Ground Elev I RTE 53.26' I Rig Name: Nabors 245E Location: Oliktok Point,North Slope,Alaska Geologist Sorin Cornea/Victor Iliescu Next Csg Pt. 8,671' Last Casing/Window i 95/8"intermediate casing set 8,671' Present Depth(MD)@ 5 A I 8,686' Previous Depth(MD) 8,686' 1 Footage Last 24 hrs f 0' Present Depth(TVD) 3,832' Fm @ Present Depth _ OA-Sand Present Activity Pressure testing casing Plan Ahead (Drill out the float collar and shoe,drill 20'of new hole,pull back up into the casing,perform an LOT. Current Operations Summary August 31 05:00-08:00 •P/U BHA#6 8 3 stands H W DP,circulate to perform surface lest of equipment. 08:00-10:00 Rig service. 10:00-14:30 TIH,tagged cement at 7,418'md. 1430-24:00 Drill up lop wiper plug and cement from 7,418'to 8,380'md. September 1 00:00-02:30 Drill up top wiper plug and cement from 8.380'to 8,562'md. 02:30-04:00 Pressure testing casing to 3,000 psi. Last survey Type MD INC AZ TVD TVDSS N/S E/W Vsect DU100 MWD Survey 8618.26 87.28 0.20 3830.35 -3777.09 2659.76 5388.12 4674.13 6.04 Extrapolation to TD 12 1/4" 8686.00 89.50 0.20 3832.25 -3778.99 2727.47 5388.36 4735.70 3.28 Lithology/Shows No new samples. Comments The TD 12 1/4"hole and 9 5/8"casing point TVD have been extrapolated past the last survey.They will be interpolated after drilling out.The tops below may be tweaked by town. Sensor distances:Inc-13.79'/GR-30.70'/PW D-32.73'/RES-36.36'/Surv-59.10'/Density-84.92'/Neutron-88.33'. , ,„ _ Contact Phone 8's:Geology:Sohn Cornea I Victor Itiescu 685.1224//Mudloggers 670-8529 Co-Man 670-8623//Directional Driller 670-8530//MWD 670-8527 Tops Marker I MD I INC i AZ I TVD I TVDSS i MD-prop i ND-prop I TVDSS-prog I d-te PROG I Comment 16"Surface Borehole 20"Conductor Shoe 160.0 0.0 0.0 160.0 -106./ 160.0 160.0 -106.8 -0.1 High to prog SV-4 712.0 9.0 108.0 710.5 -657.2 705.9 ' 705.7 -652.4 4.8 Low to prop SV-3 970.0 16.4 100.6 961.8 -908.5 ' 970.7 963.4 -910.1 -1.6 High to prog SV-2 1247.0 26.0 89.5 1221.2 -1167.9 1253.1 1226.8 -11735 -5.6 High to prop SV-1 1795.0 26.2 88.8 1709.6 -1656.3 1834.5 1731.8 -16785 -22.2 High to prog Permafrost Base 1879.0 27.4 87.7 1785.0 -1731.7 1890.2 1778.3 -1725.0 6.7 Low to prop Ugnu Top(UG4) 2195.0 42.8 83.3 2041.5 -1988.2 - 2230.6 2052.9 -1999.6 -11.4 High to prog 13 3/8"Casing Shoe 2415.6 51.0 83.2 2188.7 -2135.4 2409.1 2173.3 -2120.0 15.4 Low to prog TD 16"Surface Hole 2425.0 _ 51.0 _ 83.2 2194.6 -2141.3 2409.1 2173.3 -2120.0 21.3 Low to prog 121/4"Intermediate Borehole UG-2 Coal Bed Marker 3000.7 70.9 78.8 2489.6 -2436.3 3412.9 2530.4 -2477.1 -40.8 High to prog Lower Ugnu 6170.0 76.8 75.4 3196.2 -3142.9 6152.5 3201.1 -3147.8 -4.9 High to prog Fault Mauve Splay DTW 6998.0 73.9 47.3 3466.1 -3412.8 not expected n/a -2' Throw DTW N Sequence Top 7034.0 74.0 46.1 3476.0 -0327 7 not expected n/a Na n/a N-Sand Top 7198.0 75.1 40.2 3519.9 Na Na r/a Not expected Fault NikSE Mauve DTE 7245.0 _ 75.1 37.4 3532.1 -3478.8 7187.0 3188.4 -3435.1 -115' Throw DTE Schrader Bluff 7314.0 75.2 33.9 3549.6 -3496.3 7221.1 3498.6 -3445.3 51.0 Low to prog N Sequence Top 7517.0 75.4 24.3 3600.6 -3547.3 7403.8 3552.3 -3499.0 483 Low to prog N-Sand Top 7686.5 76.1 15.7 3643.5 -3590.2 7583.3 3605.0 , -3551.7 38.5 Low to prog N-Sand Base 7928.0 77.2 3.7 3695.8 -3642.5 7811.3 3666.8 -3613.5 29.0 Low to prog N Sequence Base 8140.0- 77.0 359.7 3743.6 -3690.3 8104.4 3714.0 -3660.7 29.6 Low to prog 0A-sb11 8427.0 79.5 0.5 3805.5 -3752.2 8373.6 3792.2 -3738.9 13.3 Low to prog 0A-6812 8500.0 81.3 0.6 3817.7 -3764.4 8540-0 3811.1 -3757.8 6.6 Low to prog OA-sbl3 8565.0 841 0.5 3826.3 -3773.0 Na Na n/a lira n/a 9 5/8"Casing Shoe 8671.0 D.2 3832.1 -3778.8 8613.6 3816.3 -3763.0 15.8 Low to prog 7D 12 1/4"Borehole 8686.0 _ 0.2 3832.3 -3779.0 8613.6 3816.3 -3763.0 16.0 Low to prop 12114"Intermediate Borehole PB1 Sidetrack Point 6239.0 73.2 782 3214.9 I -3161.7 n/a Na n/a Na could not TO.OP05-06-PB1 7036.2 74.4 68.6 3424.3 I -3371.0 n/a n/a n/a Nu turn AZ 81/2"Lateral Borehole TD 81/2"Borehole I I 17046.4 I 4073.0 I -4019.7 1 OA-Sand Concretions Concretions Concretions Top Base Thickness Formation Top Base Thickness Formation Total Thickness(feet)= 0 Total Number Concretions Drilled= 0 at OA Sand(intermediate 8 lateral sections. Average Thickness(feet)_ #DIV/01 . , Schlumberger Cementing Service Report 210- o 2 Customer Job Number ENI B67I-00103 Well Location(legal) Schlumberger Location Job Start OP05-06 Oliktok Point Prudhoe-Bay Aug/28/2010 Field Formation Name/Type Deviation Bit Size Well MD Well TVD Oliktok Point Clean-Sandstone 85 deg 12.3 in 8686.0 ft 3832.0 ft County Stab/Province Alaska BHP BHST BHCT Pore Press.Gradient Well Master API/UWI Psi 85 degF 65 degF lb/gal Rig Name Drilled For Service Via Ca•ing/finer Nabors 245E Oil Land Depth,ft Size,in Weight,lb/ft Grade Thread Offshore Zone Well Class Well Type 8671.0 9.6 47.0 110 BUTT New Development 0.0 0.0 0.0 Drilling Fluid Type Max.Density Plastic Viscosity Tubing/Drill Pipe Other 9.20 Ib/gal cP T/D Depth,ft Size,in Weight,lb/ft Grade Thread Service Line Job Type Cementing 9.625in Intermediate Max.Allowed Tub.Press Max.Allowed Ann.Press WH Connection Perforations/Open Hole psi psi Double Cement Head Top,ft Bottom,ft shot/ft No.of Shots Total Interval Service Instructions ft ft ft Cement 9-5/8"Intermediate Casing ft ft Diameter ft ft in Treat Down Displacement Packer Type Packer Depth Casing 629.0 bbl ft Tubing Vol. Casing Vol. Annular Vol. Openhole Vol. bbl 635.0 bbl bbl bbl Casing/Tubing Secured ❑ I Hole Vol.Circulated prior to Cement © Casing Tools Squeeze Job Lift Pressure Psi Shoe Type Float Squeeze Type Pipe Rotated ❑ Pipe Reciprocated © Shoe Depth 8671.0 ft Tool Type No.Centralizers Top Plugs 1 Bottom Plugs 1 Stage Tool Type Tool Depth ft Cement Head Type Double Stage Tool Depth ft Tail Pipe Size in Job Scheduled For Arrived on Location Leave Location Collar Type Float Tail Pipe Depth ft Aug/28/2010 12:00 Aug/28/2010 14:00 Aug/28/2010 23:00 Collar Depth 8585.0 ft Sqz.Total Vol. bbl Date Time Treating Flow Density Stage Total Rig Message 24-hr Pressure Rate LB/G Volume Volume Pressure dock PSI B/M BBL BBL PSI 08/28/2010 18:48:42 182 0.0 8.38 12.3 12.3 27 Check Rate Sensors on Pumps 08/28/2010 18:49:42 109 1.0 8.32 0.3 0.3 31 08/28/2010 18:50:42 118 1.3 8.35 0.8 0.8 31 08/28/2010 18:51:42 182 1.3 8.36 2.1 2.1 31 08/28/2010 18:52:42 251 4.7 8.35 5.1 5.1 31 08/28/2010 18:53:35 136 0.0 8.35 5.3 5.3 31 End Water 08/28/2010 18:54:42 127 0.0 8.35 5.3 5.3 31 08/28/2010 18:55:42 123 0.0 8.35 5.3 5.3 31 08/28/2010 18:56:42 686 0.0 8.35 5.3 5.3 31 08/28/2010 18:56:43 681 0.0 8.36 5.3 5.3 36 Low Pressure Test 08/28/2010 18:57:42 631 0.0 8.35 5.3 5.3 31 08/28/2010 18:58:42 3744 0.0 8.36 5.3 5.3 31 08/28/2010 18:58:53 4078 0.0 8.35 5.3 5.3 36 High Pressure Test 08/28/2010 18:59:42 4041 0.0 8.35 5.3 5.3 31 08/28/2010 19:00:03 4032 0.0 8.35 5.3 5.3 31 Total water Ahead=5 bbls 08/28/2010 19:00:42 100 0.0 8.36 0.0 5.3 36 08/28/2010 19:01:42 95 0.0 8.36 0.0 5.3 36 08/28/2010 19:02:42 95 0.0 8.35 0.0 5.3 31 08/28/2010 19:03:42 118 0.6 8.35 0.1 5.4 36 08/28/2010 19:03:44 127 0.9 8.35 0.1 5.4 31 Start Pumping MudPUSH 08/28/2010 19:04:42 466 4.7 10.49 2.6 7.9 31 Page 1 of 5 I Well Field lob Start Customer lob Number OP05-06 Oliktok Point Aug/28/2010 ENI B67I-00103 Date Time Treating Flow Density Stage Total Rig Message 24-hr Pressure Rate LB/G Volume Volume Pressure clock PSI B/M BBL BBL PSI 08/28/2010 19:06:42 466 5.0 10.50 12.5 17.8 31 08/28/2010 19:07:42 471 5.1 10.50 17.5 22.8 31 08/28/2010 19:08:42 471 5.1 10.50 22.6 27.9 31 08/28/2010 19:09:42 457 5.1 10.48 27.7 32.9 31 08/28/2010 19:10:42 448 5.0 10.48 32.7 38.0 36 08/28/2010 19:11:42 448 5.0 10.50 37.8 43.1 31 08/28/2010 19:12:42 448 5.1 10.50 42.9 48.1 36 08/28/2010 19:13:42 434 5.1 10.50 48.0 53.2 36 08/28/2010 19:14:42 434 5.1 10.50 53.1 58.3 36 08/28/2010 19:15:42 434 5.2 10.50 58.2 63.5 36 08/28/2010 19:16:42 429 5.1 10.51 63.3 68.6 36 08/28/2010 19:17:42 429 5.2 10.51 68.4 73.7 36 08/28/2010 19:18:42 425 5.1 10.50 73.5 78.8 36 08/28/2010 19:18:59 104 0.3 10.32 74.6 79.9 36 End MudPUSH 08/28/2010 19:19:42 104 0.0 10.47 74.6 79.9 36 08/28/2010 19:20:42 109 0.0 i 10.50 74.6 79.9 36 08/28/2010 19:21:09 146 0.0 10.32 74.6 79.9 36 Total MudPUSH=75 bbls 08/28/2010 19:21:21 141 0.0 10.24 0.0 79.9 36 Release Bottom Plug 08/28/2010 19:21:42 136 0.0 9.76 0.0 79.9 36 08/28/2010 19:22:42 132 0.0 8.41 0.0 79.9 36 08/28/2010 19:23:36 127 0.0 8.73 0.0 79.9 36 Start Mixing 12.5 ppg DeepCrete 08/28/2010 19:23:42 132 0.0 9.03 0.0 79.9 36 08/28/2010 19:24:42 127 0.0 10.90 0.0 79.9 36 08/28/2010 19:25:42 123 0.0 12.31 0.0 79.9 31 08/28/2010 19:26:42 109 0.0 12.52 0.0 79.9 36 08/28/2010 19:27:42 109 0.0 12.54 0.0 79.9 36 08/28/2010 19:28:42 109 0.0 12.57 0.0 79.9 36 08/28/2010 19:29:42 109 0.0 12.60 0.0 79.9 36 08/28/2010 19:29:46 109 0.0 12.61 0.0 79.9 36 Checking Density with Mud Balance 08/28/2010 19:30:42 132 1.8 12.63 0.1 80.0 36 08/28/2010 19:30:43 132 1.8 12.63 0.1 80.0 36 Start Pumping Cement Downhole 08/28/2010 19:31:42 278 1.6 12.36 1.8 81.7 36 08/28/2010 19:32:42 411 2.7 12.43 4.0 83.9 36 08/28/2010 19:33:42 686 3.8 11.92 7.6 87.5 36 08/28/2010 19:34:42 580 3.9 12.30 11.4 91.3 36 08/28/2010 19:35:42 745 5.2 11.82 16.0 96.0 36 08/28/2010 19:36:42 818 5.2 11.86 21.2 101.1 36 08/28/2010 19:37:42 818 5.0 11.89 26.3 106.2 36 08/28/2010 19:38:42 709 2.0 18.24 31.1 111.0 36 08/28/2010 19:39:42 773 5.0 12.02 36.0 115.9 36 08/28/2010 19:40:42 727 5.0 11.89 40.8 120.7 36 08/28/2010 19:41:42 796 4.8 11.91 45.8 125.7 36 08/28/2010 19:42:42 521 3.8 12.04 50.5 130.4 36 08/28/2010 19:43:42 493 3.7 12.11 54.3 134.2 36 08/28/2010 19:44:42 526 3.9 11.95 58.1 138.0 40 08/28/2010 19:45:42 439 3.8 12.05 61.8 141.7 36 08/28/2010 19:46:42 411 3.8 11.85 65.6 145.5 36 08/28/2010 19:47:42 503 3.7 12.12 69.4 149.3 36 08/28/2010 19:48:42 526 3.9 11.81 73.2 153.1 36 08/28/2010 19:49:42 471 3.8 12.15 77.0 156.9 36 08/28/2010 19:50:42 535 3.8 12.40 80.8 160.8 36 08/28/2010 19:51:42 397 2.9 11.63 84.5 164.4 36 08/28/2010 19:52:42 521 3.7 12.28 88.2 168.2 40 08/28/2010 19:53:42 535 3.5 12.44 92.0 171.9 36 Page 2 of 5 Well Field Job Start Customer lob Number OP05-06 Oliktok Point Aug/28/2010 ENI B67I-00103 Date Time Treating Flow Density Stage Total Rig Message 24-hr Pressure Rate LB/G Volume Volume Pressure clock PSI B/M BBL BBL PSI 08/28/2010 19:55:42 544 3.9 11.98 99.6 179.5 36 08/28/2010 19:56:42 548 3.8 12.37 103.3 183.3 36 08/28/2010 19:57:42 530 3.6 11.93 107.0 187.0 36 08/28/2010 19:58:42 471 3.7 11.98 110.7 190.6 36 08/28/2010 19:59:42 516 3.8 12.23 114.4 194.3 36 08/28/2010 20:00:42 535 3.9 11.92 118.2 198.1 36 08/28/2010 20:01:42 539 3.6 12.37 122.0 202.0 36 08/28/2010 20:02:42 535 3.9 12.08 125.9 205.8 36 08/28/2010 20:03:42 526 3.9 12.21 129.7 209.6 36 08/28/2010 20:04:42 539 3.8 12.22 133.5 213.4 36 08/28/2010 20:05:42 512 3.7 12.21 137.3 217.2 36 08/28/2010 20:06:42 512 3.7 12.23 141.0 220.9 36 08/28/2010 20:07:42 498 3.7 11.80 144.8 224.7 36 08/28/2010 20:08:42 457 3.7 12.00 148.6 228.5 36 08/28/2010 20:09:42 146 0.0 12.50 149.0 228.9 36 08/28/2010 20:10:30 251 1.8 12.61 149.5 229.4 36 Stop Pumping,Get Density Up 08/28/2010 20:10:42 260 1.7 12.62 149.8 229.7 36 08/28/2010 20:11:42 246 1.7 12.69 151.5 231.4 36 08/28/2010 20:12:36 100 0.0 11.94 152.5 232.4 36 Stop Pumping,Batch Another Tub 08/28/2010 20:12:42 100 0.0 12.21 152.5 232.4 36 08/28/2010 20:13:42 100 0.0 11.66 152.5 232.4 36 08/28/2010 20:14:42 237 1.7 12.44 152.7 232.6 36 08/28/2010 20:15:42 320 2.6 12.49 155.1 235.0 36 08/28/2010 20:16:42 95 0.0 12.56 157.5 237.4 36 08/28/2010 20:16:45 95 0.0 12.56 157.5 237.4 36 End Cement Slurry 08/28/2010 20:17:42 95 0.0 12.56 157.5 237.4 36 08/28/2010 20:18:42 132 0.0 12.60 157.5 237.4 36 08/28/2010 20:19:11 132 0.0 12.61 157.5 237.4 36 Reset Total,Vol=162.99 bbl 08/28/2010 20:19:22 150 0.0 12.61 0.0 237.4 36 Drop Top Plug 08/28/2010 20:19:30 114 0.2 12.59 0.0 237.4 36 Pump Water Behind 08/28/2010 20:19:42 127 0.7 10.11 0.1 237.5 36 08/28/2010 20:20:42 388 5.2 8.38 3.5 240.9 36 08/28/2010 20:21:41 146 0.0 8.37 5.2 242.5 36 Shut Down Cement Pump 08/28/2010 20:21:50 146 0.0 8.37 5.2 242.5 36 Switch to Rig Pumps 08/28/2010 20:22:42 141 0.0 8.37 5.2 242.5 187 08/28/2010 20:23:42 141 0.0 8.37 5.2 242.5 242 08/28/2010 20:24:42 191 0.0 8.38 5.2 242.5 223 08/28/2010 20:25:42 127 0.0 8.38 5.2 242.5 214 08/28/2010 20:26:42 127 0.0 8.37 5.2 242.5 191 08/28/2010 20:27:42 123 0.0 8.38 5.2 242.5 187 08/28/2010 20:28:42 123 0.0 8.38 5.2 242.5 173 08/28/2010 20:29:42 146 0.0 8.38 5.2 242.5 155 08/28/2010 20:30:42 77 0.0 8.38 5.2 242.5 164 08/28/2010 20:31:42 77 0.0 8.38 5.2 242.5 173 08/28/2010 20:32:42 77 0.0 8.38 5.2 242.5 182 08/28/2010 20:33:42 132 0.0 8.38 5.2 242.5 191 08/28/2010 20:34:42 123 0.0 10.23 5.2 242.5 182 08/28/2010 20:35:42 123 0.0 11.79 5.2 242.5 214 08/28/2010 20:36:42 123 0.0 12.34 5.2 242.5 191 08/28/2010 20:37:42 123 0.0 12.59 5.2 242.5 205 08/28/2010 20:38:42 118 0.0 12.41 5.2 242.5 191 08/28/2010 20:39:42 118 0.0 11.94 5.2 242.5 187 08/28/2010 20:40:42 118 0.0 11.72 5.2 242.5 191 08/28/2010 20:41:42 118 0.0 12.55 5.2 242.5 201 Page 3 of 5 • Well Field Job Start Customer Job Number 0P05-06 Oliktok Point Aug/28/2010 EN] 867I-00103 Date Time Treating Flow Density Stage Total Rig Message 24-hr Pressure Rate LB/G Volume Volume Pressure dock PSI B/M BBL BBL PSI 08/28/2010 20:43:42 118 0.0 8.41 5.2 242.5 219 08/28/2010 20:44:42 118 0.0 8.15 5.2 242.5 219 08/28/2010 20:45:42 123 0.0 8.20 5.2 242.5 274 08/28/2010 20:46:42 109 0.0 -3.11 5.2 242.5 306 08/28/2010 20:47:42 109 0.0 7.22 5.2 242.5 265 08/28/2010 20:48:42 118 0.0 8.09 5.2 242.5 292 08/28/2010 20:49:42 100 0.0 8.26 5.2 242.5 329 08/28/2010 20:50:42 100 0.0 8.02 5.2 242.5 333 08/28/2010 20:51:42 118 0.0 8.08 5.2 242.5 333 08/28/2010 20:52:42 114 0.0 7.75 5.2 242.5 310 08/28/2010 20:53:42 114 0.0 8.35 5.2 242.5 356 08/28/2010 20:54:42 114 0.0 8.35 5.2 242.5 361 08/28/2010 20:55:42 114 0.0 8.37 5.2 242.5 370 08/28/2010 20:56:42 109 0.0 8.36 5.2 242.5 370 08/28/2010 20:57:42 100 0.0 8.16 5.2 242.5 370 08/28/2010 20:58:42 100 0.0 8.33 5.2 242.5 356 08/28/2010 20:59:42 100 0.0 8.34 5.2 242.5 352 08/28/2010 21:00:42 100 0.0 8.33 5.2 242.5 388 08/28/2010 21:01:42 100 0.0 8.33 5.2 242.5 406 08/28/2010 21:02:42 100 0.0 8.33 5.2 242.5 393 08/28/2010 21:03:42 100 0.0 8.32 5.2 242.5 384 08/28/2010 21:04:42 100 0.0 8.32 5.2 242.5 374 08/28/2010 21:05:42 109 0.0 8.31 5.2 242.5 397 08/28/2010 21:06:42 109 0.0 8.33 5.2 242.5 388 08/28/2010 21:07:42 109 0.0 8.36 5.2 242.5 370 08/28/2010 21:08:42 109 0.0 6.97 5.2 242.5 370 08/28/2010 21:09:42 109 0.0 0.14 5.2 242.5 370 08/28/2010 21:10:42 109 0.0 0.01 5.2 242.5 397 08/28/2010 21:11:42 109 0.0 0.01 5.2 242.5 379 08/28/2010 21:12:42 68 0.0 0.01 5.2 242.5 338 08/28/2010 21:13:42 68 0.0 6.09 5.2 242.5 374 08/28/2010 21:14:42 72 0.0 8.38 5.2 242.5 347 08/28/2010 21:15:42 72 0.0 8.70 5.2 242.5 388 08/28/2010 21:16:42 77 0.0 8.60 5.2 242.5 379 08/28/2010 21:17:42 100 0.0 8.32 5.2 242.5 393 08/28/2010 21:18:42 81 0.0 8.25 5.2 242.5 379 08/28/2010 21:19:42 72 0.0 8.29 5.2 242.5 370 08/28/2010 21:20:42 77 0.0 8.37 5.2 242.5 397 08/28/2010 21:21:42 72 0.0 8.35 5.2 242.5 361 08/28/2010 21:22:42 72 0.0 8.36 5.2 242.5 352 08/28/2010 21:23:31 118 0.0 8.35 5.2 242.5 370 MudPUSH at Shoe 08/28/2010 21:23:42 104 0.0 8.35 5.2 242.5 374 08/28/2010 21:24:42 141 0.0 8.36 5.2 242.5 356 08/28/2010 21:25:42 86 0.0 8.38 5.2 242.5 356 08/28/2010 21:26:42 104 0.0 8.38 5.2 242.5 315 08/28/2010 21:27:42 141 0.0 8.37 5.2 242.5 338 08/28/2010 21:28:42 72 0.0 7.78 5.2 242.5 297 08/28/2010 21:29:42 68 0.0 8.37 5.2 242.5 342 08/28/2010 21:30:42 72 0.0 8.22 5.2 242.5 329 08/28/2010 21:31:42 68 0.0 8.25 5.2 242.5 301 08/28/2010 21:32:42 68 0.0 8.25 5.2 242.5 397 08/28/2010 21:33:42 68 0.0 8.25 5.2 242.5 388 08/28/2010 21:34:42 63 0.0 8.24 5.2 242.5 356 08/28/2010 21:35:42 68 0.0 8.23 5.2 242.5 361 Page 4 of S Well Field lob Start Customer Job Number OP05-06 Oliktok Point Aug/28/2010 ENI B67I-00103 Date Time Treating Flow Density Stage Total Rig Message 24-hr Pressure Rate LB/G Volume Volume Pressure clock PSI B/M BBL BBL PSI 08/28/2010 21:36:42 68 0.0 8.23 5.2 242.5 384 08/28/2010 21:37:42 63 0.0 8.28 5.2 242.5 361 08/28/2010 21:38:42 352 0.0 8.29 5.2 242.5 361 08/28/2010 21:39:42 136 0.0 8.35 5.2 242.5 379 08/28/2010 21:40:42 109 0.0 8.35 5.2 242.5 397 08/28/2010 21:41:42 86 0.0 8.36 5.2 242.5 402 08/28/2010 21:42:42 100 0.0 8.15 5.2 242.5 361 08/28/2010 21:43:42 136 0.0 8.22 5.2 242.5 370 08/28/2010 21:44:42 187 0.0 8.10 5.2 242.5 402 08/28/2010 21:45:42 72 0.0 7.74 5.2 242.5 397 08/28/2010 21:46:42 72 0.0 8.37 5.2 242.5 411 08/28/2010 21:47:42 132 0.0 8.35 5.2 242.5 406 08/28/2010 21:48:42 104 0.0 7.83 5.2 242.5 411 08/28/2010 21:49:42 68 0.0 7.86 5.2 242.5 416 08/28/2010 21:50:42 63 0.0 8.10 5.2 242.5 379 08/28/2010 21:51:42 63 0.0 8.13 5.2 242.5 370 08/28/2010 21:52:42 68 0.0 8.36 5.2 242.5 411 08/28/2010 21:53:42 63 0.0 8.36 5.2 242.5 402 08/28/2010 21:54:42 63 0.0 8.36 5.2 242.5 384 08/28/2010 21:55:42 132 0.0 1.35 5.2 242.5 439 08/28/2010 21:56:42 72 0.0 0.74 5.2 242.5 416 08/28/2010 21:57:42 63 0.0 0.01 5.2 242.5 448 08/28/2010 21:58:42 81 0.0 0.01 5.2 242.5 342 08/28/2010 21:59:19 63 0.0 0.01 5.2 242.5 310 Reduce Rate to Bump Plug 08/28/2010 21:59:42 59 0.0 0.01 5.2 242.5 306 08/28/2010 22:01:42 59 0.0 0.01 5.2 242.5 320 08/28/2010 22:03:42 77 0.0 0.05 5.2 242.5 182 08/28/2010 22:04:42 68 0.0 0.01 5.2 242.5 370 08/28/2010 22:05:42 59 0.0 7.47 5.2 242.5 191 08/28/2010 22:05:51 59 0.0 0.09 5.2 242.5 201 Shut Down,Check Numbers 08/28/2010 22:06:42 81 0.0 0.06 5.2 242.5 338 08/28/2010 22:07:42 77 0.0 0.03 5.2 242.5 361 08/28/2010 22:08:42 77 0.0 0.01 5.2 242.5 356 08/28/2010 22:09:42 59 0.0 0.01 5.2 242.5 205 08/28/2010 22:10:42 77 0.0 0.01 5.2 242.5 150 08/28/2010 22:10:57 72 0.0 0.01 5.2 242.5 118 Shut Down,Plug Did Not Bump Post Job Summary Ij Average Pump Rates,bbl/min Volume of Fluid Injected,bbl Slurry N2 Mud Maximum Rate Total Slurry Mud Spacer N2 3.8 5.4 157.5 0.0 75.0 Treating Pressure Summary,psi Breakdown Fluid Maximum Final Average Bump Plug to Breakdown Type Volume Density 4091 59 211 0 bbl 9.20 lb/gal Avg.N2 Percent Designed Slurry Volume Displacement Mix Water Temp Cement Circulated to Surface? 0 Volume bbl % 150.0 bbl 629.0 bbl 77 degF Washed Thru Perfs ❑ To ft Customer or Authorized Representative Scchlumberger Supervisor Circulation Lost 0 lob Completed El ENI Steve Abbott Page 5 of5 Schlumberger Cementing Job ..eport CemCATv1.4 Well OP05-06 Client ENI Field Oliktok Point SIR No. B67I-00103 Engineer Steve Abbott Job Type 9.625in Intermediate Country United States Job Date 08-28-2010 Time Pressure Rate Density Rig floor Messages 08/28/2010 17:21,42 17:21:42 y � J Check Rate Sensors on Pumps Pumps and Rate Sensors Match 17:42:00 18:02:00 18:22:00 18:42:00 = r Pump 5 bbls of Fresh Water to Fil End Water Low Pressure Test 19:02:00 High Lo Pressure Test Total water Ahead=5 bbls Start Pumping MudPUSH 19:22:00 End MudPUSH Total MudPUSH=75 bbls Release Bottom Plug Start Mixing 12.5 ppg DeepCrete Checking Start Pump ng' n Cement Downhole 19:42:00 20:02:00 • Stop Pumping,Get Density Up ',. Stop Pumoina.Batch Another Tut End Cement Slurry III 20:22:00 Reset Total,Vol=162.99 bbl Drop Top Plug Pump Water Behind Shut Down Cement Pump Switch to Rig Pumps 20:42:00 21:02:00 •■•J 21:22:00 ::::::t:::oe(4632 stroke 21:42:00 • 22:02:00 Reduce Rate to Bump Plug • Shut Down,Check Numbers 22:11:34 Shut Down,Plug Did Not Bump Open Up,Bleed Back,Check Floal hh:mm:ss 0.00 625 1250 1075 2500 3125 3750 1375 5000 0.00 1.0 2.0 3.0 4.0 5.0 5.0 10.0 15.0 20.0 25.0 0.00 625 1250 1875 2500 3125 3750 1375 5000 011/2201022:11:34 PSI B/M LB/G PSI 08/28/2010 22:18:02 Page 1 of 2 Schwartz, Guy L (DOA) From: Brink Jason [jason.brink @enipetroleum.com] Sent: Thursday, August 26, 2010 10:18 AM To: Schwartz, Guy L(DOA) Subject: RE: OP05-06 (PTD 210-080) Guy Our exceed rotary steerable was not able to achieve the required DLS to steer the wellpath from Northeast to North. The new projection would have moved the intersection of the OA reservoir closer to the unit boundary; therefore, ENI posed the question to land Intermediate casing closer to the boundary. In the end, ENI sidetracked and are back on the original planned wellpath. Thanks for looking into this issue for ENI. Jason Brink Drilling Engineer ENI Alaska Office: 907-865-3321 Cell: 907-947-3790 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, August 26, 2010 8:48 AM To: Brink Jason Subject: RE: OP05-06 (PTD 210-080) Jason, Can you still send me a quick paragraph outlining what happened (pertaining to how and why the drilling got off target) for a record. I never got anything back from you all. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Brink Jason [mailto:jason.brink @enipetroleum.com] Sent: Friday, August 20, 2010 4:33 PM To: Schwartz, Guy L(DOA) Subject: RE: OP05-06 (PTD 210-080) Thanks Guy. We will set casing per the permitted plan. Jason Brink Drilling Engineer ENI Alaska Office: 907-865-3321 Cell: 907-947-3790 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, August 20, 2010 10:30 AM To: Brink Jason; Kuck Marc Cc: Aubert, Winton G (DOA); Maunder,Thomas E (DOA); Ballantine,Tab A (LAW); Davies, Stephen F (DOA) 8/26/2010 Page 2 of 2 Subject: RE: OP05-06 (PTD 210-080) Jason, After discussion, the Commission is agreeable with ENI's proposal to continue drilling and landing the intermediate casing with 500' of the lease line. A spacing exception will have to be applied for and a public hearing scheduled. There is a slim possibility that the hearing will bring up issues that would cause the exception to be denied. As you stated Conoco already has 300' spacing in place to external boundaries for the West Sak Reservoir(CO 406) . We still need a written explanation of what happened so we have a complete documentation. I am leaving the office this afternoon and will be out of town for the weekend so please follow-up with Winton if needed. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L (DOA) Sent: Friday, August 20, 2010 9:51 AM To: 'Brink Jason' Subject: OP05-06 (PTD 210-080) Jason, We are waiting for a return call from our Lawyer... can you send me an email outlining the issue so I have it in writing. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. 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. 8/26/2010 sian tAsEA SEAN PARNELL,GOVERNOR 0 ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Maurizio Grandi Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Undefined Oil Pool, OP05-06 ENI US Operating Co. Inc. Permit No: 210-080 Surface Location: 3212.4' FSL, 1547.6' FEL, S5, T13N, R9E, UM Bottomhole Location: 3743' FSL, 1670' FEL, S28, T14N, R9E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. /1,, Chair DATED this ?'vday of June, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED if* JUN 1 5 2010 • Emil IPketroHeuinni Alaska Oil Fi Gas Corn.COmmiSSion Anchouge 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi @enipetroleum.com June 10,2010 Alaska Oil and Gas Conservation Commission 333 West 76 Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer OP05-06 Dear Commissioners, ENI US Operating Co.Inc.hereby applies for a Permit to Drill for the onshore production well OP05-06. The well will be drilled and completed using Nabors rig 245E. The planned spud date is 7/22/2010 contingent upon the Commission's spacing exception decision for OP 12-01 (permit request previously submitted). If OP12-01 is granted spacing exception,then spud date for OP05-06 will be 8/26/2010. 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, clitsuiv\ Maurizio Grandi Well Operation Project Manager RECEIVED STATE OF ALASKA JUN 1 5 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil&Car Cons.Commission 20 MC 25.005 Anchl�c� e1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil El • Service- Wnj E] Single Zone ❑ 1 c.Specify if we is proposed for: Drill al • Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory El Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 • Single Well ❑ 11.Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627 • OP05-06 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 17080' TVD: 4088' • Nikaitchuq• 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3212.4'FSL 1547.6'FEL S5 T13N R9E UM . ADL 355024,373301,390615 3577;6-2- Top of Productive Horizon: 8.Land Use Permit: l 1" rS,ft 13.Approximate Spud Date: 561'FSL, 1421'FEL,S33 T14N R9E UM ADL 417493 7/22/2010 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3743'FSL 1670'FEL 28 T14N R9E UM 1280 561'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- 516732 • y- 6036566 • Zone- 4 GL Elevation above MSL: • 12 feet to Same Pool: 2665'West to OP03-P05 16.Deviated wells: Kickoff depth: 350 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90° degrees Downhole: 1671 psig • Surface: 1253 psig • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole . Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" _ 178.89 X-65 Welded 84 36 36 120 120 pre-installed 16" 13-3/8" 68 L-80 BTC 2408 35 35 2408 2173 436 sx 10.7#ASL,213 sx 12.0#Deeperete 12.25" 9-5/8" 47 L-80 BTCM 8617 33 33 8617 3801 367 sx 12.5#Deeperete 8.5" 5.5" 17 L-80 DWC 8663 8417 3782 17080 4088 Slottled liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD 11 Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 BOP Sketch El Drilling Program El Time v.Depth Plot ❑ Shallow Hazard Analysis la Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Jason Brink @ 907-865-3321 Printed Name Maurizio Grandi ► \ Title Well Operation Project Manager Signature . ^A t Phone Date 6/i f Ito Commission Use Only r1 l Permit to Drill z/��. API Number: ,/ . Permit A rov I///��c*� See cover letter for other Number: �v 50� Z J 7 Date: ��/� ,' O requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 2-- Other: ,( 3506 os �e j 5•f- Samples req'd: Yes❑ No[ Mud log req'd: Yes ❑ No [v]' . Z.SOO I e$` A..„.1...., --f'3+ / yh\ H2S measures: Yes❑ No[✓1 Directional svy req'd: Yes [] No ❑ - jv („jaaVJ PQ'sc Zo` AAC ZSo3.5(11)(z) (o/ d 00 P %s/- c c /3o 0 / APPROVED BY THE COMMISSION 1 DATE: AIL ,COMMISSIONER ORIGINAL , z1Ioe_;C;e .■ /sip Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate Iwo jos_ Oliktok Point Nikaitchuq Field 2no il petroleum OP05-06 (P4) Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle X-65 0° 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res 'v Surface Cso Dir v 13-3/8" va Base Permafrost 1,900' 1,778' > 68 lbs/ft MW(ppg) Wellbore Stability in Mud Motor 1– L-80,BTC 8.8-9.5 Lost Circulation Hole Cleaning KOP:350' DLS: I 1.5-4.5 deg/100' o v v m 0 m m v Hole Angle n S 51 13-3/8"Casing Point 2,408' 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: 77 degrees III Sitill N N •"N"Sand Top 7,715' 3,600' ' — v Co ,x,— m o CD m TOL 8,417' m m m m Hole Angle ..,4 87 9-5/8"Casing Point 8,617' 3,801' 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 85 TD/5-1/2"Lnr 17,080' 4,088' 8-1/2" 85"F MOBM r°1111 Ant EIM Application for Permit to Drill Well OP05-06 Saved: 11-Jun-10 Application for Permit to Drill Document Producer Well OP05-06 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 (MI VersaPro LS Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 10.Seismic Analysis 6 Requirements of 20 AAC 25.005(c)(10) 6 11.Seabed Condition Analysis 6 OP05-06 PERMIT Document.doc Page 1 of 7 Printed: 11-Jun-10 Ent Petirolleuim •_ent Application for Permit to Drill Well OP05-06 Saved: 11-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(0 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: OP05-06 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 3212.4' FSL 1547.6' FEL S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 53.2'AMSL Northings 6,036,565.72' Eastings: 516,732.25' Pad Elevation 12'AMSL Location at Top of Productive Interval 561' FSL, 1421' FEL, S33 T14N R9E UM ("OA"Sand) OP05-06 PERMIT Document.doc Page 2 of 7 Printed: 11-Jun-10 Rat EnD Pketirolleurn Application for Permit to Drill Well OP05-06 Saved: 11-Jun-10 ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 8567' Northings: 6,039,206.60' Eastings:522,124.87' Total Vertical Depth, RKB: 3797' Total Vertical Depth, 55: 3745' Location at Total Depth 3743' FSL 1670' FEL 28 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 17080' Northings: 6,047,669.00' Eastings: 521,831.00' Total Vertical Depth, RKB: 4088' Total Vertical Depth, 55: 4035' Please see Attachment 7: Surface Platt and (D)other information required by 20 MC 25.050(6); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 MC 25.035,20 AAC 25.036, or 20 MC 25.037, as applicable; Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)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 1,253 psi: MPSP = (3,798 ft TVD)(0.44 - 0.11 psi/ft) = 1,253 psi (B)data on potential gas zones; OP05-06 PERMIT Document.doc Page 3 of 7 Printed: 11-Jun-10 Irok • Ed Petiroileurn i Application for Permit to Drill Well OP05-06 Saved: 11-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(1) Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 178.89 X-65 Welded 120 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 2408' 35 / 35 2408'/ 2173' 213 sx 12.0#DeepCRETE Tail Yield 1.58 cu.ft./sk Cement Top planned @ 7215'MD Cemented w/367 sx 12.5# 9-5/8 12-1/4 47 L-80 BTCM 8617' 33/ 33 8617'/ 3801' DeepCRETE Yield 1.54 cu.ft./sk 8-1/2"OA 5-1/2 Sand 17 L-80 DWC 8663' 8417'/ 3782' 170807 4088' Slotted Liner-no cement Lateral 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please see Attachment 3: BOP and Diverter Configuration OP05-06 PERMIT Document.doc Page 4 of,7 Printed: 11-Jun=10 vs% Enil a liroHeum 4 ! Application for Permit to Drill Well OP05-06 Saved: 11-Jun-10 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 j 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 st) Plastic Viscostiy 30 55 15 20 (CP) . pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program(LSND) Lateral Mud Program (Ml VersaPro LS Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 9.0—9.3 . Density(ppg) 8.8 - 9.5 Plastic Viscostiy 15 -25 Funnel Viscosity (CP) 45 - 60 (seconds) Yield Point 15-20 Plastic Viscostiy 12 - 18 (lb/100 sf) (CP) HTHP Fluid loss Yield Point 18.24 (ml/30 min @ <5.0 (lb/100 sf) 200psi 8 100°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 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(t); OP05-06 PERMIT Document.doc Page 5 of 7 Printed: 11-Jun-10 ...... to, • Eni Petiroileurn _en" Application for Permit to Drill Well OP05-06 Saved: 11-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 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 13.Proposed Drilling Program ✓ Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. lc- or ' ei- 1. Move in/ rig up Nabors 245E. Install 21-1/4"Annular with 16"diverter line (IF REQUIRED BY AOGCC) , 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(IF REQUIRED), 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 directional drilling assembly with MWD, LWD and PWD. , 8. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. 9. Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 10. Install 9-5/8"casing rams in the BOP and test to 3500 PSI. OP05-06 PERMIT Document.doc Page 6 of 7 Printed: 11-Jun-10 ...... ,w041 EnD Petirolleum Application for Permit to Drill Well OP05-06 Saved: 11-Jun-10 11. Run and cement 9-5/8", 47# L80, BTC Mod casing. Pump cement and displace with mud, land casing hanger and bump plug. 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. Perform formation integrity test, 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. — �1/.....Q j--. Lai Tt -'- ""!'''` 6'" COh+'� ~°pp Sob 1 J 19. Land liner, set liner hanger with 200' Liner lap inside the 9-5/8"intermediate casing. POOH laying down DP as required. 6./z•!• 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 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt OP05-06 PERMIT Document.doc Page 7 of 7 Printed: 11-Jun-10 co yy tmp yy�Ipp yy �Ipo 0 £6 NNiI m< NG�pImpOMO 84220 OmmmA m MNMIIMj. .4.MI(m4 ONION :22'.2.Ipm� L a MMMMM 4St,tm On1 V NNM '.= ;i2IA g2 W OM X22 W M �2t;.4pM .t22 W A 2 n tno m. A A mmr A r mA A n m m m m m m m m A O r A • N NNN M 4 4 m A m m m m a N lommm mmmmm N to to ION .qmm mm m mm to to mmmmm mmm 0m mm N mm C a . 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E Eni Petroleum Schlumberger WELL FIELD I STRUCTURE OP05-06 (P5) Nikaitchuq Oliktok Point Mepnelk Parameters Surface Location NA027 Alaska State Plane,Zone 04,US Feet MlscalNneous Model BGGM 2010 Dip: 80.998° Date December 08.2010 Lat N 70 30 39.909 SodNng. 603656572 SUS Grid Co.:0.12907625' Sloe: 0605 TVD Ref: Rotary TabB)5220 above MSL) Meg 0ec'. 21.316° FS'. 5764160 Lon: W 149 51 47.005 Easarg'. 51673225 SAS Scale Fact'.099990032 Plan' OP05-06(65) Noy Date June 10,2010 0 1500 3000 4500 6000 OP65-06(P5) TD EAd Cry OP P06!l gt 16 10500 10500 Cry 2/100 End Cry OP P06 Tgt 15 End Cry OP 2/100 OP PO6 Tgt 14 Cry 2/100 End Cry 9000 OP PO6 T0O 13 9000 End Cry Cry 2/100 g OP P06 Tgt 12 Cry 2I100 End Cry OP P06 Tg(11 End Dry Cry 2/100 OP P06 Tat 10 7500 ` Cry 21100 7500 Ent[Cry OP P06 Tit 9 A Cry 21100 End Cry A A OP PO6 Tgt 8 Z End Cry Cry 31100 6000 ePPO6Tgt7 End Cry 6000 p Cry 3.5/100 OP PO6 Tgt 6 Lr) Cry 3.5/160 C_ End Cry II OP PO6 Tgt 5 O) a Cry 3.5/100 End/fry OP P56 Tgt 4 4500 Cm 3/400 4500 (/) End Cry V V OP PO6 Tgt 3 V Cry 3/100 End Cry OP Pt)6 Tgt 2 End Cry OP Ptl6 Tgt 1 Cry 3/100 Cry 3/100 3000 a.,arg"c d 3000 • End cry ' Cry 3/100 End Bid Bid 3.25/100 End Cry 1500 1500 Cry 4.5/100 Bld 3/100 End Cry KOP Bld 1.5/100 4.5/100 RTE 0 0 Cry 3/100 Gyro Pt 13-3/8"Cs9 Cry 0.5/100 0 1500 3000 4500 6000 «< W Scale=1(in):1500(ft) E >>> Schlumherger OP05-06 (P5) Anti-Collision Summary Report Analysis Date-24hr Time: June 10,2010-16:18 Analysis Method: Normal Plane Client: ENI Reference Trajectory: OP05-06(P5)(Def Plan) Field: Nikaitchuq Depth Interval: Every 10.00 Measured Depth(ft) Structure: Oliktok Point Rule Set: D&M AntiCollison Standard Slot: OP05 Min Pts: All local minima indicated. Well: OP05-06 Borehole: OP05-06 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-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert 1 Minor I Major OPO4-07(Non-Def Survey) Warning Alert 7.19 4.73 3.95 4.80 268.84 268.84 OSF<5.00 MinPt-O-ADP IIIIIIIIIIIIIIIs 4.681 3.951 4.63 278.84 278.84 MinPts 7 34 EIM2E 3.81 3.97 328.84 328.84 MinPt-O-EOU 7.49 4.601 3.771 3.76 348.83 348.83 MinPt-O-ADP 1 7.77 3.95 2.65 2.52 468.98 468.96 MinPl-CtCt 7.88 3.80 2.38 2.33 499.00 498.95 MinPt-O-EOU 8.02 3.83 2.35 2.29 508.99 508.92 MinPt-O-ADP 8.23 3.95 242 2.291 518.97 518.88 MinPt-O-SF 18.05 13.38 11.65 4.88 617.93 617.45 OSF>5.00 Exit Alert 6414.98 6335.28 6295.921 81.481 7068.73 3386.79 MinPt-0-SF 6380.23 6300.96 6261.82 migE 7080.91 3390.75 MinPt-O-SF 6319.24 6240.74 6201.99® 7103.93 3398.26 MinPt-O-SF 6098.18 6022.82 5985.64 81.98 7207.64 3432.35 MinPt-O-SF 5480.79 5432.43 5408.74 115.67 8071.67 3709.55 MinPt-O-SF 4897.24 4815.76 4775.52 6084 12164.96 3983.32 MinPt-CtCt 4897.5 4815.441 4774.87 60.35 12177.29 3982.83 MinPt-O-EOU 4897.90 4815.51 4774.81 60.16 12182.22 3982.63 MinPt-O-ADP 4928.35 4838.36 4793.8 55.34 12458.54 3968.50 MinPt-0-SF 4944.00 4846.70 4798.54 51.32 13060.42 3966.58 MinPt-O-EOU 4944.16 4846.74 4798.5 1 51.26 13069.95 3966.64 MinPt-O-ADP 4947.50 4844.28 4793.17_ 48.39 13368.50 3971.06 MinPt-O-EOU 4948.24 484442 4793.00. 48.11 13398.48 3971.51 MinPt-D-ADP 4973.76 4860.27 4804.01 13996.85 3981.63 MinPt-0-SF 5063.56 4933.59 4869.1 r�l 15073.18 4030.06 MinPt-O-SF 5014.24 4868.51 4796.13 34.63 16027.28 4061.73 TD 5353.781 5291.941 5261.510 87.9511 10891.12 3996.48 MinPts OPO4-07PB1(Non-Def Survey) Warning Alert 7.19 4.73 3.95 4.80 268.84 268.84 OSF55.00 MinPI-0-ADP 7.19 4.681 3.951 4.63 278.84 278.84 MinPts 7•341 4.581 3.81 3.97 328.84 328.84 MinPt-0-EOU 749 4.601 3.77i1 3.76 348.83 348.83 MinPt-0-ADP 7.7 3.95 2.65 2.52 468.98 468.96 MinPt-CtCt 7.88 3.80 2.38 2.33 499.00 498.95 MinPt-0-EOU 8.02 3.83 2.3 2.29 508.99 508.92 MinPt-O-ADP 8.23 3.95 2.42 2.291 518.97 518.88 MinPt-O-SF 18.05 13.38 11.65 4.88 617.93 617.45 OSF>5.00 Exit Alert 6414.98 6335.27 6295.91 M. 0 7068.73 3386.79 MinPt-O-SF 6380.23 6300.96 6261.82 81.4• 7080.91 3390.75 MinPt-O-SF 6319.24 6240.74 6201.9•migi 7103.93 3398.26 MinP1-0-SF 6098.18 6022.82 5985.64 imam 7207.64 3432.35 MinPt-O-SF 5480.79 5432.46 5408.7•MEE 8071.67 3709.55 MinP1-0-SF 4897.23 4815.76 4775.52 60.83 12164.96 3983.32 MinPt-CtCt 4897.571 4815.4411 4774.87 60.35 12177.29 3982.83 MinPt-0-EOU 4897.90 4815.511 4774.8111 60.16 12182.22 3982.63 MinPt-O-ADP 4928.35 4838.36 4793.8611 55.3611 12458,54 3968.50 MinPt-O-SF 4944.04 4846.7011 4798.54 51.32 13060.42 3966.58 MinPt-0-EOU 4944.16 4846.741 4798.521 51.26 13069.95 3966.64 MinPt-0-ADP 4947.501 4844.29 4793.18 48.39 13368.50 3971.06 MinPt-O-EOU 4948.24 484443j1 4793.021 48.11 13398.48 3971.51 MinPt-0-ADP 4973.76 4860.27 4804.021[ 44.2 13996.85 3981.63 MinPI-O-SF 5019.21 4894.19 4832.18 40.46 14786.08 4023.98 TD 11 5353.7811 5291.9511 5261.521 87.9 10891.12 3996.48 MinPts OP06-105(P3)(Def Plan) Warning Alert 8.05 6.13 4.80 N/A 0.00 0.00 Surface 8.05 4.84 4.20 4.76 250.00 250.00 OSF<5.00 MinPt-O-ADP 8.051 4.13 3.13 3.06 350.00 350.00 MinPl-CICI 8.15 3.991 2.871 2.77 399.91 399.91 MinPts 8.21 4.02 2.88 2.771 409.89 409.89 MinPt-0-SF 15.68 10.99 9.60 4.96 568.67 568.45 OSF>5.00 Exit Alert 674.07 641.96 626.8.MEM. 2408.40 2172.44 MinPt-0-SF 1604.16 1521.69 1481.34 ,' 5359.70 2957.28 MinP1-0-SF 2111.03 2012.07 1963.47®i 6772.81 3294.07 MinPt-O-SF 2046.84 1956.50 MEM.. 23.09 7106.11 3398.97 MinPt-0-ADP 2045 3- 1912.54 23.39 7139.01 3409.74 MinPt-O-EOU L • 2044.6 1957.40 1914.66 23.90 7188.57 3426.05 MinPt-CtCt 1797.21 1741.45 1714.4 AIME 8594.76 3792.70 MinPt-O-SF 1676.8: 1619.44 1591.53 30.01 9255.15 3844.84 Min%-CtCt 1677.08 liiiiiiii 28.84 9573.85 3873.55 MinPts 1678.51=MEI 1583.36 26.89 10074.92 3930.33 MinPt-O-EOU 1678.62 1614.56 Mana 26.85 10083.87 3931.40 MinPt-O-ADP 1679.07 mum 1583.24 26.70 10123.66 3936.15 MinPt-0-EOU 1680.62 1614.66 1582.49 26.09 10252.95 3951.61 MinPt-O-EOU 1680.74 1614.66 1582.43 26.04 10262.90 3952.80 MinPt-O-EOU Drilling Office 2009.1.726.0 Nikaitchuq\Oliktok Point\0P05-06\0P05-06\0P05-06(P5) 6/10/2010 4:19 PM Page 1 of 7 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 1682.97 1614.811 1581.521 25.2 10421.80 3971.80 MinPts NEM 1276.79 1231.32 15.04 12239.32 3980.08 MinPt-CtCt 1369.98 1229.65 14.80 12272.64 3978.38 MinPt-O-EOU 1374.0 1111111220 MEM 14.22 12461.89 3968.32 MinPts 1374.60 1276.28 1227.9 MIK 12500.95 3966.56 MinPt-O-SF 1376.93 1246.69 MEER M11012 14065.73 3984.13 MinPts MEM 1202.89.11111=151 16257.94 4060.29 MinPts OP03-P05PB2(Def Survey) Warning Alert 15.86 13.8611 12.6211 165.10 68.00 68.00 MinPts 0 13.07 12.58 14.29 243.37 243.37 MinPt-CtCt 16.121 12.31 11.23 299.00 299.00 MinPt-O-EOU 16.27 12.97 MBE 10.39 319.00 319.00 MinPt-O-ADP 18.36 13.•:11011 6.66 469.47 469.45 MinPI-O-ADP 19.06 14.2 Man 509.69 509.62 MinPI-O-ADP 22.26 16.38 14.40 NEM 59279 592.46 MinPt-O-SF 24.03 17.66 15.43 4.97 619-70 619.21 OSF<5.00 MinPt-O-ADP 28.60 19.62 17.09 111101311 649.49 648,78 MinPt-O-SF 30.81 23.06 20.18 4.98 689.06 687.95 OSF>5.00 Exit Alert 34,61 26.14 22.87 4.99 718.60 717.12 OSF<5.00 MinPI-O-ADP 36.01 27.25 23.83 6 728.42 726.80 MinPt-O-SF 37.47 28.43 24.87 4.99 738.22 736.45 OSF>5.00 Exit Alert 429.96 402.15 389.12 MEM. 2409.36 2173.04 MinPt-O-SF 442.53 413.99 400.60 MM. 2497.67 2226.01 MinP1-0-SF 510.60 475.98 459.5 0111M 3184.40 2468.62 MinP1-0-SF 515.08 480.18 463.61 3213.81 2475.22 MinPt-O-SF 3348.31 3269.76 3231.3.MtElla 7113.25 3401.30 MinP1-0-SF 2926,87 2877.39 t 211 61.55 7762.28 3614.44 MinPt-O-ADP 2926.1.liiiiiiii 2853.76 62.09 7770.04 3616.88 MinPt-O-EOU MEM 2877.94 2855.03 63.81 7793.36 3624.20 MinPt-CtCt 2920.86 2875.34 2853.47 68.72 8022.18 3694,42 MinPt-CtCt 2920.96 :E 2853.17 66.32 8042.18 3700.53 MinPt-O-EOU 2921.15 2875.24=MR_66.13 8052.17 3703.59 MinPt-O-ADP 2951.49 2900.53 2875.9 M•' 8579.44 3792.28 MinPt-O-SF Il 2950.2811 2901.58 2878.03 62.60 9046.55 3826.35 MinPt-CtCt 2950.3911 2901.3711 2877.66 62.18 9061.47 3827.60 MinPl-O-EOU 2950.51 2901.381 2877.61 62.04 9065.63 3827.95 MinPt-O-ADP 11 2631.615 2553.92 2515.85 34.55 12142.81 3984.14 MinPt-CtCt 2631.71 2553.86 2515.73 34.49 12146.74 3983,99 MinPt-O-EOU 2631.83 2553.86 2515,68 34.44 12150.67 3983.85 MinPt-O-ADP 2669.65 2585.19 2543.76 322011 12473.89 3967.71 MinPt-O-SF 2674.72 2541.37 2475.50 20.29 12670.66 3965.46 TD 2983.13 MEM 2895.5 OEM 10814.58 3995.07 MinPts OP03-P05(Def Survey) Warning Alert MIRO 13.8611 12.6211 165.10 68.00 68.00 MinPts 10012Efi 13.07 12.58 14.29 243.37 243.37 MinPt-CtCt 16.12 Main 12.31 1123 299.00 299.00 MinP1-0-EOU 18.27 12.97 MEM 10.39 319.00 319,00 MinPt-O-ADP 18.36 13.98 11EIK 6.66 469.47 469.45 MinPt-O-ADP 19.06 14.2 5.92 509.69 509.62 MinPt-O-ADP 22.26 16.38 14.40= 592.79 592.46 MinPt-O-SF 24.03 17.66 15.43 4.97 619.70 619.21 OSF<5.00 MinPI-O-ADP 26.60 19.62 17.091 4.871 649.49 648.78 MinPt-O-SF 30.81 23.08 20.18 4.98 689.06 687.95 OSF>5.00 Fail Alert 34.61 26.14 22.87 4.99 718.60 717.12 OSF<5.00 MinPt-O-ADP 36.01 27.25 23.8311 4.9911 728.42 726.80 MinP1-O-SF 37.47 28.43 24.87 4.99 738.22 736.45 OSF>5.00 Exit Alert 429.96 402.15 389.12 16.44 2409.36 2173.04 MinP1-0-SF 442.53 413.99 400.60.11111111f1I 2497.67 2226.01 MinPt-O-SF 510.60 475.98 459.5 MEM 3184.40 2468.62 MinPt-O-SF 515.08 480.18 463.61 I 3213.81 2475.22 MinP1-0-SF 3348.31 3269.76 3231.3.111111.3 ME 711325 3401.30 MinP1-0-SF 2926.67 2877.39® 61.55 7762.28 3614.44 MinPt-O-ADP 2926.1• 2853.76 62.09 7770.04 3616.88 MinP1-0-E011 MIME 2877.95 2855.04 63.81 7793.36 3624.20 MinPt-CtCI NEM 287535 2853.47 66.72 8022.18 3694.42 MinPt-CtCt 2920.9. 2875.18 2853.17 66.32 8042.18 3700.53 MinPt-O-EOU 2921.15 2875.24=M, 66.13 8052.17 3703.59 MinPt-O-ADP 2951.49 2900.53 2875.9 IEMEI 8579.44 3792.28 MinPt-O-SF D 2950.2 2901.58 2878.03 62.60 9046.55 3826.35 MinPt-CtCt 2950.3 2901.37 2877.66 62.19 9061.47 3827.60 MinPl-O-EOU 2950.51 2901.38 2877.6111 62.04 9065.63 3827.95 MinPI-O-ADP 2631. 2553.92 2515.85 34.55 12142.81 3984.14 MinPt-C1C1 2631.71 2553.861 2515.73 34.49 12146.74 3983.99 MinP1-0-EOU 2631.83 2553.86 2515.67 34.44 12150.67 3983.85 MinPt-O-ADP 2664.85 2580.13 2538.57 32.041 12472.87 3967.76 MinPt-O-SF 2667.03 2582.04 2540.35 31.97 12670.74 3965.46 MinPt-O-EOU 2669.00E1M1 2539.18 31.18 12820.32 3965.89 MinPt-O-EOU 2669.72 2582.07 2539.04 31.01 12860.19 3966.00 MinPt-O-ADP 2673.8 1 2583.09 2538.53 29.98 13049.87 3966.54 MinPt-O-EOU 2673.97 2583.10 29.94 13059.72 3966.57 MinPI-O-ADP 2674.19 2583.18.02/fi 29.89 13075-95 3966.69 MinP1-0-ADP 2674.23 258221 2538.5..1110]:E 13079.12 3966.73 Min%-0-SF 2675.6111 2582 351 2536.52 29.18 13218.76 3968.81 MinPt-O-EOU 2676.06 258243 2536.4 2906 13238.76 3969.11 MinPI-O-ADP 2695.23 2587.55 2534.51 25.3 14007.09 3981.89 MinPt-O-SF 11 2684.2011 2569.04 2512.27 23.63 14563.82 4017.42 MinPt-CtCt 2684.77 2568.57 2511.28 23.42 14614.20 4019.86 MinPt-O-EOU 2687.561 2568.481 2509.74 22.86 14747.94 4023.18 MinPt-O-EOU 2689.53 2527.85 2447.82 16.79 15011.83 4028.73 TD 11 2983 1311 2924.2311 2895.591 10814.58 3995.07 MinPts OP03-P05PB1(Del Survey) Warning Alert 15.86 13.850 12.621 165.10 68.00 68.00 MinPts 1 15.971 13.07 12.58 1429 243.37 243.37 MinPt-CICt i Drilling Office 2009.1.726.0 Nikaitchuq\Oliktok Point\OP05-06)0P05-06\0P05-06(P5) 6/10/2010 4:19 PM Page 2 of 7 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ftL Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor 1 Major 16.12 12.94 12.31 11.23 299.00 299.00 MinPt-O-EOU 16.27 12.97 1228 10.39 319.00 319.00 MinPt-O-ADP 18.36 13.981 12.741 6.66 469.47 469.45 MinPt-O-ADP 19.06 14.251 12.80 5.92 509.69 509.62 MinPt-O-ADP 22.26 16.38 14.40 5.13i1 592.79 592.46 MinPt-O-SF 24.03 17.66 15.43 4.97 619.70 619.21 OSF<5.00 MinPt-O-ADP 26.60 19.62 17.09 IMO 649.49 648.78 MinPI-O-SF 30.81 23.08 20.18 4.98 689.06 687.95 OSF>5.00 Exit Alert 34.61 26.14 22.87 4.99 718.60 717.12 OSF<5.00 MinPt-O-ADP 36.01 27.25 23.8311 4.9911 728.42 726.80 MinPt-O-SF 37.47 28.43 24.87 4.99 738.22 736.45 OSF>5.00 Exit Alert 429.96 402.15 389.1 MIZE 2409.36 2173.04 MinPt-O-SF 442.53 413.99 400.60 MEW 2497.67 2226.01 MinPt-O-SF 510.60 475.98 459. .MIZE 3184.40 2468.62 MinP1-0-SF 515.08 480.18 _463.61 MIZE 3213.81 2475.22 MinPt-O-SF 2924.73 2872.20. 2846.81 57.57 7668.82 3584.62 MinPl-O-ADP 2923.28 2871.94 2847.15 58.93 7692.12 3592.11 MinPt-O-EOU MEE 2873.11 2849.33 61.39 7731.01 3604.53 MinPt-CtCt MEM®: r MINMEIECIEE 8490.56 3788.21 MinPts Oliktok Point I-1A-106(P4)(Def Plan) Warning Alert 32.50 30.58 29.26 N/A 0.00 0.00 Surface ®i 30.58 MIMI 85780.83 40.10 40.10 MinPts 32.63 No= 29.38 133.42 89.20 89.20 MinPt-O-EOU 66.81 58.67 00 10.42 738.21 734.47 MinPt-O-ADP 86.13 70.51 63.6 iEl 1004.06 994.13 MinPt-O-SF 421.21 393.71 380.84 Mint 2507.20 2231.43 MinPt-O-SF 423. ' 871MEZE 3062.36 2441.20 MinPts 241.08 192.06 168.05 5.00 4218.21 2700.85 OSF<5.00 MinPt-O-ADP 214.83 168.69 146 121=1=1 4473.79 2758.27 MinPt-O-SF 198.40 157.93 138.19 5.00 4699.89 2809.06 OSF>5.00 Exit Alert 195.85 156.91 137.93 5.13 4749.04 2820.10 MinPt-O-ADP 191.97" 156.14 138.71 5.48 4847.34 2842.18 MinPt-O-EOU 1 189.32 157.60 14222 6.13 5014.45 2879.72 MinPt-CtCt 204.89 162.86 142.34 4.97 5437.15 2974.68 OSF<5.00 MinPt-O-ADP 216.02 166.021 141.511 4.39 5574.77 3005.60 MinPI-O-ADP 304.12 214.57 170.291 3.421 6292.37 3166.80 MinPt-O-SF 505.84 403.20 352.36 4.97 6797.83 3301.59 OSF>5.00 Exit Alert 775.33 723.84 698.5.MEE 8590.94 3792.59 MinPt-O-SF 773.45 722.88 698.09 15.58 8632.96 3794.11 MinPI-O-ADP 772.9 ® 698.14 15.68 8648.59 3794.85 MinPI-0-EOU MAIKE 723.50 699.70 16.20 8708.19 3798.48 MinPt-CICI 723.13 697.50 15.11 9367.95 3854.90 MinPt-CICt 780 921111MM 679.28 11.62 10425.36 3972.22 MinPt-O-EOU 781.04 712.86=MEI 11.61 10434.00 3973.25 MinPI-O-ADP 826.71 751.97 715.10 IIIEI 10896.67 3996.58 MinPt-O-SF 1069.51 979.89 935.57I�1 4I 11853.32 3989.37 MinPt-O-SF 1071.22 874.53 776.68 547 16790.88 4064.53 MinPt-CtCt 1071.4011 868.361 767.3 31 5.30 17080.23 4087.70 MinPts Olikto6 Point 1-1(Def Survey) r'"r,� 0_ d'$8 Warning Alert 32.50 30.58 29.26 N/A 0.00 0.00 Surface ®' 30.58 IIIIIIIIEEEE 85780.83 40.10 40.10 MinPts 32.63 29.38 133.42 89.20 89.20 MinP1-0-EOU 66.81 58.6 MIME 10.42 736.21 734.47 MinPI-0-ADP 86.13 70.51 63.6 EWE, 1004.06 994.13 MinPt-O-SF 421.21 393.77 380.94 1.rf, 2507.20 2231.43 MinPt-O-SF 360.94 314.31 291.88 8.01 3642.07 2571.43 MinPt-CICI 361.0:MEE 291.58 7.96 3662.05 2575.92 MinPt-O-EOU 361.43 314.22 man 7.91 3682.05 2580.41 Min%-0-ADP 366.73 317.09 IIIMM 7.62 3831.89 2614.07 MinPt-O-ADP 388.70 334.11 307.70® 4096.60 2673.54 MinPt-O-SF 422.34 362.39 333.2•Min 4372.81 2735.58 MinPt-O-SF 458.71 393.49 361.7 ®i 4667.06 2801.68 MinPt-O-SF 485.37 416.49 382.92®i 4894.66 2852.81 MinPt-0-SF 504.50 433.20 398.4 ® 5035.77 2884.51 MinP1-0-SF 564.0 MEEZ1 417.17 5.81 6178.38 3141.19 MinPt-O-EOU 565.71 465.87 416.8711 5.75 6228.14 3152.37 MinPt-0-ADP 444.62 354.21 309.89 5.00 7167.89 3419.24 OSF<5.00 MinPt-0-ADP 338.27 265.69 230.271 4.751 7485.40 3524.60 MinPt-O-SF 292.29 232.37 203.29 5.00 7662.31 3582.52 OSF>5.00 Exit Alert 290.25 231.491 202.99 5.06 7677.56 3587.43 MinPt-O-ADP 288.811 231.181 203.24 5.14 7692.63 3592.28 MinPt-O-EOU 1-079 1 232.27 205.41 5.32 7722.22 3601.74 MinPt-CtCt 756.12 702.42 676.3811 14.481 9080.92 3829.30 MinPt-O-SF 772.761 851t&/I 6512711 9.651 9196.13 3839.58 MinPts Oliktok Point 1-2(Def Survey) Pass 24.46 22.55 21.22 N/A 0.00 0.00 Surface IIIMEIEV 22.55 M13311 N/A 40.00 40.00 MinPts ® 18.98 17.79 9.00 358.36 358.36 MinPt-CtCt 23.51®.-r MIZE 7.75 398.29 398.29 MinPts 24.46 19.50 17.98 438.08 438.08 MinPt-O-SF 9647.03 9562.27 9520.6•MH 'l 11144.82 3997.98 MinPt-O-SF 11461.47 11391.29 11357.0:MEIEE 7616.39 3567.63 MinPt-O-SF 9363.54 9305.79 9277.7•aI 7834.23 3636.91 MinPt-O-SF 10534.04 10442.42 10397.41=MI 10912.14 3996.84 MinPt-O-SF 9007.72 8990.16 8982.34 MIEE 1083.51 1069.23 MinP1-0-6F 8131.32 8114.90 8107.6 560 42 1136.32 1118.54 MinPt-0-SF 7588.28 7572.75 7565.94 mum 1169.83 1149.56 MinP1-0-SF 7326.75 7311.66 7305.08 MEE 1185.76 1164.23 MinPt-O-SF 7121.00 7106.36 7100.00 IMEIZE 1201.03 1178.25 MinP1-0-SF 7041.46 7027.00 7020.7 MIMI 1207.46 1184.13 MinPI-0-SF 6583.17 6569.40 6563.48 MIZE 1246.71 1219.87 MinPt-O-SF 11774.87 11654.46 11595.1 99.26 12154.48 3983.71 MinPt-O-SF Drilling Office 2009.1.726.0 Nikaitchuq\Oliktok Point\OP05-06\0P05-06\0P05-06(P5) 6/10/2010 4:19 PM Page 3 of 7 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct.Ct(ft)I EOU(ft) Day.(ft) Fact. MD(ft) I TVD(n) Alert I Minor I Major 10493.90 10402.64 10357.811 117.0 10923.37 3997.02 MinP1-0-SF 13046.22 12904.17 12833.951 92.8 13080.25 3966.74 MinPt-O-SF 13216.41 13069.47 12996.81 90.91 13276.83 3969.68 MinP1-0-SF OP07-104(P2)(Def Plan) (i, Pass 24.04 22.13 20.80 N/A 0.00 0.00 Surface 111111X11121 20.12 19.12 11.02 350.00 350.00 MinPt-C1Ct 24.14 ENE= 18.95 10.19 379.85 379.85 MinP1-0-EOU 24.30 20.06 18.90 9.64 399.75 399.75 MinPt-O-ADP 27.36 22.12 20.46 567.95 567.73 MinPt-0-SF 73.83 63.21 58.9 f181 925.24 918.66 MinPt-O-SF 4986.01 4903.46 4863.0 �� 7100.06 3396.99 Min%-0-SF 4219.40 4165.34 4139.2.1 90j 8427.77 3782.67 MinPt-O-SF 4225.17 4169.99, 4143.27 79.05 8607.39 3793.11 MinPt-O-EOU 4224.40 4171.08 4145.30 81.89 8705.41 3798.28 MinPt-CtCt 4220 4. _4166.30 4140.02 80.27 9071.95 3828.50 MinPt-CtCt 4220.83 4164.38 4136.96 76.93 9410.76 3858.72 MinPt-O-EOU 4225.34=MCI 412179 63.39 10361.95 3964.64 MinPt-O-EOU 4225.50 MEM IMMI, 63.24 10379.13 3966.70 MinPts MEM 3809.56 3764.25 43.04 12237.65 3980.16 MinPt-CtCt 3902.5 3808.85 3762.81 42.36 12264.69 3978.80 MinP1-0-EOU 3904.44, 3809.01 3762.10 41.60 12335.27 3975.05 MinP1-0-EOU 3907.45 3809.16 �"' 12465.14 3968.15 MinPts 3907.181 3780.96 3718.66 31.34 13927.84 3980.35 MinPt-C1Ct 3908.051 3758.56 3684.62 26.42 15071.93 4030.03 MinPt-CtCt 3908.71 3746.53 3666.24 24.33 15594.72 4046.77 TD 4225 8611_ 4157.40 4123.97 63.18 10446.55 3974.71 MinPt-CtCt 4220 4411 4152 1411 4118.7911 63.2 10890.48 3996.46 MinPts OP08-04(P4b)(Def Plan) Pass MMOZ 28.21 27.00 12.67 429.42 429.42 MinP1-CtCI 31.89 1.133E msn 12.00 459.09 459.08 MinPts 34.02 29.87 28.41® 537.46 537.34 MinP1-0-SF 114.69 104.76 100.40 MEIKEI 873.42 868.59 MinP1-0-SF 6510.40 6430.92 6391.68 MNE 7172.54 3420.77 MinPI-O-SF 6192.76 6116.83 6079.35 82.61 7263.74 3450.95 MinP1-0-SF 5532.55 547874=ER 104.72 8649.00 3794.87 MinPt-O-ADP 5532.14 5478.65 5452.40 105.35 8669.51 3795.97 MinPt-O-EOU 11M 547890 5452.97 10663 8712.12 3798.77 MinPL-CtCt mum 5475.38 5448.88 104.30 9064.94 3827.89 MinPt-CtCt 5531.4 547346 5444.95 97.01 9540.18 3870.27 MinP1-0-EOU 5531.47 5473.46 5444.9 96.9• 9544.19 3870.63 MinPts 5675.97 5612.36 5581.04 90.62 11166.28 3997.82 MinP1-0-SF 5386.8 5307.49 5268.30 68 72 11946.09 3988.57 MinPt-CtCt 5386.8•MEM M.: , 68.66 11948.47 3988.54 MinPts 5662.59 5574.43 5530.8 64 9 12147.27 3983.98 MinPt-O-SF 5761.85 5672.35 5628.64=Ma 12179.20 3982.76 MinP1-0-SF 5536.4 ,mmilE 5433.35 81.30 10438.61 3973.79 MinP1-0-EOU = t4 5467.61 5433.71 81.62 10455.95 3975.76 MinPt-C1Ct 6598.59 6501.08 6452.811.: ,I 12512.39 3966.18 MinP1-0-SF 7852.38 7738.59 7682.19 69.60 13401.82 3971.56 TD 8182.49 8150.00 8134.2 mom 2025.27 1891.95 MinPt-O-SF 8030.62 7998.71 7983.2 mum 2071.82 1929.92 MinPt-O-SF OP09-S03(P1)(Del Plan) Pass 40.05 38.13 36.80 N/A 0.00 0.00 Surface 35.68 34.57 17.11 389.66 389.66 MinPt-CtCt 39.95 MEM 34.24 15.05 449.08 449.07 MinPI-O-EOU 40.01 35.52 04 14.79 458.89 458.87 MinP1-0-ADP 41.93 37.15 35. mum 527.17 527.07 MinP1-0-SF 148.81 138.48 134.2 •lI5 901.07 895.35 MinP1-0-SF 2144.61 2122.44 2112.3 mom 1827.20 1724.40 MinPt-O-SF 7380.62 7290.33 7246.0.1Ea 7200.61 3430.03 MinPt-O-SF 5998.27 5942.14 5914.•.MOM 8066.95 3708.11 MinP1-0-SF l 5946.45 5898.25 62.68 12033.75 3987.19 MinPt-CtCt 6045.44 5945.56 5896.42 61.50 12059.34 3986.61 MinPt-O-EOU 8046.64 5945.81 5896.21 60.93 12072.11 3986.30 MinPt-O-ADP 6188.52 6113.95 6077.47 84.79 10671.07 3991.80 MinPt-O-ADP 6188.2 6113.90 6077.54 85.07 10681.50 3992.18 MinPt-O-EOU 6187.92 6114.19 6078.13 85.77 10707.53 3992.99 MinPt-CtCt 6613.90 6454.00 6374.8511 41.7711 14402.91 4006.60 MinPt-O-SF 10867.93 10676.70 10581.89 57.31 17080.23 4087.70 TD 16405.42 1631420 16269.5611 183.70 864.92 860.34 MinPt-O-SF OP1O-P09(P1)(Def Plan) Pass 48.04 46.12 44.79 N/A 0.00 0.00 Surface 43.90 42.89 22.61 369.78 369.78 MinPt-CtCt 47.91 mmE3 42.79 21.52 389.55 389.55 MinPt-O-EOU 47.97 43.86 20.99 399.43 399.43 MinPt-O-ADP 55.88 50.85 49.291® 554.97 554.80 MinPt-O-SF 168.28 158.22 154.14®" 884.68 879.50 MinPt-O-SF 8311.27 8226.61 8185.16 7306.09 3465.02 MinPt-O-SF 6925.35 6856.4. 6822.82 102.91 11124.17 3998.09 MinP1-0-ADP 6925.1:mczni 6822.84 103.09 11130.20 3998.06 MinP1-0-EOU 6925.0: 6856.50 6823.02 103.38 1113925 3998.01 MinPt-C1Ct 6906.5. 6830.68 6793.54 92.96 11596.71 3991.93 MinPt-CICI 6906.9 6830 291 6792.76 92.01 11611.73 3991.73 MinPt-O-EOU 6907.57 683042 6792.64 91.41 11621.11 3991.61 MinPt-O-ADP 7554.61 7426.29 7362.94 MEDI 13075.46 3966.69 MinPt-O-SF 7901.71 7765.03 7697.50 58.4• 13563.31 3973.99 MinPt-O-SF 8914.10 8768.14 8695.9.mBEJ 14047.27 3983.30 MinPt-0-SF 16352.27 16168.35 16077.19 89.68 17080.23 4087.70 TD 16954.91 16873.42 16833.6 11111.1M1 773.21 77083 MinPt-O-SF 9382.53 9357.02 9345.2 mini 1552.06 1488.15 MinPt-O-SF 9038.53 9014.17 9002.94 ME= 1667.32 1587.53 MinPt-O-SF 8897.06 8873.01 8861.94=111EM 1704.58 1619.53 MinPt-O-SF Drilling Office 2009.1.726.0 Nikaitchuq\Oliktok Point\OP05-06\OP05-06\OP05-06(P5) 6/10/2010 4:19 PM Page 4 of 7 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Day.(ft) Fact. MD(ft) I TVD(ft) Alert 1 Minor I Major 11233.71 11140.57 11094.871 122.94 7125.86 3405.43 MinPt-O-SF 0111-01(P3)(Def Plan) Pass 56.04 54.81 52.79 N/A 0.00 0.00 Surface MOM 52.81 51.80 27.31 350.00 350.00 MinPt-CICt 56.1 ® 51.63 25.16 379.66 379.66 MinPI-0-EOU 56.29 52.74=MEI 23.68 399.43 399.42 MinP1-0-ADP 71.93 66.76 64.79 MUM 632.34 631.76 MinPt-0-SF 7557.33 7473.95 7432.7.MEM 7408.13 3498.97 MinPt-0-SF 7377.21 7295.16 7254.6 i• 9100 7438.60 3509.09 MinP1-0-SF 7183.07 7102.79 7063.14E0 �t 7477.17 3521.88 Min Pt-O-SF 6659.3 I 6584.50 6547.56 90.13 9267.75 3845.97 MinPt-0-EOU 6659.46 6584.52' 4 90.04 927327 3846.48 MinPt-0-ADP 6793.8. 6707.85 6665.34 79.90 11043.83 3998.14 MinPts 6793.8 6707.89 6665.41 79.96 11046.98 3998.15 MinPt-CtCt 6764.00 667348 662872 75.54 11587.36 3992.06 MinPt-CtCt 6764.0: 6673.38 66287 52 75.38 11591.19 3992.00 MinPts IKE= 667767 6631.32 73.04 11639.35 3991.39 MinPt-CtCt 6771.46 msza 6631.08 72.86 11643.12 3991.34 MinPts 7267.96 7157.35 7102.53 M:13 E1 12039.59 3987.07 MinP1-0-SF 9009.84 8880.90 8816.93 111111150001 12412.87 3970.93 MinPt-O-SF 6945.24 6854.57 6809.72 MEM 10522.88 3982.41 MinPt-0-SF 9463.03 9325.41 9257.0•M110 ii 12948.96 3966.25 MinPt-O-SF OP12-01(P3b)(Def Plan) Pass 64.04 62.82 60.80 N/A 0.00 0.00 Surface 61.17 60.34 38.10 300.00 300.00 M1nPI-CtCI 64.11 60.92 59.93 31.89 359.87 359.87 MinP1-0-EOU 64.16 60.93 MIIMEI 31.25 369.73 369.73 MinPt-0-ADP 76.16 71.82 70.2 ON= 583.06 582.77 MinPt-0-SF 82.02 77.42 75.74 MEER 620.75 620.25 MinPt-0-SF 7726.26 7657.85 7624.14 man 7722.21 3601.73 MinPt-O-SF 7583.69 7516.52 7483.42 IMIKEfi. 7743.14 3608.39 MinP1-0-SF 7303.41 7238.82 7207.0 mom 7788.48 3622.68 MinPt-0-SF L 6901.2• 6841.6 6812.30 117.69 7867.12 3647.02 MinPts 7552.65 7481.97 7447.12 ' 8615.09 3793.39 MinPt-0-SF rat=11 7288.39® 109.39 8735.78 3800.61 MinPts 7801.80 7716.26 7673.98 1am. 11190.16 3997.59 MinPt-0-SF 3104.79 3095.34 165.37 2119.06 1967.45 MinPts 8470.88 8367.59 8316.44 MEE 11697.51 3990.74 MinPt-0-SF 8983.62 8869.71 8813.24 MEC 11973.73 3988.23 MinP1-0-SF 9641.48 9517.96 9456.6•MEC 12105.79 3985.35 MinPt-O-SF 11251.28 11101.01 11026.3 MEE 13081.66 3966.76 MinPt-O-SF 12126.21 11954.25 11868.76 70.92 13987.91 3981.42 TD 11 8069.661 7974.46] 7927.3511 85.64i1 11582.07 3992.13 MinPts OP13-103(P1)(Del Plan) Pass 88.02 86.11 84.78 N/A 0.00 0.00 Surface 88.02 84.10 83.09 42.90 350.00 350.00 MinPt-CtCt 88.11 82.92 39.51 379.46 379.46 MinPt-0-EOU 88,28 84.03 37.11 399.10 399.10 MinPt-O-ADP 127.80 120.79 118.25=EH 730.34 728.69 MinPt-O-SF 10419.43 12344.49 12711.8 M1MEfi, 7605.40 3564.05 MinPt-0-SF 130111.42 12844.49 12761.8 786• 13977.28 3981.22 Mine1-0-SF 13986.18 13810.79 13723.8• 804 14424.64 4008.08 MinP1-0-SF 17858.94 17664.02 17567.3.IMES 16107.79 4062.06 MinPt-0-SF 18475.99 18277.16 18178.54 93.67 16372.56 4058.94 TD 15772.39 15681.97 15637.61 177.81 7363.50 3484.12 MinP1-0-5F OP14-108(P1)(Def Plan) Pass 96.02 94.10 92.77 N/A 0.00 0.00 Surface 96.02 92.09 91.09 46.90 350.00 350.00 MinPt-CtCt 96.11=MB 90.92 43.19 379.42 379.42 MinPt-0-EOU 96.27 92.03 90.86 40.56 399.02 399.02 MinPt-O-ADP 140.21 132.95 130.29 IIIMM1. 747.25 745.34 MinPt-O-SF 15178.43 15105.79 15070.3 MIR 7613.46 3566.68 MinPt-O-SF 11023.08 10964.18 10935.62- 7788.53 3622.69 MinPt-0-SF 11484.47 11397.79 11355.24=DM 10894.70 3996.54 MinPt-O-SF 12802.51 12690.76 12635.6•- 12036.66 3987.13 MinPt-0-SF 14466.15 14343.70 14283.2:MEE 12154.23 3983.72 MinPt-0-SF 17187.64 17061.10 16998.6 mug 13055.29 3966.58 MinPt-0-SF 18096.98 17963.03 17896.8.1=1EMN 13573.35 3974.15 MinPt-0-SF 18798.52 18658.03 18588.5:111111110a 13976.83 3981.21 MinPt-0-SF 19065.42 18924.59 18854.98 136.93 14103.53 3986.21 TD OP15-P06(P2)(Def Plan) Pass 104.06 102.14 100.82 N/A 0.00 0.00 Surface 11 104.061 100.14 99.13 50.91 350.00 350.00 MinPt-C1C1 104.08 100.111 99.09 49.84 359.79 359.79 MinP1-0-EOU 104.13 100.12 99.07 48.72 369.58 369.58 MinPt-0-ADP 156.61 149.56 147.00 30.17 724.17 722.61 MinPt-0-SF 11698.65 11614.35 11573.00 141.4 10977.29 3997.70 MinP1-0-SF 13208.63 13100.24 13046.85 123.6 11974.29 3988.23 MinP1-0-SF 11033.95 10979.00 10952.41 207.4 7852.06 3642.40 MinP1-0-SF 11495.66 11432.67 11402.06` 187.72 8638.83 3794.38 Min191-0-SF 13704.84 13618.71 13576.44 162.12 10061.64 3928.79 MinPt-0-SF 14221.36 14131.74 14087.721 16154 10204.65 3945.84 MinP1-0-SF 19087.46 18967.54 18908.371 161.30 13073.71 3966,67 MinPt-0-SF 19718.13 19588.95 19525.161 15465 13577.21 3974.21 MinP1-0-SF 20247.62 20110.27 20042.391 149 14] 13998.61 3981.67 MinPt-0-SF 20335.75 20198.11 20130.10 149.48 14057.03 3983.73 TD OP19-ENI#1(P1)(Non-Def Plan) Pass 144.051 140.20 139.23 73.42 340.20 340.20 MinPt-CtCt 144.15 140.051 138.96 65.20 379.33 379.33 MinPt-0-EOU 144.31 140.06 138.901 61.20 398.75 398.74 MinPt-0-ADP Drilling Office 2009.1.726.0 Nikaitchuq\Oliktok Point\OP05-06\OP05-06\OP05-06(P5) 6/10/2010 4:19 PM Page 5 of 7 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 173.08 160.66 155.41_ 16.30 997.64 988.01 MinPt-O-SF 374.47 358.58 351.601 2676 2106.51 1957.58 MinPt-O-SF 4124.99 4074.65 4050.361 84.871 7140.11 3410.10 MinPt-O-SF 4133.79 4083.89 4059.82` 85.831 8320.96 3768.14 MinPt-O-SF 4788.85 4737.91 4713.331 97.361 8739.81 3800.94 MinPt-O-SF 5265.02 5214.47 5190.00 107.55 9048.38 3826.50 TD OP16-P03(P2)(Def Plan) Pass 11205 110.13 108.80 N/A 0.00 0.00 Surface =11E01 108.48 107.66 66.81 300.00 300.00 MinPt-CICI 112.13®0: 107.46 60.06 330.00 330.00 MinPt-O-EOU 112.27 108.40®" 56.47 350.00 350.00 MinPt-O-ADP 179.07 171.54 168.74® 758.01 755.91 MinPt-O-SF 13067.84 12979.72 12936.4.1®9 10924.17 3997.03 MinPt-O-SF 11758.87 11677.51 11637.6 1=n1M; 11046.89 3998.15 MinPt-O-SF 12267.82 12174.74 12129.00 EIMI. 11667.08 3991.07 MinPt-O-SF 12987.29 12889.83 12841.90 IIMEal 11716.15 3990.56 MinPt-O-SF 19268.10 19165.95 19115.68 191.61 12192.77 3982.19 TD 13008.16 12949.87 12921.61 MEM 7801.13 3626.63 MinPt-O-SF 12991.42 12926.76 12895.31 NE= 8542.07 3791.09 MinPt-O-SF 12991.51 12926.28 12894.54 204.66 8598.57 3792.82 MinPt-O-SF 12412.70 12346.99 12314.94 MEM 9050.84 3826.70 MinPt-O-SF 12979.97 12911.86 12878.61 mum 9110.88 3831.98 MinPt-O-SF 12662.43 12641.25 12631.61 MKS 795.40 792.58 Min%-0-SF 12565.87 12544.82 12535.2x. , 798.82 795.92 MinP1-0SF 12488.65 12467.70 12458.1' 656 20 801.58 798.62 MinPt-O-SF 12392.17 12371.36 12361.9, 656.0 805.08 802.05 MinP1-0-SF mEztamt 134 :316FEIMEE MMIFE 10697.98 3992.72 MinPts OP20-ENI#9(P1)(Non-Def Plan) Pass NEEsEr 148.23 147.26 77.56 340.20 340.20 MinPt-CtCt 152.17 IMIM 146.98 68.88 379.28 379.28 MinPt-O-EOU 152.33 148.09 S." 1 64.66 398.67 398.67 MinPt-O-ADP 196.33 182.71 176.. 1003.53 993.63 MinP1-0-SF 267.04 252.30 245.8:MINED'I.1 1581.67 1513.74 MinPI-0-SF 276.87 261.62 254.9 IZ s 1688.91 1606.09 MinP1-0-SF 308.41 291.59 284.0 MIECIER 1979.99 1854.12 MinPt-O-SF 5727.93 5684.87 5664.22 6494.95 3216.02 MinPt-O-SF OP22-ENI#1(P2)(Def Plan) Pass 168.01 166.10 164.77 N/A 0.00 0.00 Surface 168.01 164.09 163.09 83.00 349.00 349.00 MinPt-CtCt 168.16 164.00 162.88 74.08 387.69 387.69 MinPt-O-EOU 168.25 164.02 162.86 71.75 397.35 397.35 MinPt-O-ADP 196.47 183.83 178.47 MEM 1000.06 990.32 MinPt-O-SF 385.11 369.68 362.921M. 0i 2102.64 1954.52 MinPt-O-SF 4128.67 4078.13 4053.740 _84.61 7135.74 3408.67 MinPt-O-SF 4135.78 4085.74 4061.60 85 6 8322.14 3768.33 MinPt-O-SF 4782.83 4731.72 4707.0 968• 8740.24 3800.98 MinPt-O-SF 5261.25 5210.57 5186.03 107.17 9053.55 3826.93 TD OP17-P02(P3)(Def Plan) Pass - 120.03 118.12 116.79 N/A 000 0.00 Surface =0, 11647 115.65 71.91 299.00 299.00 MinPt-CICI 120.12 mom 115.47 64.81 329.00 329.00 MinPt-O-EOU 120.19 116.39 MOE 62.83 339.00 339.00 MinPt-O-ADP 198.65 190.72 187.71® 781.65 779.11 MinP1-0-SF 11529.82 11446.95 11406.31 I 11026.13 3998.07 MinPt-O-SF 10922.57 10846.85 10809.7•=ME 11205.80 3997.41 MinP1-O-SF 11488.86 11398.96 11354.81 IMEEIE 11628.56 3991.52 MinPt-O-SF 12122.06 12031.67 11987.2 =ME 11932.17 3988.70 Min%-0-SF 15438.95 15363.40 15326.51=ME 7513.71 3533.96 MinP1-0-SF 11353.43 11297.65 11270.64 MEE 7828.54 3635.15 MinPt-O-SF 11348.78 11290.79 11262.6 =BE 8183.68 3740.11 MinP1-0-SF 11357.01 11295.22 11265.21 1111116125 8703.61 3798.16 MinPt-O-SF 11356.37 11294.03 11263.6. 186.94 8841.57 3809.37 MinPt-O-SF 12076.12 12010.54 11978.5.i 188.74 9569.19 387306 MinPt-O-SF 12502.56 12431.56 12396.8 mom 10062.69 3928.91 MinPt-O-SF 12547.91 12476.67 12441.8 m.0 10073.01 3930.10 MinPt-O-SF 14305.10 14193.94 14139.1:jjjjjjjjj .1 12558.73 3965.28 MinPt-O-SF 6585.75 6570.64 6564.04 498.81 1146.20 1127.71 MinPt-O-SF 6675.31 6660.03 6653.341 499 .1 1146.31 1127.81 MinPt-O-SF 11809.87 11772.87 11755.3 878.16 873.18 MinPt-O-SF 7150.68 7134.36 7127.1 496.5 1131.49 1114.05 MinPt-O-SF 6916.44 6900.66 6893.72 111.111210 1143.24 1124.96 MinPt-O-SF 6800.83 6785.29 6778.48 a00 1145.80 1127.34 MinP1-0-SF 14807.89 14686.63 14626.81® 13077.37 3966.71 MinPt-O-SF 15634.44 15502.48 15437.30 MEM 13570.22 3974.10 MinPt-0-5F 16622.89 16481.87 16412.1 IMEIRS 13978.03 3981.23 MinPt-O-SF 18573.67 18416.61 18338.94'min 14781.50 4023.88 MinPt-O-SF OP21-ENI#10(P1)(Non-Def Plan) Pass 160.03 158.11 156.79 N/A 0.00 0.00 Surface 1 160.021 156.21 155.27 83.62 350.00 350.00 MinPt-C1CI 160.09 156.17 155.17 78.97 379.04 379.04 MinPt-O-EOU 160.24 156.21 155.15 74.91 398.40 398.39 MinPt-O-ADP 217.94 206.59 201.87 22.90 906.78 900.86 MinPt-O-SF 6319.26 6303.04 6295.81 436.9 3514.50 2542.77 MinPt-O-SF OP18-107(P2)(Def Plan) Pass 128.04 126.12 124.80 N/A 0.00 0.00 Surface L 128.041 124.83 124.19 97.78 250.00 250.00 MinPt-CICI 128.14 124.751 124.02 86.20 280.00 280.00 MinPt-O-EOU 128.21 124.77 124.011 83.13 290.00 290.00 MinPt-O-ADP 222.13 214.49 211.63 38.481 737.90 736.13 MinPt-O-SF Drilling Office 2009.1.726.0 Nikaitchuq\Oliktok Point\0P05-0610P05-06\OP05-06(P5) 6/10/2010 4:19 PM Page 6 of 7 Offset Trajectory Separation Allow Sep. Reference Traject Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 14213.75 14134.91 14096.29 184.011 10997.80 3997.89 MinPI-O-SF 13145.66 13061.76 13020.61( 159.721 11627.10 3991.54 Min%-O-SF 14160.05 14073.08 14030.401 165.87 11665.33 3991.09 MinPt-O-SF 16832.97 16745.88 16703.141 196.90 11931.88 3988.70 MinPt-O-SF 18247.52 18157.32 18113.03 205.96 12046.21 3986.92 TD 16805.13 16748.13 16720.44 IIMEM 9045.79 3826.28 MinPt-O-SF 17851.88 17790.17 17760.13 MOE 9572.63 3873.42 MinP1-0-SF 12891.71 12872.50 12863.8 il 781.64 779.10 MinP1-0-SF 11241.07 11221.40 11212.5 ® 837.63 833.80 MinPt-O-SF 3180.18 3168.44 3163.5 MII1ME' 1090.08 1075.39 MinPt-O-SF 16884.01 16808.80 16772.00=NEE 10885.81 3996.38 MinPt-O-SF OP23-WW02(Def Survey) Pave ® 172.5511 171.7211 146.58 267.98 267.98 MinPts 174.98 172.26 171.51 115.78 329.00 329.00 MinPt-CtCt 175.00 mmin99 109.03 349.00 349.00 MinPts 175.3 MEE MEM 96.34 398.79 398.79 MinPts 234.96 225.71 221.70® 899.90 894.22 MinPt-O-SF 127321 1258.16 1251.24 M'= 2173.81 2009.62 MinPt-O-SF 5437,09 5407.39 5393.0 189.2: 3556.54 2552.21 MinPt-O-SF 6055.42 6022.35 6006.30 188.6: 3820.81 2611.58 MinP1-0-SF 6648.05 6611.76 6594.11 188.2 4065.48 2666.54 MinPt-O-SF 6851.51 6814.07 6795.84 187.90 4145.05 2684.42 MinPt-O-SF 6270.45 6206.01 6174.2: 98.80 7093.64 3394.90 MinPt-O-SF 5423.43 5384.76=EV 143.87 7842.06 3639.33 MinPt-O-ADP 5423.30 MEE= 5365.94 144.26 7846.43 3640.67 M1nPI-O-EOU Main 5384.85 5366.16 145.05 7853.96 3642.99 MinPt-CtCt NEM 5369.53 5348.82 130.63 8410.72 3780.78 MinPt-CICt 5412.2: 5368.93 5347.75 127.73 8473.68 3786.94 MinPt-O-EOU 5412.64 5369.01 mczy,E. 126.91 8492.01 3788.31 MinPt-O-ADP 5415.35 5370.94 -' ' 124.68 8614.84 3793.38 MinPI-O-ADP 5414.9 5370.84 5349.29 125.56 8627.99 3793.90 MinPt-O-EOU 5371.22 5350.04 127.80 8661.19 3795.51 MinPt-CtCt 5410.91 5368.24 5347.36 129.54 8938.85 3817.43 MinPt-CtCt 5411.01 5368.22 5347.32 129.40 8947.20 3818.12 MinPt-O-EOU 5411.07 536E24 MEMI 129.26 8955.55 3818.81 MinPt-O-ADP 411.38 5367.55 5346.14 126.30 9065.07 3827.90 MinPt-CtCt 5411 4.® 5345.81 125.50 9080.52 3829.27 MinPt-O-EOU 5411.72 5367.42 MIME 124.90 9114.11 3832.26 MinPt-O-ADP 5434.60 5386.92 5363.5 Imo' 9556.17 3871.75 MinPt-O-SF 5527.56 5469.17'4 1 96.27 10968.95 3997.62 MinPI-O-ADP 5527.5 5469.17 5440.49 96.33 10972.59 3997.66 MinPt-O-EOU IMEME 5469.19 5440.53 96.39 10976.22 3997.69 MinPI-CICI 5408.93 5376.49 84,36 11680.16 3990.92 MinPi-CICI 5474.8 5408.92 537645 84,31 11681.93 3990.91 MinPt-O-EOU 5474.86 5408.92 MR= 84.26 11683.71 3990.89 MinPt-O-ADP 5594.12 5522.36 5486.9 12017.20 3987.52 MinPt-O-SF 7320.37 7251.19 7217.09 107.33 12203.80 3981.72 TD 5535.98 5479.20 5451.34 99.20 10500.11 3980.32 MinPt-O-SF 5533.05 5473.74 5444.58 94.8 10887.86 3996.42 MinPt-O-SF OP24-ENI#4(P2)(Def Plan) Pass 183.95 182.04 180.71 N/A 0.00 0.00 Surface 183.951 180.03 179.03 90.98 349.00 349.00 MinPt-CtCt 184.10 179.94 178.82 81.21 387.57 387.57 MinPt-O-EOU 184.19 179.96 178.801 78.65 397.20 397.20 MinPI-O-ADP 276.93 267.35 263.51 3585 885.49 880.28 MinPt-O-SF 9413.09 9357.06 9329.931 173.42 7763.38 3614.79 MinPt-O-SF 10085.44 10020.44 9988.811 159A51 8385.89 3777.73 MinPt-O-SF 10092.86 10004.59 9961.261 116 4411 11208.57 3997.37 MinPt-O-SF 10335.98 10241.85 10195.581 111691 11492.20 3993.39 MinPt-O-SF 11767.41 11675.92 11630.98 130.90 11653.03 3991.23 TD 10102.32 10034.61 10001.561 152.811 8765.16 3803.04 MinPt-O-SF 11705.01 11633.82 11599.0 168.191 9660.41 3883.31 MinPt-O-SF OP26-DSPO2(Def Survey) 1 Pass II I 385.60 Q N/A 0.00 0.00 MinPts NEM 367.02 363.37 51.32 762.56 760.38 MinPt-CICI 378.50 366.70 362.75 47.48 787.74 785.08 MinPt-O-EOU 377.56 366.90 moms 42.94 820.97 817.57 MinPt-O-ADP 386.91 374.13 368.69IKI 930.22 923.46 MinPt-O-SF 931.04 918.41 913.0 1673.21 1592.59 MinPt-O-SF 1001.50 988.04 982.24 86.6 1724.46 1636.59 MinPt-O-SF 1080.65 1066.27 1060.04 1777.79 1682.23 MinPt-O-SF 6817.12 6758.59 6730.20 MEW 7399.31 3496.03 MinPt-O-SF 6372.70 6322.15 6297.6 MIZEI 9561.05 3872.23 MinPt-O-SF 6651.96 6596.00 6568.81=BE 10062.03 3928.83 MinPt-O-SF 6595.27 6534.30 6504.62=ME 11011.61 3997.99 MinPt-O-SF 6485.88 maga 6398.61 113.54 11151.96 3997.93 MinPts 6485.86 6427.17 6398.63 113.59 11154.07 3997.92 MinPt-CtCt 6480.72 6418.38 6388.00 106.66 11469.17 3993.71 MinPt-CtCt 6480.90 6418.24 6387.71 106.12 11485.88 3993.48 MinPt-O-EOU 6481.05 6418.28 6387.70 105.94 11491.38 3993.40 MinPt-O-ADP 6579.82 6513.91 6481.76=BE 11580.28 3992.15 MinPt-O-SF 6825.08 675842 6725.89 104.89 11604.26 3991.83 TD II 6828.4911 6761.8411-1711.71M4.9 I 11604.25 3991.83 MinPts OP25-DSP01(P1)(Def Plan) Pass II 402.631 398.30 397.09 165.69 350.00 350.00 MinPt-CtCt 402.78 398.131 396.76 14627 397.57 397.56 MinPt-O-EOU 402.85 398.14 396.741 143.47 407.08 407.07 MinPt-O-ADP 467.93 452.03 445.04 33.331 997.66 988.03 MinP1-0-SF 4316.56 4300.19 4292.89 295.37 2827.68 2378.44 TD Drilling Office 2009.1.726.0 Nikaitchuq\Oliktok Point\0P05-06\0P05-06\0P05-06(P5) 6/10/2010 4:19 PM Page 7 of 7 Schlumimrger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OP05-06 Oriented EOU Dimension Field: Nikaitchuq N NoGo Region Anti-Collision rule use. Structure: Oliktok Point Minor Risk- -•aration Factor '_ Date: June 10,2010 --mallIrf North 350 0 10 340 iiiir 330 ��1114\ 30 /li�l�y124:2 140 Milli 32 • ; ' .,\ ►` 40 ••��; 14� 1 ,� 120 �p• ;' '�ktok Point I-1A-106(P4) 310 •09.--�3(..41' `, �, / �� `N 50 ��l\� �`, .; 100 / 111� —IP. 300 `11 • iiiII I'^V.f�rd ,000 '$ , 60 290 �►�—‘,..41.111111' .' `I`,�'•�> �` • 6 9,• -11 j , ,',70 . f2111 \ lid.,\*,∎. yip 1�:.�. ��. \,• 280 0.,12 (P3b) ,�,� ,„&1 `,Tj� � �.i 1 4 80 : 0. eillAll 0 '',11":'4:.'iZ.!.,:'.'OA', '.2“! ••■•I. ". ab 270 • Or- .,, \ 0 , - . . IL90 s ° r4• — 'sue► no P4 g '''' / • :°` 441411,0.y"'�`` .o_4,iti-.c •Pr , f.: "1) , ��_�, l! a 260 '^y.4.1.m..:..r62� 8�� ;.! ro /,' 100 .� P s ' :, o �� 250 ^ . `, O /,110 ,77)6...,/ 1.v,'.. J 1O � , '-' = ENI#9(P1) o� I/�120**al 4041111 240'> / ■r 230 130 220 140 210 150 200 160 190 180 170 Well Ticks Type: MD on OP05-06(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azitraith Interval: 10.0 deg Scale: IN=%50.00 ft Drilling Hazards Summary 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase • Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 8-1/2" Open Hole / 5-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud • Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip _ sheets),pumping out, backreaming Drilling Hazards Summary.doc 6/3/2010 2:53:00 PM r\ O o d O u_ co v 4e1J I 1k i, \ . 4 ev - , ___,, , . .. . ... . .. ,. .. ,,• , . . . 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Z ED W > J 3 e p W I W W O h= O O 10 0 U 2 ti \W \W I 7 U e U I Schlumberger CemCADE well cementing recommendation for 13.375°" Surface Casing Operator : Eni Petroleum Well : OP05-06 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Jason Brink Location : North Slope -Alaska Proposal No. : Draft v1 Service Point : Prudhoe Bay, Alaska Date Prepared : 6-10-2010 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-223-0093 E-Mail Address : JLong1 @slb.com ft 1 C? r B C 1.4UATE 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 : OP05-06 Sal( rger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Total MD : 2376.0 ft BHST : 48 degF Bit Size : 16 in ft (x 1000) psi OD 20.in 0 f1 5 1.0 1.5 - Q 160ft Pore i • • M • • l\ i II ll ii I i t o OD 13A in n °- 0013 ft . . . . . Permafrost j { z """ � g_ LC Q2296 ft I. 1 I , . . . UG4 , i 1 l I ° iii ? 1 0 co- Well Lithology Formation Press. Page 2 op05-06.cfw;06-10-2010; LoadCase Surface Casing;Version wcs-cem460_02 : Eni Petroleum Well OP 05-06 Schlokrier String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 169.0 18.376 Landing Collar MD : 2296.0 ft Casing/liner Shoe MD : 2376.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2376.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 125.3% Mean OH Equivalent Diameter: 18.778 in Total OH Volume : 759.1 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1900.0 16.000 150.0 19.279 2376.0 16.000 35.0 16.822 Page 3 op05-06.cfw;06-10-2010; LoadCase Surface Casing;Version wcs-cem460_02 Client : E Petroleum Well SccIinhrgnr Well OP 05-06 String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 50 deg Max. DLS : 4.502 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 100.0 0.000 100.0 100.0 0.0 100.0 0.000 200.0 200.0 0.0 100.0 0.000 300.0 300.0 0.0 100.0 0.000 350.0 350.0 0.0 100.0 0.000 400.0 400.0 0.8 100.0 1.500 450.0 450.0 1.5 100.0 1.500 500.0 499.9 3.0 100.0 3.000 600.0 599.6 6.0 100.0 3.000 700.0 698.8 9.0 100.0 3.000 800.0 797.1 12.0 100.0 3.000 850.0 845.8 13.5 100.0 3.000 900.0 894.3 14.9 97.9 3.000 1000.0 990.3 17.8 94.7 2.997 1100.0 1084.7 20.7 92.4 2.998 1200.0 1177.3 23.6 90.6 3.005 1300.0 1267.9 26.5 89.2 2.999 1395.5 1352.2 29.4 88.1 3.002 1400.0 1356.1 29.4 88.1 0.441 1500.0 1443.1 29.9 88.1 0.500 1600.0 1529.6 30.4 88.1 0.500 1700.0 1615.6 30.9 88.1 0.500 1800.0 1701.2 31.4 88.1 0.500 1900.0 1786.3 31.9 88.1 0.500 1977.7 1852.2 32.3 88.1 0.502 2000.0 1870.9 33.2 87.6 4.481 2100.0 1952.4 37.6 85.6 4.498 2200.0 2029.3 42.0 84.0 4.502 2300.0 2101.0 46.4 82.6 4.502 2376.0 2151.8 49.7 81.7 4.495 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 120.0 11.00 8.43 Permafrost Sandstone 1889.0 12.00 8.43 Permafrost Sandstone 2430.0 13.00 9.20 UG4 Sandstone II Page 4 op05-O6.cfw;06-10-2010; LoadCase Surface Casing;Version wcs-cem460_02 : Eni Petroleum Well OP 05-06 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1900.0 1786.3 32 0.7 2430.0 2185.9 50 1.4 ft degF ft 0 911 40 60 n qnn 600 900 _—Geoth.Profile L- l -Hod.Depart. I i ci I immimmorn , , m Wum am am l _ =� i�1� � o - iminammonom os - o =itiiMililiw5 B o ry H 0 __ ,� 1 L o _ ca I 1 I mokiumummovi 1111111111111111•1011111111•1•1 MIII c,-.. .�a I n f o � M i Temperature Hori. Departure Page 5 op05-06.cfw;06-10-2010; LoadCase Surface Casing;Version wcs-cem460_02 Client : E Petroleum Well Schlunkrgcr Well OP 05-06 String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost Original fluid Mud 9.50 lb/gal Pv: 12.000 cP Tv:7.00 lbf/100ft2 Displacement Volume 343.8 bbl Total Volume 854.4 bbl TOC _ 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 Pv:16.000 cP Ty:12.00 lbf/100ft2 Lead Slurry 350.5 1900.0 0.0 10.70 k:4.06E-2 Ibf.s^n/ft2 n:0.345 Tv:0.03 lbf/100ft2 12.0 ppg 60.1 476.0 1900.0 12.00 k:7.50E-2 lbf.sAn/ft2 n:0.372 Tv:4.15 lbf/100ft2 DeepCRETE Mud 343.8 0.0 9.50 Pv:12.000 cP Tv:7.00 lbf/100ft2 Static Security Checks: Frac 5 psi at 160.0 ft ? Pore 19 psi at 160.0 ft c Collapse 2182 psi at 2376.0 ft 3 Burst 5020 psi at 0.0 ft is Csg.Pump out 52 ton 2 ra CD ft (x 1000) psi 0 I 0 1 .5 so i Hydrostatic -Prat � I Pore o o � i �\ om - I i . ' . lIIco I o_ 1 t t 1 4 { O co co M- Fluid Sequence Static Well Security Page 6 op05-06.cfw;06.10-2010; LoadCase Surface Casing;Version wcscem460_02 : Eni Petroleum Well OP 05-06 Sccl krgcr 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 lnj. 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 DeepCRETE 5.0 60.1 12.0 60.1 80 16-Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.5 343.8 40.4 343.8 80 19-Start Displacement Total 02:29 854.4 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 3 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2077 psi at 0.0 ft Burst 4827 psi at 0.0 ft Temperature Results BHCT 64 degF Simulated Max HCT 71 degF Simulated BHCT 71 degF Max HCT Depth 2376.0 ft CT at TOC 60 degF Max HCT Time 02:29:14 hr:mn:sc Static temperatures : At Time (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 20 degF Bottom Hole (degF) (degF) 48 degF Page 7 op05-06.cfw;06-10-2010; LoadCase Surface Casing;Version wcs-cem460_02 Well : Eni 5-06 HIMbil biller Well OP05-06 String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing o — �° —Acquired Pressure Calc. Pump Press. 11 11 I 7 i m I I , 1 i ■1111 _ti_-�l_i 0 0 20 40 60 80 100 120 140 160 Time (min) o_ .-- Fluids at 2376 ft Acquired 4 Out , L _ I i_ ; - —Acquired 0 In i I I i I i- G i I �— i, i , s QO - Q�n �i I p _. I t a LL I '-i ,_ - 0 20 40 60 80 100 120 140 160 0 Time (min) E c 3 ar CD CD -n K GI CD fD Page 8 op05-06 cfw;06.10-2010; LoadCase Surface Casing;Version wcs-cem460_02 : Eni Petroleum Well OP 05-06 Schnm rgcr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 4: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2356.0 ft Casing Shoe :2376.0 ft NB of Cent. Used :35 NB of Floating Cent. :35 Centralizer Placement Bottom MD Nbr. Cent./ Cent.Name Code Min.STO @ Depth t (ft) Joint (%) (ft) 1936.0 24 1/2 NW-TR-13 3/8-8-TR 3 W304 14.4 516.0 2376.0 11 1/1 NW-TR-13 3/8-8-TR 3 W304 71.1 2376.0 1 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-TR-13 3/8-8-TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 CA n (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications = E 3 Cr CD CD 0A m ft m 0 9n 40 60 80 100 — Between Cent. I I + -I-Ft Cent. + I O O I r ill I I I! I I 1 !___._ J t ,--T_, 1 I 1 , ill 1111111 -t 1 O o . O I 1T' (--4 i i 1 1 I I I I 1 ar O Pipe Standoff Page 9 op05-06.cfw;06-10-2010; LoadCase Surface Casing;Version wcs-cem460_02 Client : Eni Petroleum Well Schlumbcrgcr Well OP05-06 String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing f Section 5: WELLCLEAN II Simulator i ft % 0 9n LO 60 80 100 Std Hem. Cent. { 1+••••...........,J i - Cement Coverage a I ��a a_ ( i imixr i I 1. i nil 1 . I JITI:j _. 1 E , c„,0 . • L, _ 1 _i I 1 __,__i_J C B Cement Coverage c Cr s Fluids Concentrations Risk Mud on the Wall -1 z 5 z C' 0-1 I 70 0 0 200- 7200 200- v- 200 440- -400 400- -_.. 400 600- -600 640- c-,. .? 800 600- -1300 800- e_ _0 800— 1900= 71000 11300- 1000 r 1 200- -1200 f r 1200- A L 1200 r c 1440- 1.109 c c ,100- _^a 1.100 o 1 660- -1600 1600- 1600 1800- -1800 1600- - - 1806 2000 ', -2000 2900- 2000 2200- -2200 2200- 2200 24001 -2400 2400 2.100 ,; m i o T Z f'. 3 0 3 3 N x Mud I I High ® LOW 12.0 ppg DeepCRETE I I Medium I ] None I I Lead Slurry I I MUDPUSH II Page 10 op05-06.cfw;06-10-2010; LoadCase Surface Casing;Version wcs-cem460_02 : Eni Petroleum Well OP 05-06 SccliNkergcr 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 lbf/100ft2 Gel Strength : (lbf/100ft2) MUD Mud Type :WBM Job volume :343.8 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 :(lbf/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.sAn/ft2 At temp. :80 degF n :0.345 Ty :0.03 lbf/100ft2 Gel Strength :(lbf/100ft2) DESIGN BLEND SLURRY Name :B809 Mix Fluid :20.852 gal/sk Job volume :350.5 bbl Dry Density : 108.75 lb/ft3 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 Thickening Time Schedule () (Bc) at (hr:mn) Compressive Strength Schedule () (psi) at (hr:mn) Page 11 op05-06.cfw;06-10-2010; LoadCase Surface Casing;Version wcs-cem460_02 Client : E Petroleum Well SCIllehrga Well OP 05-06 Ir , 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 I bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.0 PPG Lit Mix Fluid :5.043 gal/sk Job volume :60.1 bbl Dry Density : 110.20 lb/ft3 Yield : 1.58 ft3/sk Quantity :213.39 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 Thickening Time Schedule ( ) (Bc) at (hr:mn) Compressive Strength Schedule () (psi) at (hr:mn) Annulus ID: 13.375 in-OD: 16.000 in ca z _ -D MUDPUSHH -Mud .K- -Tail Slurry CD Oct - Lead Slurry CD 0) O O O c) 'tn a N yD N -- to a C v O N .0 O N CD 1 1 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 Flow Rate (bbl/min) Page 12 op05-06.cfw;06-10-2010; LoadCase Surface Casing;Version wcs-cem460_02 Client : E Petroleum Well Schiberger Well OP 05-06 String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 7: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total ' Item Pack. Packaging Comments Quantity Quantity Name D178 3204 lb 65 sack 501b D124 263701b 660 sack 40 lb S001 638 lb 7 sack 100 lb D079 639 lb 7 sack 100 lb D053 127581b 128 sack 100 lb D044 3843 lb 70 sack 55 lb D907 55555 lb 592 sack 94 lb D182 555 lb 23 sack 25lb D046 275 lb 6 sack 50 lb D031 95271b 87 sack 110 lb D047 4.3 gal 1 pail 5.0 gal D185 10.7 gal 3 pail 5.0 gal Mix Water Requirements : Fresh water 14032 gal 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 81924.383 lb Fresh water 216.348 bbl 10.001 bbl 12.0 ppg DeepCRETE Volume : 60.1 bbl Density : 12.00 lb/gal Yield : 1.58 ft3/sk Dry Phase Liquid Phase Blend: 21339 lb Design Mix Water 25.6 bbl 10.0 bbl LAS Design 12.0 PPG Lit 21339.316 lb Fresh water 25.268 bbl 9.862 bbl D047 4.268 gal 1.666 gal 0.020 gal/sk blend D185 10.670 gal 4.164 gal 0.050 gal/sk blend Page 13 op05-06.cfw;06-10-2010; LoadCase Surface Casing;Version wcs-cem460_02 Schlumberger CemCADE well cementing recommendation for 9-5/8" Intermediate Casing Operator : Eni Petroleum Well : OP05-06(P4) 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 : 6-10-2010 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-223-0093 E-Mail Address : JLong1 @slb.com n c cr rc cQ CM L � &ATE 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 : E Petroleum Well Schl berger Well OP 05-06(P4) String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Total MD : 8600.0 ft BHST : 85 degF Bit Size : 12 1/4 in I ft (x 1000) psi o020.in 0 2 3 — g 120ft - . „ -Frac —Pore • - • Permafrost 0D 13.4 in / ®2376f1 Middle Ugnu _ C) C - B CD o_ OD9.62in -,/ LUgnu kil @ 8570ft -s -o C W .+- - N Sand top LC @8490 ft OA sand top 0 0 0 0 Well Lithology Formation Press. Page 2 op05-06.ctw;06-10-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_02 Client : E Petroleum W Sc mkrger Well ll OP 05-08(P4) String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2376.0 13 3/8 68.0 12.415 Landing Collar MD : 8490.0 ft Casing/liner Shoe MD : 8570.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 8570.0 9 5/8 40.0 47.0 8.681 L-80 4760 6870 BTCM Page 3 op05-06.cfw;06-10-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_02 Client : E Petroleum Well Schl bergcr Well OP 05-06(P4) 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 : 989.3 bbl (including excess) Max. Deviation Angle : 87 deg Max. DLS : 4.537 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 100.0 0.000 100.0 100.0 0.0 100.0 0.000 200.0 200.0 0.0 100.0 0.000 300.0 300.0 0.0 100.0 0.000 350.0 350.0 0.0 100.0 0.000 400.0 400.0 0.8 100.0 1.500 450.0 450.0 1.5 100.0 1.500 500.0 499.9 3.0 100.0 3.000 600.0 599.6 6.0 100.0 3.000 700.0 698.8 9.0 100.0 3.000 800.0 797.1 12.0 100.0 3.000 850.0 845.8 13.5 100.0 3.000 900.0 894.3 14.9 97.9 3.000 1000.0 990.3 17.8 94.7 2.997 1100.0 1084.7 20.7 92.4 2.998 1200.0 1177.3 23.6 90.6 3.005 1300.0 1267.9 26.5 89.2 2.999 1395.0 1351.8 29.4 88.1 3.017 1400.0 1356.1 29.4 88.1 0.400 1500.0 1443.1 29.9 88.1 0.500 1600.0 1529.5 30.4 88.1 0.500 1700.0 1615.6 30.9 88.1 0.500 1800.0 1701.2 31.4 88.1 0.500 1900.0 1786.3 31.9 88.1 0.500 1977.0 1851.6 32.3 88.1 0.506 2000.0 1870.9 33.2 87.6 4.343 2100.0 1952.4 37.6 85.6 4.498 2200.0 2029.3 42.0 84.0 4.502 2300.0 2101.0 46.4 82.6 4.502 2376.0 2151.8 49.7 81.7 4.537 2400.0 2167.1 50.8 81.4 4.372 2500.0 2227.3 55.2 80.4 4.509 2600.0 2281.2 59.6 79.5 4.499 2700.0 2328.3 64.1 78.6 4.494 2800.0 2368.5 68.5 77.8 4.498 2900.0 2401.5 72.9 77.1 4.504 2991.0 2425.1 77.0 76.4 4.527 3000.0 2427.1 77.0 76.4 0.000 3100.0 2449.6 77.0 76.4 0.000 3200.0 2472.1 77.0 76.4 0.000 3300.0 2494.5 77.0 76.4 0.000 3400.0 2517.0 77.0 76.4 0.000 3500.0 2539.4 77.0 76.4 0.000 3600.0 2561.9 77.0 76.4 0.000 3700.0 2584.4 77.0 76.4 0.000 3800.0 2606.8 77.0 76.4 0.000 3900.0 2629.3 77.0 76.4 0.000 Page 4 op05-06.cfw;06-10-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_02 Client : Eni Petroleum Well OP 05-06(P4) Sch ibergnr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 4000.0 2651.7 77.0 76.4 0.000 4100.0 2674.2 77.0 76.4 0.000 4200.0 2696.7 77.0 76.4 0.000 4300.0 2719.1 77.0 76.4 0.000 4400.0 2741.6 77.0 76.4 0.000 4500.0 2764.1 77.0 76.4 0.000 4600.0 2786.5 77.0 76.4 0.000 4700.0 2809.0 77.0 76.4 0.000 4800.0 2831.4 77.0 76.4 0.000 4900.0 2853.9 77.0 76.4 0.000 5000.0 2876.4 77.0 76.4 0.000 5100.0 2898.8 77.0 76.4 0.000 5200.0 2921.3 77.0 76.4 0.000 5300.0 2943.7 77.0 76.4 0.000 5400.0 2966.2 77.0 76.4 0.000 5500.0 2988.7 77.0 76.4 0.000 5600.0 3011.1 77.0 76.4 0.000 5700.0 3033.6 77.0 76.4 0.000 5800.0 3056.0 77.0 76.4 0.000 5900.0 3078.5 77.0 76.4 0.000 6000.0 3101.0 77.0 76.4 0.000 6100.0 3123.4 77.0 76.4 0.000 6200.0 3145.9 77.0 76.4 0.000 6293.0 3166.8 77.0 76.4 0.000 6300.0 3168.4 76.9 76.1 -4.024 6400.0 3191.9 75.9 71.7 -4.498 6500.0 3217.1 74.8 67.1 -4.498 6600.0 3244.0 73.9 62.5 -4.504 6700.0 3272.4 73.1 57.9 -4.496 6800.0 3302.0 72.4 53.3 -4.507 6900.0 3332.7 71.8 48.6 -4.494 7000.0 3364.4 71.3 43.9 -4.504 7100.0 3396.7 70.9 39.1 -4.500 7200.0 3429.5 70.7 34.4 -4.493 7300.0 3462.7 70.6 29.6 -4.502 7400.0 3495.9 70.6 24.8 4.498 7500.0 3529.1 70.7 20.1 4.502 7600.0 3561.9 70.9 15.3 4.503 7700.0 3594.3 71.3 10.6 4.500 7800.0 3625.9 71.8 5.9 4.495 7867.0 3646.6 72.2 2.7 4.523 7900.0 3656.7 72.2 2.7 0.000 8000.0 3687.3 72.2 2.7 0.000 8067.0 3707.7 72.2 2.7 0.000 8100.0 3717.6 73.2 2.7 2.970 8200.0 3744.0 76.2 2.7 3.000 8300.0 3765.3 79.2 2.7 3.000 8400.0 3781.5 82.2 2.7 3.000 8500.0 3792.5 85.2 2.7 3.000 8567.0 3797.0 87.2 2.7 3.015 8587.0 3797.9 87.2 2.7 0.000 8600.0 3798.6 87.2 2.7 0.000 Page 5 op05-06.cfw;06-10-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_02 : Eni Petroleum Well OP 05-06(P4) Schinkrier String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 120.0 11.50 8.30 Permafrost Sandstone 1900.0 12.00 8.30 Permafrost Sandstone 3458.0 12.40 8.30 Middle Ugnu Sandstone 6502.0 14.00 8.30 L Ugnu Shale 7715.0 14.00 8.30 N Sand top Sandstone 7865.0 14.00 8.30 N Sand bottom Sandstone 8600.0 14.00 8.30 OA sand top Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1900.0 1786.3 32 0.7 2430.0 2185.8 50 1.4 5330.0 2950.5 85 2.2 5342.1 2953.2 85 2.2 8570.0 3796.9 85 1.7 8600.0 3798.6 85 1.7 Page 6 op05-06.ctw;06-10-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_02 We : Eni Petroleum ll OP 05-06(P4) Sehin rger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) ft degF (x 1000)ft o- 0 I 60 90 ri 95 5.0 7.5 —Geoth.Profile Hori.Depart. S i - y 1,_.. i �o — so-- ■UU■ i �_ j { I o co ■ ■N ■■r ' ! I ■ �� ■=mu. ' 1 _ 1 . ! _ _4______________ __--- • _ - ■ 0 _ ■� o IA ■ 1 o_ ! o ■■ ammo o c� - _ 1111111111111111111111=6111 4, CI . 1 111111111111--- _-__i- — p l t cv {� ■ CO ■ _ — ■ Csi - -,- 4- -i 1 (!) i -\ c 3 [d — ■�■.I•■Ll�■� cn o ( ■�■■■■■■■■ CD NIMEMMIII...1 o � CD 0 C Temperature Hori. Departure ro Section 2: fluid sequence Job Objectives: Zonal Isolation,TOC @ 7215(500'over N-sand) Original fluid Mud 9.50 lb/gal Pv:20.038 cP Ty:20.59 lbf/100ft2 Displacement Volume 621.5 bbl Total Volume 791.9 bbl TOC 7215.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 1003.9 6211.1 10.50 Pv:36.000 cP Ty:20.00 Ibf/100ft2 DeepCRETE 100.3 1355.0 7215.0 12.50 k:3.90E-3 lbf.s^n/ft2 n:0.911 Ty:11.77 lbf/100ft2 Mud 621.5 0.0 9.50 Pv:20.038 cP Ty:20.59 Ibf/100ft2 Page 7 op05-06.cfw;06-10-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_02 : Eni Petroleum Well OP 05-06(P4) SchlVmbergcr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Static Security Checks: Frac 305 psi at 2376.0 ft Pore 134 psi at 2376.0 ft Collapse 4569 psi at 8570.0 ft Burst 6870 psi at 0.0 ft Csg.Pump out 74 ton ft (x 1000) psi 0 3 --Hydrostatic —Frac Pore oo _ – .n = ' o cr 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 lnj. 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 5.0 100.3 20.1 100.3 80 9-Start Cement Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.5 621.5 73.1 621.5 80 19-Start Displacement Total 01:57 791.9 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 214 psi at 2376.0 ft Pore 134 psi at 2376.0 ft Collapse 4304 psi at 1409.3 ft Burst 6419 psi at 0.0 ft Page 8 op05-06.cfw;06-10-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_02 We : Eni Petroleum ll OP 05-06(P4) Schlin rger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Temperature Results BHCT 83 degF Simulated Max HCT 85 degF Simulated BHCT 64 degF Max HCT Depth 5246.9 ft CT at TOC 61 degF Max HCT Time 00:05:10 hr:mn:sc Static temperatures : At Time (hr:mn) (hr:mn) Geo.Temp. Top of Cement (degF) (degF) 85 degF Bottom Hole _ (degF) (degF) 85 degF ° —Acquired Pressure ° —Cale.Pump Press. i o. a I , —{ �� -. _ I I-- 0 25 50 75 100 125 Time (min) CA .-...c,_ Fluids at 8570 ft 0 Acquired 0 Out -- ' .--- - C —Acquired Q In 1....-,- — — .—_- _. . . � Q Out i l CD lllafl , ea ' VIM 111 Q= I t '0 —t 1 O I� ° I v 0 25 50 75 100 125 Time (min) Page 9 op05-06.cfw,06-10-2010, LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem460_02 We : Eni Petroleum ll OP 05-06(P4) Schliberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 4: centralizer placement Top of centralization :7200.0 ft Bottom Cent. MD :8550.0 ft Casing Shoe :8570.0 ft NB of Cent. Used :34 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent./ Cent.Name Code Min.STO @ Depth (ft) Joint (0/a) (ft) 8570.0 34 1/1 NW-TR-9 5/8-6-TR 3A W090 61.5 7230.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) NW-TR-9 5/8-6-TR W090 9 5/8 12.850 11.591 No Hannover 11.625 775.59 5626.97 3A CA (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications j- c B is CC CD 0 7n 40 60 80 100 0 ---Between Cent. f}— ------ I -s +Pt Cent. i I m i fD ' 11 AN ME - w 1111111111111 1 CD 1 111 ? i 111111 ' i11l 1 I o Pipe Standoff Page 10 op05-06.cfw;06-10-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcscem460_02 We : Eni Petroleum ll OP 05-06(P4) Schl hrgcr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 5: WELLCLEAN II Simulator ft % 2 I 75 100 Std Betw.Cent. _ -Cement Coverage a i l i I 0 4---t H- o— 1 I ; . in IL:11 I !Co o 1_.__I___i_..-1._____1_____ E E c co Cement Coverage o Fluids Concentrations Risk Mud on the Wall ar Fg 7200 7200 7200- 7200 7400 7400 74005 x -7400 7600 7600 7600 - -.-7600 _ � � ' ,-- U 7600 7800 E 7800 z, 7800 E S 2 -u 1 0 8000 8000 a Pk 8000 -8000 a o a o �4, o' g"- B200 8200 6200 r x-8200 y• 8400 8100 8400- P ,44 -8a00 6600 8600 86001 k -8800 r i • W O W If 12 S G W 5 'o Z Z IIIII Mud in High Low DeepCRETE Medium None MUDPUSH II Page 11 op05-06.cfw;06-10-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_02 Client : E Petroleum Well SchI rger Well OP 05-06(P4) 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 :621.5 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 : 11.77Ibf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.5 ppg Lit Mix Fluid :5.175 gal/sk Job volume : 100.3 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity : 366.99 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 Thickening Time Schedule () (Bc) at (hr:mn) Compressive Strength Schedule () (psi) at (hr:mn) Page 12 op05-06.cfw;06-10-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_02 We : Eni Petroleum ll OP 05-06(P4) Scciibergnr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 7: operator summary Additives Total Item Pack. Packaging Comments Quantity Quantity Name D178 5681 lb 114 sack 50 lb D124(.76 7340 lb 184 Sack 40 lb SG D907 23678 lb 252 sack 94 lb D182 382 lb 16 sack 251b D046 86 lb 2 sack 50 lb D031 8199 lb 75 sack 110 lb D167 92lb 4 sack 251b D185 22.0 gal 5 pail 5.0 gal D110 3.7 gal 1 can 5.0 gal Mix Water Requirements : Fresh water 4551 gal 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 : 100.3 bbl Density : 12.50 lb/gal Yield : 1.54 ft3/sk Dry Phase Liquid Phase Blend: (lb) Design Mix Water 45.2 bbl 10.0 bbl LAS Design 12.5 ppg Lit 36699.059 lb Fresh water 44.606 bbl 9.866 bbl D167 91.748 lb 0.250%BWOB D185 22.019 gal 4.870 gal 0.060 gal/sk blend D046 73.398 lb 0.200%BWOB D110 3.670 gal 0.812 gal 0.010 gal/sk blend Page 13 op05-06.cfw;06-10-2010; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem460_02 S P E O IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. Eni E&P Division REVISION STAP-P-1-M-6140 0 1 1 1 1 1 1 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW = +MW 0.052 x 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. Ertl E&P Division REVISION STAP-P-1-M-6140 0 1 1 1 I I I l LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT)or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. S P E O IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. Eni E&P Division REVISION STAP-P-1-M-6140 0 11 1 1 1 1 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of 'Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity,filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also,the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. ENI S.p.A. S P E O IDENTIFICATION CODE PAG 209 OF 338 Em E&P Division REVISION STAP-P-1-M-6140 0 1 • Vit LEAK-OFF TEST REPORT Report N° . Date• ,WELL NPME: WELL CODE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 Mud T}pe: FWG EL S Rig type: J.LIPs Hole Dameter(in): 121/4 Weight(KgA): 1.3 R.K.B.elevation(m): 26 Last Csg.Shoe(m): 797 Marsh Ascosity(sec/0t): 44 Water Depth(m): 24 Cog.diameter On): 13'•3/88 P.V.(cps): 19 Pumps: 12-P.160 _Grade: 2.55 Y.P.Qb/100 6): 5 Liners(in): 6.5" _Weight(Ib/t): 61 Gels(b/100 t': 2/8 Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(ccRO min): 10.5 Lithology Shale ■ Expected EMW 1.68 Kg/cm2/10 m Time Volume Pressure Time Volume Pressure Time Volume Pressure [rc�inI (b1:1) (Psi) (min] (bbl) [Psi] (min] (bbl) (Psi) 1- 025 50 9 2 490 16 2 435 2 050 100 95 2 480 3 0.7 5 200 10 2 470 4 1D0 300 10.5 2 463 _ — 5 125 400 11 2 455 • 6 150 500 11.5 __2 450 7 1.75 570 12 2 445 8 2D0 600 13 2 440 8 2D0 550 14 2 437 • 8.5 200 505 15 2 435 _ rid e: Pumped with a constant tow rate of(bhp: Vblurne pumped(bbl): \/plume returned(bbl): (psi) I 1000 900 • I 800 • stop pump P 700 - ` e Boo -fJ S shut in curve S 500 -.._ti—. U 400 . - 1 18 minutes e 300 - 200 100 • 0 0,25 0,5 0,75 1 1,25 1,5 1,75 1 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbf) 14 Time mins RESULTS: (Press.mw+Press.Lo.)x10/)epth=[(1.3 x797/10)+(430 x0.07)]x10 1 797=1.68(Kg/cm2/10 m) Note: Company Representative Figure 15-1 - Leak-Off Test Report REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 Oliktok Cs 11 OLIKTOK 5 Point 0 INTAKE DOCK \ OPP IN THIS S' MODULE • Pie 1. k5 SURVEY _� N �O� .y lei I 9 U E 1‘. , El DEW SITE • STP ___1-- , jt 0uKT0K Poik MODULES I NOC STAGING AREA•, I + T13N, R9E DS-30 f' _ 18 '‘) 1° CS 15• SCALE: Li : O 1" = 150, 7 f DS-30 1 � 21�\ J�,[\1j\�1\l2 S TP PAD ` VICINITY MAP O,� \'� SCALE: 1" = 1 Mile 0'30 0 Ova 0-0 0-0\.--__ O°O� aOw O°-0Oj�3r \ ° � G ` OW° ° ,` O '0 0caN \ ° � -0 O O-0 � N �1 TS ~ \o t.PQ Z --_..-c ? -o„..,--,..0 / \\ DO \ OLIKTOK ` � ` °� POINT PAD `� N. 0 \ o• as \ \ o \ \ Ci \ / \ \ SEE SHEET 3 FOR NOTES / \ `\ / A LOUNSBURY Existing Conductor /� & ASSOCIATES, INC. • Conductor Asbuilt this survey / SURVEYORS ENGINEERS PLANNERS / AREA: MODULE: UNIT: M B P urolleum OLIKTOK POINT PAD lillll �� WELL CONDUCTOR ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-di 1 OF 3 2 ■■■•■■• ■••■•■■•■■•■-■•■•■■ REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN AK STATE PLANE(NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. 'y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP-11 6,036,332.70 1,656,791.89 70°30'39.015" 149°51'57.587" 2,052 1,519 12.1 4.0 OP-I2 6,036,328.85 1,656,784.83 70°30'38.977" 149°51'57.795" 2,056 1,526 12.2 4.0 0P03-P05 6,036,325.10 1,656,777.76 70°30'38.940" 149°51'58.004" 2,059 1,533 12.2 4.0 0PO4-P07 6,036,321.43 1,656,770.69 70°30'38.904" 149°51'58.212" 2,063 1,541 12.2 3.8 OP05 6,036,317.71 1,656,763.67 70°30'38.868" 149°51'58.419" 2,067 1,548 12.2 3.7 OP06 6,036,313.96 1,656,756.55 70°30'38.831" 149°51'58.629" 2,070 1,555 12.2 3.6 OP07 6,036,306.41 1,656,742.45 70°30'38.757" 149°51'59.045" 2,078 1,569 12.2 3.5 OP08 6,036,302.66 1,656,735.36 70°30'38.720" 149°51'59.254" 2,082 1,576 12.2 3.5 OP09 6,036,298.90 1,656,728.32 70°30'38.683" 149°51'59.462" 2,085 1,583 12.2 3.5 OP10 6,036,295.16 1,656,721.26 70°30'38.647" 149°51'59.670" 2,089 1,590 12.2 3.7 OP11 6,036,291.38 1,656,714.21 70°30'38.610" 149°51'59.878" 2,093 1,597 12.2 3.8 OP12 6,036,287.63 1,656,707.14 70°30'38.573" 149°52'00.086" 2,097 1,604 12.2 4.0 OP13 6,036,276.37 1,656,685.97 70°30'38.463" 149°52'00.711" 2,108 1,626 12.2 3.6 OP14 6,036,272.66 1,656,678.89 70°30'38.426" 149°52'00.920" 2,112 1,633 12.2 3.5 OP15 6,036,268.88 1,656,671.79 70°30'38.389" 149°52'01.129" 2,115 1,640 12.2 3.4 OP16 6,036,265.11 1,656,664.75 70°30'38.353" 149°52'01.337" 2,119 1,647 12.2 3.3 OP17 6,036,261.36 1,656,657.70 70°30'38.316" 149°52'01.545" 2,123 1,654 12.2 3.2 OP18 6,036,257.62 1,656,650.62 70°30'38.279" 149°52'01.753" 2,127 1,681 12.2 3.1 OP19 6,036,250.09 1,656,636.50 70°30'38.205" 149°52'02.170" 2,134 1,675 12.2 2.5 OP20 6,036,246.31 1,656,629.41 70°30'38.168" 149°52'02.379" 2,138 1,682 12.2 2.2 OP21 6,036,242.57 1,656,622.39 70°30'38.132" 149°52'02.586" 2,141 1,689 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 t , AK STATE PLANE(NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. 'y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP25 6,036,004.35 1,656,510.91 70°30'35.791" 149°52'05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70°30'35.867" 149°52'05.456" 2,372 1,787 12.2 -2.7 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: Ed' Pet�rolleu�nn� CONDUCTOR D Einli ASBUILT LOCATIONS CAD LK680D1 10/9/08 DRAWING NO: NSK 6.80-dl PART: REV: 2 OF 3 2 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductos 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. SEE LOUNSBURY DOCUMENT L-2539 FOR NAD27 INFORMATION. SUR VEYOR'S CER TI Fl CA TE —1,.' ij �� • h 0 I HEREBY CERTIFY THAT I AM PROPERLY • 0 REGISTERED AND LICENSED TO PRAC77CE • •• LAND SURVEYING IN THE STATE OF T J. ROOKUS i ALASKA AND THAT THIS PLAT REPRESENTS ♦ 0 A SURVEY DONE BY ME OR UNDER MY # ""k1) '•.,•Or LS-803 Jam,: DIRECT SUPERVISION AND THAT ALL ♦ 1Fp p•�1Z3 •'•gyp�i CORRECT AS AND OFF DECEMBER 23, 2008. +/,,,�\�I"M11��•• 0. LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA MODULE UNIT: __ I=inii P tiroIIeiuii WELL OCONDUCTOR D Cinlll ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-d1 3 OF 3 2 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, June 29, 2010 2:50 PM To: 'Quay Walter' Cc: DOA AOGCC Prudhoe Bay Subject: RE: OP12-01(PTD 210-069)and OP05-06 (PTD 210-080)Clarifications Walter, As per our conversation OP12-01 (PTD 210-069) and OP05-06 (PTD 210-080) do not require a diverter as outlined in the AOGCC waiver letter dated June 11, 2010. 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. 6/29/2010 0 O O O co M .0 O 00 N • • co O O qqr ti T � o - LL W U r Q o 0 O r r> o M. i 1 O co N O O v U E o G1 X • o O w Ne $ 00 L 0 'N Q Q a O O W O co O O O O O o O O O O O V. 0 0 0 0 0 0 0 CO TRANSMITTAL LETTER CHECKLIST WELL NAME A7/ "/C %4-> L-' PTD# 9 70 /Development Service Exploratory Stratigraphic Test Non-Co entional Well FIELD: l�w Sci L j;` POOL: - � l ! ( ,( Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 i T3 Cl) a> o- u) N a) O p _a as Ts E v Q N 0 Y U co 2 o c n a) U n m 0 3) 2 d -p 65 a > C N .N E• W' lf) C sn s- 0 n o O M o - o q c "o m a E co E O @ o n as rn 2 . N -c n co 0)2 O a ) O ui 9) 0) a co 3 N a) O) C so c•) a) 3 N 3 L •�Ta ca Cs co u 3 w a°) o - v >, as o a 2 n c 'o co -o o '5 - a> n N Q) CO O -p N S] N N C m a)- o N o ui = E D a o c > as N 0) (6 O Q U 7 E 3 o w co o m ° w 0. 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O a) a) a) 3 E 'O O) c Q o• N C 2 (o - 3 0 @ "513 O ° 0) N T "J N LL w a@i E a c°a 0 c 3 aci c°a m o .� @ r m a o N c o c°i m aci c o o co • a c u c m o 0 0 .0 ° ° ° o o a> o N o >c a a) o o - -° m `o m = N o- E -- a0 c 0 a) ° -°o c w 445 ° .E ° ° ° 0 10 a n a> a) (0 ° 3 2 0 0 0 2 2 2 co -o m o O O r ° °- 0 m co .8 aa)) o CO > a 2 N w O O a a U Q a Z U co U U U U Q Q w m m U N m a O co (n O W n N M � (( CO N 00 O) O N M V u<-) r O N r 0r 0 O.-) O N N N M V N N) N N N O N) (O Ch (N M h V M O CN h M CO M 7U o O O o s,• m o m o m o ° O C f6 N l0 N R N ° ° IX 0 0 p (° p N p (n m'y W 000 •� 1- 0) N 1- o (.0 0 o r cfl co cfl o•E J Cl) ai 0) o0 N CD E W O E a s c a 0 O. a o ; a Q < w Q C9 Q U Well History File �P " X Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 2n Eirii PtIroIIeLuIm FINAL WELL REPORT MUDLOGGING DATA NIKAITCHUQ OP05-06, OP05-06 PB1, OP05-06 PB2 OLIKTOK POINT, ALASKA t x a "lb in Alk '...111171111111111111111111111111111111.11"4"...." -- - CANRIG 1� ■ DRILLING;TECHNOLOGY LTI). Approved by: Andrew Buchanan Compiled by: Emil Opitz Zachary Beekman Tollef Winslow John Lundy Distribution: September 30, 2010 Date: September 6, 2010 0) 0 -- a-da 13 1 ,eni Eni Petroleum OP05-06, PB1 and PB2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT& CREW 3 1.1 Equipment Summary 3 1.2 Crew 4 2 WELL DETAILS 5 2.1 Well Summary 5 2.2 Hole Data 5 2.3 Well Synopsis 6 3 GEOLOGICAL DATA 7 3.1 Target and Offset Well Data 7 3.2 Formation Tops. 8 3.2.1 Surface and Intermediate Section 8 3.2.2 Production Section 9 3.2.3 PB1 9 3.2.4 PB2 9 3.3 Lithologic Descriptions/Stratigraphy 10 3.3.1 Main Wellbore 10 3.3.2 PB1 36 3.3.3 PB2 38 3.4 Connection Gas Summary 40 3.5 Trip/Wiper Gas Summary 40 3.6 Iso-Tube Sample Chromatography 41 3.7 Sampling Program And Sample Dispatch 42 4 PRESSURE/FORMATION STRENGTH DATA 43 4.1 Pore Pressure Gradient Evaluation 43 4.2 Quantitative Methods 43 5 DRILLING DATA 44 5.1 Daily Activity Summary 44 5.2 Survey Data 47 5.2.1 Main Wellbore 47 5.2.2 PB1 53 5.2.3 PB2 53 5.3 Bit Record 54 5.4 Mud Record: Surface and Intermediate Hole 55 5.5 Mud Record: Production Hole 56 6 DAILY REPORTS 57 Enclosures 2"/100' Formation Log (MD and TVD) 2"/100' Gas Ratio Log (MD and TVD) 2"/100' LWD Combo Log (MD and TVD) 2"/100' Drilling Dynamics Log (MD and ND) Show Reports Final Data CD 2 CANRIG E n i Petroleum OP05-06, PB1 and PB2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type/Position Downtime Comments (hours) Casing Pressure Cable to 1502 transducer for BOP 0 tests only. 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) 0 Toolpusher, office (wireless) Computer for Mud Engineer RigWatch Remote(HP Compaq) 0 Computer for Toolpusher RigWatch Remote(HP Compaq) 10 Rig Report Freezes Computers for Mudloggers(3) Data editing, RigWatch Master, and 0 RigWatch Remote(all HP Compaq) QGM Agitator Clean/repair/ Ditch gas (Mounted in possum belly) 4 adjust gas trap Flame Ionization Detector(FID) /chromatograph. Total Gas and Chromatography. Hook Load/Weight on bit Drilling Line Sensor on Rig Floor 0 Mud Flow In Derived from Strokes/Minute and 0 Pump Output 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 Draw Works Encoder 0 RPM PLC feed 0 Torque PLC feed 0 Wits In (LWD Data) LWD Computer to RigWatch 0 Master Computer 3 TA 1c ni Eni Petroleum OP05-06, PB1 and PB2 1.2 Crew Unit Number: ML059 Unit Type: Arctic/Steel Mudloggers Years of Days at Sample Years of Days at Technician Days at Experience OP05-06 Catchers Experience OP05-06 OP05-06 John Lundy 18 19 Doug Acker 1 30 Allan Williams 5 Zach Beekman 2 27 Steve Franzen 2 32 Howard Lamp 2 Emil Opitz 2 22 Tollef Winslow 2 14 4 CANRIC INA Eni Petroleum OP05-06, PB1 and PB2 2 WELL DETAILS 2.1 Well Summary Well: Nikaitchuq OP05-06 API Index#: 50-029-23427-00-00 Well: Nikaitchuq OP05-06 PB1 API Index#: 50-029-23427-00-70 Well: Nikaitchuq OP05-06 PB2 API Index#: 50-029-23427-00-71 Field: Nikaitchuq Surface Co-Ordinates: 3 182.4 FSL 1,604.3 FEL S5 T13N R9E UM Borough: North Slope Primary Targets: OA Sand of the Schrader Bluff State: Alaska Primary Target Depth: 8373'; -3738'TVDSS Rig Name/Type: NAD 245E/Arctic/Triple TD Depth: 17035' MD; -3940.34' TVDSS Spud Date: August 12, 2010 Ground Elevation: 12.2' MSL TD Date: September 6, 2010 RT Elevation: 53.26' MSL Days Drilling: 25 TD Formation: Schrader Bluff OA Sand Classification: Producer 2.2 Hole Data Maximum Depth Mud Shoe Depth Hole TD Weight Dev. Casing/ MD TVD - FIT MD TVD o Section (ft) (ft) Formation (PR) ( inc) Liner (ft) (ft) (ppg) Conductor 160 160 Recent 8.8 0 20 160 160 N/A casing 16" Surface 2425 2194.6 Ugnu 9.3 50.94 13-3/8" 2415 2188.3 11.00 Borehole casing 12-1/4" 8686 3839 Schrader 9.1 89.5 9-5/8 8671 3839 12.07 casing 8-1/2" 17035 3993.6 Schrader 8.8 94.01 5-1/2 16920 4000 -- liner 5 CCANRIG ink ,en'Eni Petroleum OP05-06, PB1 and PB2 2.3 Well Synopsis The Borehole extends from the surface to a TD at 17305' MD/-3940.34' TVDSS and has three sections designated by hole diameter: 16" Surface; 12-1/4" Intermediate; 8-1/2" Production Lateral. This well is designed as a production well. OP05-06 was spudded on the 12th of August 2010,entering a pre-set conductor pipe at a depth of 160'. 16" hole was drilled to a depth of 2425'. 13-3/8", 681b surface casing was set at 2415'MD/2188.35'TVD/- 2135.05'TVDSS. The float equipment and shoe were drilled out and new hole was drilled to 2450'.A Leak Off Test was performed to 11.0 ppg. The intermediate section was drilled with a hole diameter of 12-1/4" to a depth of 7036'MD Lack of steering control forced an open hole sidetrack. The rotary steerable BHA was removed. A downhole motor and appropriate BHA were picked up and the well was sidetracked at 6255'MD. The plugback well has been designated OP05-06 PB1. Drilling resumed at 6255'MD using a 12-1/4"tri-cone bit and drilled to a depth of 8686'MD. The rotary steering assembly was returned to operation at 8686'. 8-1/2" hole was drilled to 15433'MD. A fault was crossed at which point an open hole sid track was made at 14508' MD. This well was designated OP05-06 PB2. OP05-06 was drilled to TD of 17035' MD. 6 CANRIG IR _eni En! Petroleum OP05-06, PB1 and PB2 3 GEOLOGICAL DATA 3.1 Target and Offset Well Data OP05-06 Offset Well Data Prognosed Zone or Horizon Depth (ft) P03- OP-11 1 OP-12- OP26- PO3PB1 PB01 DSPO2 MD TVDSS TVDSS TVDSS TVDSS TVDSS SV-4 705.92 -652.4 -657.7 -659.1 SV-3 970.68 -910.1 -907.6 -902.8 SV-2 1253.13 -1173.5 -1174 -1169 -1163.2 SV-1 1834.53 -1678.5 -1671.1 -1671.2 -1647 -1648.1 Permafrost Base 1890.20 -1725.0 -1722.1 -1726.8 -1724.3 Ugnu Top (UG4) 2230.60 -1999.6 -1984.8 -1984.8 -1931.5 -1957.2 13 3/8" SCP 2409.10 -2120.0 UG-2 Coal Marker 3412.90 -2477.1 -2512.7 -2488.2 -2422 -2428.2 L Ugnu 6152.50 3147.8 -3140.3 -3274.3 -3060 -3122.5 Schrader Bluff 7012.22 3382.3 -3387.3 -3511.3 -3341.9 -3325 Fault 1 7187.00 -3435.1 Schrader Bluff 7221.10 -3445.3 N Sand Top 7583.30 -3551.7 N Sand Bottom 7811.30 -3613.5 -3523.5 -3640.5 -3424.4 -3423.3 OA Sand Top 8373.60 -3738.9 -3789.6 -3518.2 -3536.4 0A2 8540.00 -3757.8 9 7/8" ICP 8613.60 -3763.0 Total Depth 17046.40 -4037.2 7 CANRIG ,emu Eni Petroleum OP05-06, PB1 and PB2 3.2 Formation Tops: 3.2.1 Surface and Intermediate Section Depth (ft) Prognosed Depth (ft) Zone or Horizon MD TVD TVDSS MD TVD TVDSS 20"Conductor Shoe 160.0 160.0_ _ -106.7 160.0 160.0 -106.8 SV-4 712.0 710.5 -657.2 705.9 705.7 -652.4 SV-3 970.0 961.8 -908.5 970.7 963.4 -910.1 SV-2 1247.0 1221.2 -1167.9 1253.1 1226.8 -1173.5 SV-1 1795.0 1709.6 -1656.3 1834.5 1731.8 -1678.5 Permafrost Base 1879.0 1785.0 -1731.7 1890.2 1778.3 -1725.0 Ugnu Top (UG4) 2195.0 2041.5 -1988.2 2230.6 2052.9 -1999.6 13 3/8"Casing Shoe 2415.6 2188.7 -2135.4 2409.1 2173.3 -2120.0 TD 16"Surface Hole 2425.0 2194.6 -2141.3 2409.1 2173.3 -2120.0 UG-2 Coal Marker 3000.5 2489.6 -2436.3 3412.9 2530.4 -2477.1 Lower Ugnu 6170.0 3196.6 -3143.3 6152.5 3201.1 -3147.8 Fault 1 6998.0 3466.1 -3412.8 not expected n/a N Sequence Top 7035.0 3476.4 -3423.1 not expected n/a N Sand Top 7198.0 3519.9 -3466.6 n/a n/a n/a Fault 2 7245.0 3532.0 -3478.7 7187.0 3488.4 -3435.1 Schrader Bluff 7314.0 3549.6 -3496.3 7221.1 3498.6 -3445.3 N Sequence Top 7517.0 3600.3 -3547.0 7403.8 3552.3 -3499.0 N Sand Top 7686.5 3643.5 -3590.2 7583.3 3605.0 -3551.7 N sbl2 7765.0 3661.2 -3607.8 n/a n/a n/a N sbl3 7850.0 3678.8 -3625.5 n/a n/a n/a N Sand Base 7928.0 3695.6 -3642.3 7811.3 3666.8 -3613.5 Lower N Marker 8021.0 3716.9 -3663.6 n/a n/a n/a N Sequence Base 8140.0 3744.7 -3691.4 8004.4 3714.0 -3660.7 OA sbll 8423.3 3804.8 -3751.5 8373.6 3792.2 -3738.9 OA sb12 8497.0 3817.3 -3764.0 8540.0 3811.1 -3757.8 OA sbl3 8566.5 3825.3 -3772.0 n/a n/a n/a 9 5/8"Casing Shoe 8671.0 3831.8 -3778.6 8613.6 3816.3 -3763.0 TD 12 1/4" Borehole 8686.0 3831.8 -3778.6 8613.6 3816.3 -3763.0 -- 8 C VA�!RIV IA ,eni Eni Petroleum OP05-06, PB1 and PB2 3.2.2 Production Section Depth (ft) Prognosed Depth (ft) Zone or Horizon MD TVD TVDSS MD TVD TVDSS Fault 3 8948.0 3831.6 -3778.3 8900.0 3840.0 -3786.7 OA sbl2 9100.0 3839.1 -3785.9 n/a n/a n/a OA sbl3 9335.0 3848.6 -3795.3 n/a n/a n/a OA sbl3 10406.0 3838.6 -3785.3 n/a n/a n/a OA sbl2 10591.0 3829.6 -3776.4 n/a n/a n/a OA sbl2 11649.0 3839.0 -3785.2 n/a n/a n/a OA sbl3 11876.0 3852.9 -3799.7 n/a n/a n/a Fault 4 12762.0 3895.4 -3841.9 n/a n/a n/a OA sbl3 13450.0 3899.1 -3845.8 n/a n/a n/a OA sbl2 13508.0 3896.1 -3842.8 n/a n/a n/a OA sbll 13578.0 3892.9 -3839.7 n/a n/a n/a OA sbll 13776.0 3896.9 -3843.7 n/a n/a n/a OA sbl2 14460.0 3924.6 -3871.4 n/a n/a n/a OA sbl2 14912.5 3945.7 -3892.4 n/a n/a n/a Fault 5 15168.5 3956.5 -3903.2 n/a n/a n/a OA sbl3 16300.0 3992.6 -3939.3 n/a n/a n/a OA sbl2 16472.0 3995.9 -3942.6 n/a n/a n/a OA sbll 16895.0 4002.0 -3948.7 n/a n/a n/a TD 8 1/2" Borehole 17035.0 3993.6 -3940.3 17046.4 4073.0 -4019.7 3.2.3 PB1 Depth (ft) Prognosed Depth (ft) Zone or Horizon MD TVD TVDSS MD TVD TVDSS Sidetrack Point PB1 6239.0 3214.9 -3161.6 n/a n/a n/a Fault 1 7000.3 3414.6 -3361.3 n/a n/a n/a TD OP05-06 PB1 7035.0 3424.2 -3370.9 not expected n/a 3.2.4 PB2 Depth (ft) Prognosed Depth (ft) Zone or Horizon MD TVD TVDSS MD TVD TVDSS Sidetrack Point PB2 14603.0 3933.0 -3879.7 n/a n/a n/a OA sbl3 14845.0 3944.3 -3891.0 n/a n/a n/a Fault 5 15193.0 3970.6 -3917.3 n/a n/a n/a OA sbl3 15284.6 3977.0 -3923.7 n/a n/a n/a TD OP05-06 PB2 15433.0 3994.1 -3940.8 n/a n/a n/a 9 CANRIG tri Eni Petroleum OP05-06, PB1 and PB2 3.3 Lithologic Descriptions/Stratigraphv 3.3.1 Main Wel!bore The Permafrost section of the OP05-06 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 and contained no oil shows; some minor methane hydrates were encountered. PERMAFROST AND RECENT/QUATERNARY DEPOSITS SURFACE TO 2195.0'MD/1988.2'TVDSS This interval extends from surface down to the top of the Ugnu at 2230.55' 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. Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 802.9 27.4 119.4 485 0 90.8 PEAKS Depth TG C1 C2 C3 C41 C4N C51 C5N 1300 261 52176 1478 307 60589 1510 297 59109 1568 372 72222 1842 485 97345 1900 300 60237 • 2116 157 30897 SV4 712'MD/657.2'TVDSS SV3 970'MD/908.5'TVDSS Claystone(1000-1090)=medium light gray to medium dark gray to brownish black; no cohesive or adhesive properties exist; curdy consistency; dull earthy luster; clayey to silty texture; no reaction to HCI. Sand (1000-1090) = transparent to light gray to brownish gray unconsolidated sand; upper fine to upper medium grained;poorly sorted;angular with low to moderate sphericity;conglomeratic sand pieces are firm to moderately hard and react very slightly to HCI; pyrite is abundant(>5%); occurs as individual grains and as growths on other grains. Claystone(1090-1120)=light gray to olive gray to medium dark gray;slightly adhesive and slightly cohesive; clumpy pasty consistency; waxy earthy luster; smooth to clayey texture to locally gritty to granular due to reworked sand grains; no reaction to HCI. 10 ail► + Eni Petroleum ieni OP05-06, PB1 and PB2 Claystone(1120-1180)=olive gray to medium dark gray to brownish gray throughout sample interval;slightly adhesive; slightly cohesive when prodded samples coming over shakers mechanically reworked globular masses containing sand grains;dull earthy luster;smooth clayey texture to gritty where reworked sand grains present; amount of sand decreases with depth throughout sample interval; no visible structures present. Claystone(1180-1240)=medium light gray to olive gray to brownish gray;moderately cohesive;very slightly adhesive;clumpy to pasty consistency;globular masses clump together in sieve and sample tray showing no visible structure; smooth clayey texture with decreasing sand content; no reaction to HCI. SV2 1247'M D/-1167.9'TVDSS Claystone (1240-1300) = medium light gray with a slight brownish secondary hue; soft to slightly firm; samples collected as clay masses with adherent sand; interbedded with thin to moderate beds of medium lower to medium upper and fine upper grain clay matrix sand with trace to abundant small dark gray chert and lithic pebbles and pebble fragments; sand and pebbles worked into the clay masses by circulation/solids removal;silky/clayey to gritty texture;dull earthy luster;moderately cohesive;slightly to moderately adhesive; slightly hydrophilic; non to trace calcareous; no oil indicators. Sand/Conglomeritic Sand/Conglomerate(1300-1420)=medium to medium dark gray with a slight brownish secondary hue; soft to disaggregated; medium lower to fine upper and coarse grain sand with abundant 3 to 10 mm pebbles/pebble fragments;finer material is sub-angular to sub spheroidal in the finer material;coarse varies from sub-angular to slightly and moderately well rounded as grain size increases;sand is about evenly divided between clear to translucent quartz and medium to light and dark gray with trace olive and brown grains;coarser material is dominated by dark gray chert and lithics with trace to common well rounded small white quartzite pebbles; matrix supported; some grain support in part; matrix is light to medium light clay similar to the overlying claystone; trace to non calcareous; no oil indicators. Claystone (1420-1510) = medium light gray with a slight brownish secondary hue; soft to slightly firm; samples collected as clay masses with adherent sand; trace to locally abundant small dark gray chert pebbles; trace pyrite as small microcrystalline masses; some pebbles heavily pyritic; silky/clayey to gritty texture; dull earthy luster; moderately cohesive; moderately cohesive; sticky/adhesive; non to slightly hydrophilic; non calcareous; no oil indicators. Sand/Sandstone Conglomerate (1450-1620) = medium light to medium dark gray with a slight brownish secondary hue; soft to disaggregated;vertically sorted through the interval; locally well sorted; upper part of the zone is very clayey fine lower to very fine upper quartz and light gray lithic sand; as sand cleans up at 1570' sample material becomes fine upper to medium lower and fine lower; 50 to 60% clear to translucent white quartz; balance is medium to light and dark dray lithics,dark gray and black chert/volcanics and lithics; becomes conglomeratic at the base of the zone; pebbles have the same lithology as the associated sand; common to abundant pyrite as small micro-crystalline masses;appears pyrite is a secondary cementing agent; some pebbles are heavily pyritic; primarily matrix supported in the upper zone, grain supported in the base; non to trace calcareous; trace C-2 gas; no oil indicators. Claystone (1630-1750) = medium light gray; soft to slightly firm; samples collected as clay masses with adherent sand; trace small, dark gray to black chert and medium to light gray lithic pebbles; trace pyrite as small micro-crystalline masses;some pebbles heavily pyritic;silky/clayey texture;dull earthy luster;sticky/very to moderately cohesive; moderately adhesive; non to slightly hydrophilic; trace partially decomposed wood; trace white tabular calcite; trace calcareous; no oil indicators. Sand/Sandstone (1720-1840) = medium light gray with a slight brownish secondary hue; soft to disaggregated;moderately well to well sorted;material is collected as very sandy clay masses and loose sand; appears to me primarily clay matrix sandstone with locally grain supported interbeds;fine upper to fine lower and scattered medium grain;trace to scattered small pebbles and pebble fragments;angular to sub-angular in the sand range;pebbles are moderately well to slightly rounded and show some remnant surface undulations; primarily clear to translucent quartz; 30 to 40%medium and light gray lithics trace to common olive and light 11 CANRIG 11, _eni Eni Petroleum OP05-06, PB1 and PB2 brown lithic/mineral grains;trace light green grains;common pyrite as small micro-crystalline masses;trace to common thin black carbonaceous lamina fragments non calcareous; no oil indicators. SV-1 1795'MD/-1656.3'TVDSS Permafrost Base 1879'MD/-1731.7'TVDSS Sand/Sandstone (1840-1930) = medium light gray with a slight brownish secondary hue; soft to disaggregated;moderately well to well sorted;material is collected as loose sand with occasional loose sandy clay masses appears to me primarily matrix supported with occasional clean grain supported intervals; fine upper to fine lower grain scattered medium grain; scattered small pebbles and pebble fragments;angular to sub-angular in the sand range;pebbles are moderately well to slightly rounded;50 to 60%clear to translucent quartz; balance is medium and light gray lithics with trace to common olive and light brown lithic/mineral grains;trace light green grains;common pyrite as small micro-crystalline masses and occasionally as surface encrustations on pebbles;trace to common thin black carbonaceous lamina fragments; non calcareous;no oil indicators. Claystone(1900-2020)=medium light gray;soft to slightly firm;samples collected as sandy clay masses and loose sand; scattered 3 to 5 mm gray chert pebbles;trace pyrite as small micro-crystalline masses;clayey to gritty/sandy texture; dull earthy to satiny luster; sticky/very to moderately cohesive; moderately adhesive; slightly hydrophilic; interbedded with and grading to associated similar clayey sand; non calcareous; no oil indicators. Claystone (2020-2080) = light gray to medium gray overall; very soft to soft; samples collected are silty clayey masses with reworked sands throughout; dull earthy to slightly waxy luster; clayey to silty texture to locally gritty; moderately cohesive;moderately adhesive;interbedded sands and clays;sands decreasing with depth throughout interval; no reaction to HCI; no oil indicators. Claystone(2080-2140)=medium light gray with secondary hue of yellowish brown;soft to slightly firm;clayey to silty/gritty texture;dull earthy to satiny luster;trace pyrite as gritty masses;trace light green and dark brown lithics; sticky/moderately cohesive; slightly adhesive; non to slightly hydrophilic; non calcareous; no oil indicators. Sand (2140-2200)=translucent to milky white to olive gray to medium dark gray; lower fine to upper fine to lower medium grain;well sorted; sub angular to angular to few sub rounded with moderate to low sphericity; trace pyrite found in sample interval as crystalline grains;coal bed found with interval 2140 to 2170; brownish black to dark reddish brown;friable to firm;blocky fracture;wedge like tabular cuttings habit;dull earthy luster to slightly resinous; matte to slightly mottled texture; no visible structures. Claystone(2200-2290)=medium dark gray to brownish gray to olive gray throughout sample interval;soft to slightly firm; reworked globular masses coming over shakers; curdy to pasty to somewhat clumpy sample consistency; dull waxy to earthy luster; clayey to silty texture to gritty in parts; sand reworked into clayey masses but decreasing with depth; trace pyrite and orange lithics found throughout sample interval; moderately cohesive slightly adhesive;slightly hydrophilic;no visible structures exist; no reaction to HCI;no oil indicators. UGNU TOP(UG4)2195' MD/-1988.2'TVDSS The Ugnu is an Upper Cretaceous and Lower Tertiary shallow marine and deltaic deposit. The Ugnu, in places,contains oil which is bitumen and extra heavy crude with API gravities between 8°and 12°. OP05-06 encountered the Upper Ugnu (also known as the"L"sand) at 2195' MD, continuing to the Lower Ugnu (also known as the"M"sand)at 6170' MD and leaving the Ugnu when it crossed a fault at 6998' MD. The Upper Ugnu is characterized by interbedded layers of sand,sandstone and claystone with occasional coal beds. The sands are primarily upper fine to lower medium in size. At 3000.5' MD the UG-2 Coal Bed Marker was encountered. The Lower Ugnu is an unconsolidated sand of upper fine to lower medium grains with thin beds of carbonaceous material. The OP05-06 did not encounter any oil indicators in the Upper Ugnu, but in the 12 CANRIG eni Eni Petroleum OP05-06, PB1 and PB2 Lower Ugnu, dull yellow ultra violet fluorescence increasing to a faint light yellow ultra violet fluorescence as the depth increased. Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 389.5 8.4 179.4 427 0 58.9 PEAKS Depth TG C1 C2 C3 C4I C4N C5I C5N 2645 80.3 15996 2996 187.0 37407 3098 106.9 21979 3450 91.2 19370 3821 110.4 24008 4024 115.1 25250 4070 113.4 28747 4785 98.6 22759 5512 229.1 46045 5985 270.8 54374 6180 186.0 41980 Claystone(2200-2290)=medium dark gray to brownish gray to olive gray throughout sample interval;soft to slightly firm; reworked globular masses coming over shakers; curdy to pasty to somewhat clumpy sample consistency; dull waxy to earthy luster; clayey to silty texture to gritty in parts; sand reworked into clayey masses but decreasing with depth; trace pyrite and orange lithics found throughout sample interval; moderately cohesive slightly adhesive;slightly hydrophilic;no visible structures exist;no reaction to HCI;no oil indicators. Sand/Sandstone (2290-2380) = transparent to translucent to light gray to medium dark gray throughout sample interval;friable to firm; upper fine to upper medium grained with trace lower fine grains; moderately to well sorted; sub angular to sub rounded with few angular grains; moderate to high sphericity; predominately quartz sand (50-60%); seems to be grain supported for the most part; trace accessory minerals including pyrite, muscovite, trace orange lithics; abundant pale green to light green to brilliant green glauconite; sub rounded to sub angular; low to moderate sphericity; non calcareous; no oil indicators. Claystone (2380-2425) = medium light gray to brownish gray; soft to slightly firm; samples are pasty to mushy; moderately cohesive; slightly adhesive; satiny earthy luster; clayey silty texture; no oil indicators. 13 3/8 SCP a 2415' MD/-2135.4' TVDSS Sand(2430-2560)=medium light gray with a very slight greenish secondary hue;samples collected as loose disaggregated sand; well sorted; friable; fine upper to medium lower and fine upper grain; angular to sub- angular;trace sub-rounded;predominantly clear to translucent white quartz;trace medium gray to black lithics; trace to common clayey light gray lithics;trace to common glauconite and green stained quartz;trace black pyritic coal fines; quartz grains are lightly frosted with cement overgrowth; appears to be primarily grain supported; no remnant matrix material noted in samples; trace calcite fracture fill; overall very slightly calcareous; trace thin coaly interbeds in the upper part of the section; no oil indicators. note: un-dissolved polymer in samples. Sand (2560-2710) = medium light gray with a slight greenish to brownish secondary hue; soft to disaggregated; friable; sample collected as loose sand; no matrix material noted in samples; well sorted; medium lower to fine upper grain;trace medium upper and fine upper grain;sub-angular to sub-spheroidal and sub-rounded; clear to translucent white quartz predominates; common medium to light gray lithic/mineral 13 CANRIG ift ,eni Eni Petroleum OP05-06, PB1 and PB2 grains;trace to common green stained quartz and glauconite;trace brown lithics;trace orange jasper as flakes and fine grains;trace to common pyritic coal fines and dark gray to black lithic/mineral grains;trace fine grain micro-crystalline pyrite masses; trace very light gray to white calcite fracture fill; quartz grains are slightly frosted/pitted; locally common carbonaceous shale and poor quality lignite coal; slightly calcareous; no oil indicators; note: un-dissolved polymer(fluorescent) in samples. Sand/Sandstone(2710-2840)=medium light gray with a slight greenish to brownish secondary hue;sample collected as loose disaggregated sand;friable; moderately well sorted; medium lower to fine upper and fine lower grain; common medium upper grains; scattered coarse grain sand; sub-angular to angular and sub spheroidal;trace sub-rounded grains; primarily clear colorless to translucent white quartz;20 to 40%medium to light and dark gray lithics;trace black mafic mineral/volcanics;trace fine to medium grain pyritic coal fines; trace soft clay supported sandstone;trace hard silica cemented sandstone fragments with abundant pyrite in pore spaces;trace blue gray,gray-green and brown lithics;trace bright orange and red jasper;occasional thin silty coal and siltstone interbeds; trace white calcite fracture fill; slightly calcareous; no oil indicators. Sand/Sandstone(2840-2960)=medium light gray with a slight greenish to brownish secondary hue;sample collected as loose disaggregated sand with scattered to common moderately firm clayey sandstone fragments; friable in part; moderately well sorted;medium upper medium lower and fine upper grain;common fine lower; scattered very coarse and small pebble fragments; sub-angular to angular and sub-spheroidal; trace sub- rounded; approximately 50%clear colorless to translucent white quartz; 30 to 40% light to medium and dark gray lithics; common to abundant glauconite and green stained quartz; trace to common dark gray to black mafic mineral grains; trace coal fines; trace blue gray, greenish gray and brown grains; trace brick red and mottled yellow/gray jasper and thinly banded gray/white chert; occasional thin coal and siltstone interbeds; trace brownish clay; trace calcite; slightly calcareous; no oil indicators. Coal(2950-3000)=very dark gray to black;very firm to firm; crumbly; hackly in part;displays some remnant woody characteristics; irregular splintery to slightly tabular habit; no mature coal characteristics;silty to shaly in part; interbedded with thin sand,silt and clays;trace brown clay shows trace dead oil;dull blue fluor-escence; slow streaming cut to dull milky blue;slight trace brown residue fluoresces dull yellow and cuts to dull blue; no odor. Ugnu-2 Coal Bed Marker 3000.7' MD/-2436.3'TVDSS Sand/Sandstone/Conglomerate (2960-3180) = medium light gray with a slight greenish secondary hue; sample collected as loose disaggregated sand imbedded in soft hydrophilic clay;friable in part;medium lower to fine upper and medium upper and coarse lower;trace to common coarse upper;common small pebbles and pebble fragments to 5mm;sub-angular to angular and sub-spheroidal;trace sub-rounded;approximately 60% clear colorless to translucent white quartz; 20 to 30% light to medium and dark gray lithics; common to abundant glauconite and green stained quartz;trace to common dark gray to black mafic mineral grains;trace coal fines; trace blue gray, greenish gray and brown grains; trace brick red and mottled yellow/gray jasper; interbedded with moderate coals and thin siltstone and brownish gray clay; apparently matrix supported; matrix is light brownish gray hydrophilic clay; trace dull blue fluorescence; slow streaming cut to dull milky blue; slight trace brown residue fluoresces dull yellow and cuts to dull blue; no odor; slightly calcareous. Sand/Sandstone(3180-3310)=medium light gray;soft to disaggregated;friable; moderately to moderately well sorted; sub-angular to angular; coarse lower to medium upper, coarse upper and medium lower grain; trace very coarse; clear translucent slightly frosted to translucent white quartz predominates; common to abundant medium to light gray lithic/mineral grains;common green stained quartz and glauconite;trace blue- gray,greenish gray, brown;and yellow grains;trace brick red to orange jasper;trace to common pyrite;trace dark gray to black mafic mineral/lithics; trace coal fines; trace calcite; apparently matrix supported in light brownish gray clay; some local grain support; moderate beds with thinner clay and occasional coaly inter- beds;slightly calcareous;trace dull blue to dull greenish yellow fluorescence;slow streaming cut to dull milky blue; slight trace brown residue fluoresces dull yellow and cuts to dull blue; no odor. Sand/Sandstone(3180-3440)=medium light gray; soft to disaggregated;friable; moderately to moderately well sorted;sub-angular to angular;medium lower to medium upper,coarse lower and fine upper grain;trace 14 CANRIG ieni Eni Petroleum OP05-06, PB1 and PB2 very coarse;clear translucent slightly frosted to translucent white quartz predominates;common to abundant medium to light gray lithic/mineral grains; common green stained quartz and glauconite; trace blue-gray, greenish gray, brown; and yellow grains; trace brick red to orange jasper; trace to common pyrite as small microcrystalline masses and inclusions in lithic sand grains; occasional medium grain size pyrite crystals; common dark gray to black mafic mineral/lithics;trace coal fines;trace calcite;apparently matrix supported in light brownish gray clay;some local grain support;moderate beds with thinner clay and occasional coaly inter- beds; slightly calcareous. no oil indicators. Sand/Sandstone (3440-3540) = medium light gray with a slight brownish secondary hue; soft to disaggregated; moderately well sorted; angular to sub- angular and sub spheroidal; clear transparent to translucent white quartz predominates; common to abundant medium to light gray lithics; common to trace dark gray to black mafic mineral/lithics; trace pyrite; trace blue-gray, green and brown lithic/mineral grains; trace brick red to orange jasper; trace calcite; apparently matrix supported throughout, sample becomes dominantly fine upper grain and is collected as soft irregular clay matrix fragments at 3550';occasional trace fluorescence as described above; very slightly calcareous. Sand/Sandstone(3550-3640) = light gray to medium light gray overall; soft to disaggregated; lower fine to upper medium grained; sub rounded to sub angular with moderate sphericity; moderate to well sorted throughout sample interval; common to trace dark lithics; trace pyrite and other accessory minerals; predominately transparent to translucent milky white quartz; common to abundant medium gray to brownish gray lithics throughout sample interval;trace to common light green to brilliant green lithics around 3640'; non calcareous; trace fluorescence in the 3640' sample; no odor present and no cut or residue. Sand/Sandstone(3640-3730)=medium light gray to olive gray throughout sample interval;disaggregated to soft to slightly firm; lower medium to lower coarse grain; moderately sorted; rounded to surrounded to occasional sub angular; moderate to high sphericity; clear transparent to translucent to milky white frosted quartz;trace pyrite as individual crystalline grains and as growths on other grains;common to abundant pale blue green to moderate blue green glauconite; lower medium to upper fine;sub rounded to rounded;trace to scattered dark gray to olive black mafic/lithics; seems to still be clay matrix but washing most out when sample is cleaned. none to trace fluorescence. no odor or cut. Sand/Sandstone(3730-3790)=light gray to light olive gray to light brownish gray throughout interval; lower fine to lower medium with occasional upper medium; moderately well sorted;subrounded to sub angular; low to moderate sphericity; soft to easily friable;trace pyrite as individual grains and locally as cementing agent; slightly calcareous; no oil indicators. Sand/Sandstone(3790-3880) = medium light gray to brownish gray overall; easily friable to friable to firm; upper fine to upper medium with occasional lower coarse;well sorted;sub rounded to sub angular;moderate to low sphericity; translucent to transparent to frosted quartz predominates; trace orange lithics; trace to common brownish black to black mafic;trace to common pale blue green to moderate blue lithics;glauconite decreasing with depth;trace pyrite in sample interval predominately fine grain crystalline and growths on other grains; slightly to moderately calcareous; no oil indicators present. Sand/Sandstone(3880-3970)=light gray to medium gray to olive gray overall; upper fine to upper medium grained; moderate to well sorted;subrounded to sub angular to locally rounded; moderate to sub-spheroidal; predominately clear transparent to translucent quartz; firm friable to occasional moderately hard; trace fine grain orange lithics and bluish green glauconite;clay matrix becomes more prominent with depth;clay matrix noticeable in 3970'sample;trace pyrite is found as microcrystalline masses to few medium grained;very few small minor low grade coals throughout sample interval; trace sample fluorescence; no odor and no cut present. Sand/Sandstone(3970-4060)=medium light gray with secondary brownish hue;upper fine to upper medium to trace lower coarse; moderate to well sorted;subrounded to sub angular;moderate to high sphericity;soft to disaggregated to locally firm; apparently matrix supported; clay matrix is slightly visible but is mostly being washed away with sample cleaning;trace to scattered pale blue green to brilliant green to moderate blue fine 15 C:ANRIG eni Eni Petroleum OP05-06, PB1 and PB2 grained glauconite;coal layer found in the 4060'sample interval;dark brown to reddish black; blocky;tabular cuttings habit; earthy resinous luster; matte texture; very slightly calcareous; no oil indicators. Sand/Siltstone(4060-4150)=light gray to medium light gray to olive gray throughout sample interval;friable to firm to locally hard; lower fine to upper medium grain;moderate to well sorted;subrounded to sub angular to trace angular; moderate sphericity; translucent to milky white quartz predominates; trace to common pyrite within sample interval mostly as growths on other minerals; light gray to medium gray to brownish gray accessory minerals are common; trace fine grained orange lithics;trace to common light bluish gray to pale blue green glauconite; fine to medium grained; samples are slightly calcareous; no oil indicators. Claystone(4150-4210)=pinkish gray to medium light gray;curdy clumpy consistency;dull earthy luster;silty gritty texture; reworked sand grains create gritty texture; no structures present within sample interval;trace to common reddish black to brownish black coal fragments; wedge like and splintery; trace grains of pyrite; sample is slightly calcareous; no oil indicators. Claystone (4210-4270) = light gray to medium gray to slight brownish gray overall; mushy to pasty consistency; moderately cohesive; slightly adhesive to moderately adhesive when prodded; earthy waxy luster; silty to gritty texture; so visible structures present; scattered brownish black splintered fragments of a silty coal layer; trace pyrite and other accessory minerals; non calcareous; no oil indicators. Sand/Sandstone(4270-4330) = light gray to medium gray to olive gray; lower fine to upper medium grain; well to moderately well sorted; sub angular to subrounded to trace angular; moderate to sub-spheroidal; disaggregated to soft to friable; clay content has decreased to small clayey masses containing sand grains; predominately colorless transparent to translucent quartz; non calcareous; no oil indicators. Sand/Sandstone(4330-4420)= light gray to medium light gray to medium gray throughout sample interval; lower fine to upper medium to trace lower coarse;well sorted to very well sorted; subrounded to sub angular with moderate to high sphericity; predominately clear transparent to translucent to very light gray quartz; disaggregated soft;clay matrix visible as soft,clumpy,hydrophilic clay masses supporting fine grained sands; trace orange and yellow fine grained lithics; scattered to common fine grained black lithic giving a salt and pepper appearance; trace light green fine grained glauconite; no reaction to HCI; no oil indicators. Sand/Sandstone(4420-4480)= medium light gray to olive gray overall; lower medium to upper medium to trace lower coarse; poor to moderate sorting; sub angular to subrounded; moderate to low sphericity; disaggregated to friable; very slightly calcareous; no oil indicators. Sand/Sandstone(4480-4600)=light gray to medium gray to olive gray throughout sample interval;upper fine to lower medium to trace upper medium; poor to moderate sorting; subrounded to sub-angular; moderate to sub-spheroidal; disaggregated; soft to friable to occasional firm; predominately translucent to milky white to colorless transparent quartz; few quartz grains etched and slightly frosted; clay matrix becoming more apparent with depth in sample interval; trace orange and yellow lithics; common to abundant medium gray, brownish gray, dark gray and olive black grains/lithics through sample interval; green stained quartz and glauconite grains;trace to common very pale green to pale blue green to moderate green glauconite;fine to medium grained; trace pyrite microcrystalline masses; non calcareous; no oil indicators. Claystone (4600-4660) = light gray to medium light gray to light brownish gray overall; curdy clumpy consistency; moderately to very cohesive; little to slightly adhesive; hydrophilic;waxy earthy luster;silty gritty texture,slightly gritty due to reworking very fine grained sands;almost silty in some clayey masses; no visible structures present; no reaction to HCI; no oil indicators. Claystone (4660-4720) = medium light gray to light brownish gray to light olive gray overall; lumpy pasty consistency; moderately to very cohesive; slightly to moderately adhesive when prodded; hydrophilic; dull earthy luster; silty to gritty texture, clayey siltstone to silty claystone; common to abundant very fine to fine grained black lithics;trace very fine orange and fine greenish gray lithics; no oil indicators. 16 CANRIG -ten'Eni Petroleum OP05-06, PB1 and PB2 Claystone(4720-4780)=light gray to medium light gray to brownish gray overall;curdy to pasty consistency; moderately to very cohesive; very little to slightly adhesive; dull earthy to slightly waxy luster; gritty to silty texture;common to abundant black lithic fragments;trace very fine to fine grain orange lithics and light bluish gray to grayish blue green glauconite; no visible structures; no oil indicators. Sand/Sandstone(4780-4840)=light gray to medium gray to light brownish gray throughout sample interval; lower fine to upper medium to upper very fine; moderately to well sorted; sub angular to subrounded; moderate to high sphericity; very soft, disaggregated; clay matrix forming clayey masses in sample trays; scattered dark yellowish orange to dusky brown pebbles 5mm in sample interval; non calcareous; no oil indicators. Sandstone/Siltstone(4840-4930)= light to medium light gray with a slight brownish secondary hue; soft to disaggregated; samples collected as irregular lumpy masses of disaggregated silt with variable amounts of loose sand; included sand is very fine upper to fine lower a very fine lower with trace to common medium lower grains; predominantly angular to sub-angular;translucent white to clear quartz predominates; trace to common medium, light and dark gray lithics;trace small micro-crystalline pyrite masses;scattered fine ground shell fragments; very slightly calcareous; no oil indicators. Sandstone/Siltstone(4930-5060)= light to medium light gray with a slight brownish secondary hue; soft to disaggregated; samples collected as irregular lumpy masses of disaggregated loose sand imbedded in hydrophilic siltstone matrix;well to moderately well sorted;vertically sorted in moderately thick beds;very fine upper to fine lower in the upper portion grading to medium lower to medium upper and fine upper with increasing depth;trace coarse angular ironstone fragments;sub-angular to angular and sub-spheroidal grains; primarily translucent white to clear colorless quartz; common light to medium gray lithics; trace dark gray to black mafic mineral grains;trace brown mineral grains;trace to common thin carbonaceous lamina fragments; matrix supported in light to very light brownish gray silt; very slightly calcareous; no oil indicators. Sandstone/Siltstone(5060-5180)= light to medium light gray with a slight brownish secondary hue;soft to disaggregated; samples collected as irregular lumpy masses of disaggregated loose sand imbedded in hydrophilic siltstone matrix; matrix is easily washed away in sample preparation; this section is somewhat more sandy than previously observed; well to moderately well sorted; vertically sorted in moderately thick beds; very fine upper to fine lower in the upper portion grading to medium lower to medium upper and fine upper with increasing depth; trace coarse angular ironstone fragments; sub-angular to angular and sub- spheroidal grains; primarily translucent white to clear colorless quartz; common light to medium gray lithics; trace dark gray to black mafic mineral grains;trace brown mineral grains;trace to common thin carbonaceous lamina fragments; matrix supported in light to very light brownish gray silt; very slightly calcareous; no oil indicators. Sandstone/Siltstone(5180-5350)=medium light to light gray with a slight brownish secondary hue;samples collected as irregular masses of disaggregated loose sand in hydrophilic silt matrix; matrix material is easily lost in sample preparation;well to moderately well sorted; moderate to fairly thickly bedded;vertically sorted beds coarsening with depth; very fine upper to fine upper in the upper portion grading to medium lower and fine upper as depth increases; trace medium upper grains throughout; trace coarse grain size angular ironstone fragments; occasional thin very hard ironstone concretions; individual grains are sub-angular to angular and sub-spheroidal;primarily translucent white to clear colorless quartz;common light to medium gray lithics; trace dark gray to black mafic mineral grains; trace brown mineral grains; scattered blue-gray and orange grains; generally matrix supported in light to very light brownish gray silt; locally shows some grain support;trace very small micro-crystalline pyrite masses;occasional pyrite encrusted sand grains;trace point source effervescence with HCI; no oil indicators. Sandstone/Siltstone(5350-5500)=light to medium light gray with a slight brownish gray secondary hue;soft to disaggregated;well to moderately sorted;vertically sorted in moderate beds;fine lower to very fine upper in the upper portion grading to medium lower to fine upper and very fine upper with increasing depth; trace medium upper and coarse grains throughout; common small pebble fragments in the 5380' sample; sub- angular to angular and occasionally sub-spheroidal; translucent white to clear colorless and slightly smoky 17 CAIVRIG Eni Petroleum OP05-06, PB1 and PB2 quartz predominates; common to locally abundant medium to dark and light gray lithics; trace dark gray to black mafic mineral/lithics;trace to common brown,blue-gray and greenish gray;trace to common brick red to orange jasper; trace pyrite; trace muscovite mica; abundant to trace thin black carbonaceous lamina and medium to fine grain clastic coal; generally matrix supported in light to very light gray silt; sample at 5500' displays no visible matrix; matrix material is hydrophilic and easily washed away in sample preparation; non to trace calcareous; no oil indicators. Sandstone/Siltstone (5500-5620) = light to medium light gray with a brownish secondary hue; samples collected as soft to masses of silty sand and loose sand; moderately well to well sorted; vertically sorted in moderately thick beds; friable in part; fine lower to very fine upper and fine upper in the top of the section; grades to medium lower and fine at the base;trace medium upper throughout becomes common at the base; sub-angular to angular in finer range; larger grains tend to be angular;translucent white to clear colorless and smokey quartz predominate 20 to 30% medium to dark and light gray lithics; trace brown and blue gray lithic/mineral grains; scattered to trace orange and rose jasper;trace pyrite;trace to common fine to medium grain carbonaceous grains; slightly calcareous primarily from point source effervescence. Sandstone/Siltstone(5620-5720)= light to medium light gray with a slight brownish secondary hue;soft to disaggregated; sample consists of loose sand with scattered masses of soft silty sand and occasional silty/ashy sandstone fragments;moderately well to well sorted;very fine upper to fine lower and medium lower grain; vertically sorted beds fining from the top down as depth increases; medium lower to fine upper dominates the basal sample; sub-angular to angular grain; translucent white to smokey and colorless clear quartz predominate; 20 to 30% medium to light and dark gray lithics; trace black mafic mineral/lithics; trace brown, blue-gray and gray-green grains; scattered rose jasper; trace pyrite; matrix supported in hydrophilic silt/ash; very slightly calcareous; no oil. Sandstone/Siltstone(5720-5800) = light gray to light brownish gray; very soft to soft; samples range from silty masses containing fine grained sands to loose sands of upper medium grained and coarse grained pebbles at the top of the interval and fining with depth; predominately translucent white to milky white quartz; trace to common greenish gray to pale blue mineral grains;scattered to trace pyrite as individual grains; 30% light brown to moderate brown lithics; very slightly calcareous; no oil indicators. Sand/Sandstone(5800-5860)= light gray to medium light gray to light olive gray overall; upper fine to lower medium grained; moderate well to well sorted; subrounded to sub angular; moderate to high sphericity; disaggregated; samples consist of loose sands; 50-60% colorless transparent quartz; 20%very fine to fine grained brownish black to black lithics; 10-20% pale green to grayish green lithics/minerals;trace fine grain calcite give reaction to HCI; no oil. Sandstone/Siltstone(5860-5930)=light to medium light gray to slight brownish hue;siltstones are very soft to soft silty masses; sandstones are easily friable to moderately firm; loose sands are upper fine to upper medium to few scattered coarse pebbles;sub angular to subrounded;select pebbles are rounded in part;silt matrix is cause for the softer sandstones at bottom of interval; moderately calcareous; scattered dull fluorescence looks like addition of mud products to mud. Sand/Sandstone(5930-6020)=light gray to medium light gray to medium gray throughout sample interval; very fine to lower fine to lower medium grained;well to moderate well sorted; subrounded to sub angular to rounded in part; moderate to high sphericity; disaggregated, samples consist of loose sands and scattered pieces of firm sandstones; 50-60% colorless transparent quartz, translucent white to gray smokey quartz; scattered to trace reddish brown to brownish black fine grained lithics; slightly to moderately calcareous; scattered minerals have dull yellow fluorescence. Sandstone/Siltstone(6020-6100)= light gray to medium light gray overall; silt matrix is light brownish gray and forms very soft to soft silty masses; siltstone is seen as yellowish brown soft to easily friable wedge like cuttings; loose sands are upper fine to upper medium throughout sample interval, occasional lower coarse grain; low to moderate sorting;sub angular to subrounded;moderate sphericity;disaggregated,friable to firm in part; translucent white to colorless to light gray quartz predominates; trace to common brownish black, 18 C:ANRIG fitik eni Eni Petroleum OP05-06, PB1 and PB2 brown,greenish gray very fine to fine lithics;slightly calcareous;5%scattered dull yellow fluorescence may be dead oil or mud additive. Sand/Siltstone(6100-6160)= light gray to medium light gray to secondary brownish hue;very little sample visible in tray, consists mainly of calcite sweep pumped by rig crew; silt forms silty masses containing loose sands; even dull fluorescence may be dead oil or due to addition of mud products. Carbonaceous Shale(6160-6220)=reddish brown to brownish black throughout sample interval;moderately firm to firm to locally hard; brittle;splintery to slightly blocky fracture;wedge like almost bladed cuttings habit; earthy resinous luster; mottled texture;thin micro laminae present in larger pieces;strong reaction to HCI still in part due to mud additive; 5-10%dull yellow fluorescence may be due to mud additive or dead oil. LOWER UGNU 6170.0 MD/-3143.2 TVDSS Drill Rate(ft/hr) Total Gas(units • _ Maximum Minimum Average Maximum Minimum Average 459.7 1.6 128.8 415 0 38.1 PEAKS Depth TG C1 C2 C3 C4I C4N C5I C5N 6238 415.7 93558.3 7048 124.9 24387.2 123.3 72.6 67.9 51.8 15.8 Sand/Sandstone (6239-6400) = medium light gray with a slight brownish secondary hue; soft to disaggregated; moderately well to well sorted;friable in part;fine lower to medium lower and fine upper grain; sub-rounded to sub-angular and slightly rounded; samples collected as loose sand slurry; appears to be primarily matrix supported; some locally grain supported in part; 50% to 60% translucent white to clear colorless quartz;common slightly smoky quartz;common medium and dark gray lithics;trace black lithic/mafic mineral grains and moderately rounded coal fines;trace hard,fine grain pyritic ironstone trace orange,yellow and rose jasper; samples covered 60 to 100%with matted translucent brown to dark muddy brown dead oil stain; becomes gray-brown as it dries;general medium yellow sample fluorescence with patches of dull gold; slow streaming cut to milky yellow white; medium brown residual stain fluoresces medium yellow and cuts Sand/Sandstone (6400-6540) = medium light gray with a slight brownish secondary hue; disaggregated; friable; moderately well to well sorted; sub-angular to angular and sub spheroidal; trace slightly rounded; moderately thickly bedded; fine upper to medium lower and fine lower at upper contacts becoming medium lower to fine upper and trace medium upper at the base;56 to 60%translucent white to clear quartz;trace to common slightly smokey quartz;common to abundant medium to light gray lithics;common dark gray to black mafic ironstone;trace pyrite and slightly rounded coal fines; 10 to 30%of sample is stained brown with sticky opaque brown dead oil stain; becomes gray-brown as it dries; general medium yellow sample fluorescence with patches of dull gold; slow streaming cut to milky yellow white; medium brown residual stain fluoresces medium yellow and cuts slowly to medium yellow white; no oil odor; slightly calcareous. Sand/Sandstone(6540-6640)=medium gray to medium light gray;soft to disaggregated;moderately well to well sorted;vertically sorted in moderately thick beds;sub angular to angular and sub-spheroidal;trace slightly rounded; primarily translucent white to clear colorless quartz; common medium to light and dark gray lithics; trace dark gray to black mafic mineral/lithics; trace pyritic ironstone fragments and moderately rounded coal fines; trace rose, yellow and orange jasper; 10 % of sample light brown oil staining; light to medium yellow sample fluorescence with patchy dull gold; slow streaming cut to milky yellow white; medium brown residual stain fluoresces light yellow; no oil odor; very slightly calcareous. Sand/Sandstone(6640-6730)=light gray to medium light gray throughout sample interval; upper fine to lower medium grained predominates, trace lower fine and lower coarse, vertically graded; well to moderate well 19 CANRIG ,eni Eel Petroleum OP05-06, PB1 and PB2 sorted; sub-angular to angular with moderate to high sphericity; soft to disaggregated; translucent white to clear colorless quartz predominates; common light gray to medium light gray lithics; trace fine grained dark gray to black lithics;trace pyritic ironstone fragments;5%light brown oil staining; no oil odor;5-10%patchy to even faint yellow sample fluorescence;very slow faint yellow white cut fluorescence; no visible cut or residue; slightly calcareous. Sand/Sandstone(6730-6820)=medium light to light gray with secondary light olive green hue;lower medium to upper medium to scattered lower coarse grained;moderately to well sorted;sub-angular to angular to trace rounded;moderate to sub-spheroidal;soft to disaggregated;predominately translucent white to very light gray quartz;common medium gray to light olive gray lithics;trace coal fines;trace orange and pale green lithics;no oil odor; 5-10%patchy yellow sample fluorescence;very slow transparent yellow cut fluorescence; no visible cut/visible residue; very faint yellow residual fluorescence; slightly calcareous. Sand/Sandstone(6820-6940)=medium gray to medium light gray to light gray; upper fine to upper medium to trace lower fine with depth of interval;well to moderate well sorted;sub-angular to angular;moderate to high sphericity; soft to disaggregated; trace pale green to pale greenish blue fine grained glauconite; translucent white to clear colorless quartz predominates;common grayish black to black mafics/lithics;trace orange and yellow minerals/lithics; slightly calcareous; 5% visible oil staining; 5-10% patchy dull yellow sample fluorescence; no visible cut;very slow faint yellow cut fluorescence; no visible residue;very faint light yellow residual fluorescence. Sand/Sandstone(6940-7030)=light to medium light gray to slight secondary olive green hue; upper medium to upper fine grained to locally lower coarse; moderate well to well sorted; sub-angular to sub-rounded to angular; moderate to high sphericity; translucent white to colorless transparent to light gray smokey quartz predominates;common dark gray to black mafics/lithics;trace orange lithics;trace pale green to greenish blue fine grained rounded glauconite; 10%oil stain in samples; 10-15% patchy dull yellow sample fluorescence; slow streaming transparent yellowish white cut fluorescence;slow streaming light brown visible cut; medium light amber residue with a dull yellow residual fluorescence. FAULT 1 6998.0 MD/-3412.7 TVDSS The Schrader Bluff formation is the zone of interest in this well. At this location, it consists of two main sands, the"N"Sand and the"O"Sand. The Schrader Bluff is an Upper Cretaceous turbidite deposit formed as shelfal lobes. In general, the"OA" Sands contain viscous crude with an API gravity between 16° and 19°. N SEQUENCE TOP 7035.0/-3422.9 TVDSS The"N" Sand was encountered after crossing a fault at 6988'. The"N"Sands continue until 7245' at which point another fault is crossed and the"N"Sand sequence repeats itself until it's base at 7928'. The"N"Sand consists of fine to medium grained sand which is well rounded. It's oil properties are a medium yellow sample fluorescence with a fast streaming milky white cut and fair brown residual stain with free oil on the shakers just below the fault at 7245'. Oil indicators increased as the interval increased. Drill Rate(ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 802.9 27.4 119.4 485 0 90.8 PEAKS Depth TG C1 C2 C3 C41 C4N C51 C5N 7427 368.7 70632.7 731.6 259.0 217.9 162.4 176.2 39.1 7532 303.8 60201.7 546.2 178.6 169.0 117.0 110.2 40.1 7906 782.1 145834.4 1840.0 1018.3 763.5 905.0 586.4 329.7 8072 606.0 113837.9 1325.4 827.6 568.8 716.7 494.8 301.4 8277 181.3 32574.0 329.7 158.6 184.4 254.9 289.4 206.3 20 CANRIG fat ,en'Eni Petroleum OP05-06, PB1 and PB2 8470 1059.2 164949.4 2191.4 520.6 396.0 362.3 233.7 107.8 8527 758.4 141373.8 1867.2 400.3 339.3 322.4 249.4 113.0 8571 1368.9 176694.9 3622.4 821.0 706.0 669.8 475.6 193.2 8672 825.4 154827.1 2133.1 543.4 546.7 539.9 411.9 163.4 Sand/Sandstone (7030-7150) = light to medium light gray; soft to disaggregated; moderately well sorted; vertically sorted, fining upward; moderately thickly bedded; angular to sub-angular and occasionally slightly rounded;translucent white to clear colorless quartz predominates;trace slightly smokey translucent quartz;30 to 40% medium to light and dark gray lithics;trace black mafic mineral/lithics;trace dark gray to black pyritic ironstone;trace pyrite as small micro-crystalline masses;trace clastic coal fines;trace splintery fresh coal may be from up section; trace brown and yellow grains; trace to scattered brown oil stain at 7030' gradually increasing 80% at 7150'; 10 to 80% medium yellow sample fluorescence; patchy dull gold fluorescence; medium streaming cut to yellow white; slight to good brown residue with dull yellow fluorescence cuts to medium yellow; slight oil odor; moderately calcareous. N SAND TOP 7198.0'MD/-3466.4'TVDSS Sand/Sandstone (7150-7270) = light to medium light gray; pronounced brownish secondary hue; disaggregated; friable; moderately well to well sorted; material at 7210' appears to be the base of the described above as sand continues to coarsen to that point;medium lower to medium upper and coarse lower above 7110' becomes medium lower and fine upper at 7260'; predominantly translucent white to clear colorless quartz;30 to 40%lithics/mineral grains as previously described; 100%to 30%brown oil stain;slight oil odor;free oil noted at the shakers; 100 to 40%medium yellow sample fluorescence;fast streaming cut to milky yellow white; fair brown residue stain cuts to yellow white slightly to moderately calcareous. Sand/Sandstone(7270-7350)= light gray to medium light gray; upper fine to upper medium grained; trace lower coarse grained; moderate well to well sorted; sub-rounded to sub-angular to scattered angular; moderate to high sphericity; disaggregated, friable to slightly firm; predominately translucent white to clear colorless quartz;medium gray to dark gray lithics are common;trace pyrite;trace orange lithics;scattered pale green to bluish green fine grained glauconite;5-10%brown oil staining;oil odor has decreased to no odor; 10- 15%patchy dull yellow sample fluorescence;streaming cut milky yellow fluorescence;very light brown residue fluoresces faint yellow. Sand/Sandstone(7350-7450)=medium gray to medium light gray with prominent secondary brownish hue; lower fine to lower medium to upper medium grained; well to moderate well sorted; sub-rounded to sub- angular; moderate to high sphericity; disaggregated; friable; translucent white to clear colorless quartz predominates; 15-20% dark gray to black lithics; 70-80% oil staining; free standing oil on shakers; slight oil odor; 90%even medium yellow sample fluorescence;fast streaming milky yellowish white cut fluorescence; fast streaming brown visible cut; fair brown oil residue; medium yellow residual fluorescence; slightly to moderately calcareous. Sand/Sandstone (7450-7560) = medium light to light gray with slight brownish hue; lower fine to lower medium to slight upper medium grained;well to moderate well sorted;sub-angular to sub-rounded to angular in part;moderate to sub-spheroidal;disaggregated;friable; predominately translucent white to clear colorless quartz;common light gray to somewhat smokey quartz;trace to common dark gray to black lithics;40-80%oil staining across sample interval, highest percent in the 7480' sample; 40-80% medium yellow sample fluorescence;fast streaming brown cut with fast streaming milky white fluorescence;moderate brown residue fluoresces bright yellowish white; slightly to moderately calcareous. Sand/Sandstone (7560-7620) = light to medium light gray to light olive gray; upper medium to upper fine grained; moderate to well sorted; sub-angular to sub-rounded; moderate to sub-spheroidal; disaggregated; translucent white predominates;slightly calcareous;no oil odor;5%oil staining in sample trays;5-10%patchy dull yellow sample fluorescence;slow streaming light amber visible cut fluoresces transparent milky yellowish white; light brown residue fluoresces dull yellow. 21 BRIG - Eni Petroleum OP05-06, PB1 and PB2 Sand/Sandstone (7620-7720) = medium to light medium gray; upper fine to lower medium to trace upper medium;moderate to well sorted;sub-angular to angular to sub-rounded;moderate sphericity;disaggregated; soft; silt matrix found in sample interval to form small silty masses containing sand grains; trace pyrite as micro-crystalline masses; slightly calcareous; no oil odor; <5%visible oil staining; 5-10% patchy dull yellow fluorescence;slow streaming transparent milky white cut fluorescence with light amber slow streaming visible cut; faint light brown residue fluoresces to a dull yellow. N SAND SUB-LOBE 2 7765.0'MD/-3607.6'TVDSS Sand/Conglomeratic Sand (7720-7810) = medium to light medium gray to slight olive gray; material in sample interval appears to be the base of previously described sample as sand continues to coarsen to this point; lower medium to upper medium to locally lower coarse to pebbles as large as 5mm; moderate to well sorted; sub-angular to angular; soft; disaggregated; silty matrix forms small silty masses; no oil odor; 5%oil staining; streaming milky yellowish white cut fluorescence; light brown visible cut; faint light brown residue fluoresces dull yellow; slightly to moderately calcareous. N SAND SUB-LOBE 3 7850.0'MD/-3625.2'TVDSS Sand/Conglomeratic Sand (7810-7960) = medium light gray with a slight brownish secondary hue; disaggregated;friable; medium upper to medium lower grain with common angular flaky coarse size pebble fragments to 7840' then becoming fine upper to medium lower with scattered medium upper in the 7870' sample;from 7870 material becomes well sorted in the fine upper to fine lower and medium upper range;sub- angular to angular in the finer grain; coarser material is uniformly angular; translucent white to clear quartz predominates;common to abundant medium to dark gray lithics;trace to common tan shell fragments;trace to common light gray and black lithics; common coal fines; appears matrix supported in clayey siltstone; interbedded with sandy siltstone; locally grain supported; porosity cannot be determined from samples; scattered brown oil stain becomes trace below 7900 very slight oil odor; 20 to 70% dull yellow to dull gold sample fluorescence; fast streaming cut to yellow white; faint brownish residue ring cuts readily to yellow white; slightly to moderately calcareous. N SAND BASE 7928.0'MD/-3642.1'TVDSS LOWER N MARKER 8021.0'MD/-3663.3'TVDSS Sand/Conglomeratic Sand (7960-8030) = medium light gray; soft silty to disaggregated; friable in part; moderately sorted; medium upper to medium lower and fine upper; common coarse lower; trace 3 to 5mm pebble3 fragments;angular to sub-angular;about evenly divided between translucent white to clear quartz and gray lithics; trace coal fines, pyrite and multicolored jasper; common to very abundant tan shell fragments; interbedded with sandy siltstone; matrix supported in light brownish grey silt; general dull yellow-gold fluorescence;fast streaming cut to yellow-white;faint brownish residue ring fluoresces dull yellow;yellow white residue cut; scattered to common brown oil stain; no odor; slightly to moderately calcareous. Sand/Conglomeratic Sand(8030-8200)=medium to medium light gray with a distinct brownish secondary hue; disaggregated sand collected in masses of re-worked silt/clay matrix; moderately to poorly sorted;fine upper to medium lower, medium lower and scattered coarse lower becoming increasingly coarse as depth increases;scattered to common 3 to 10mm pebbles and pebble fragments;angular to sub-angular in the sand range pebbles are moderately to slightly rounded; sand is predominately translucent white to clear colorless and slightly smoky translucent quartz; abundant medium to light and dark gray lithics; trace orange jasper; very abundant to 20% shell fragments; pebbles are predominantly chert and translucent quartz; trace to common brown oil stain;20-40%dull yellow-gold sample fluorescence;fast streaming cut to yellow-white;very slight residual ring with dull yellow fluorescence; no oil odor; moderately to very calcareous. 22 CANRIG fa ,eni Eni Petroleum OP05-06, PB1 and PB2 N SEQUENCE BASE 8140.0'MD/-3691.1'TVDSS The"OA"sand appears at 8423'. The"OA"sand is consists of three sub lobes of turbidite sand separated by silty sandstone and sandy siltstone. The"OA" Sand is the sand of interest and the production zone for the OP05-06 well. The well bore follows the sand as it undulates and at times,will move between the three sub- lobes at the direction of the geologists and engineers. The sand is a upper fine to lower fine quartz sand which is sub-rounded and moderate sphericity. Oil indicators are a dull yellow to alight green sample fluorescence with a milky white streaming cut, white residual fluorescence; light to dark amber cut and dark straw residual cut. Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 714.1 9.2 175.4 1582 2 541.5 PEAKS Depth TG C1 C2 C3 C4I C4N C51 C5N 8277 181.3 32574.0 329.7 158.6 184.4 254.9 289.4 206.3 8470 1059.2 164949.4 2191.4 520.6 396.0 362.3 233.7 107.8 8527 758.4 141373.8 1867.2 400.3 339.3 322.4 249.4 113.0 8571 1368.9 176694.9 3622.4 821.0 706.0 669.8 475.6 193.2 8672 825.4 154827.1 2133.1 543.4 546.7 539.9 411.9 163.4 9113 857.6 149369.3 814.8 100.5 84.6 57.6 42.8 41.2 9349 643.0 88793.0 606.7 69.8 54.1 51.4 25.5 21.6 9428 644.5 95473.1 88.3 64.7 55.5 36.5 5.3 7.9 9707 822.2 109734.2 673.2 91.3 73.5 55.7 57.0 24.4 9944 847.1 98190.0 517.6 80.0 82.1 78.5 70.4 17.7 10104 1292.2 149421.1 837.3 309.7 140.8 162.1 141.2 106.7 10325 758.6 103160.3 540.6 86.3 67.7 71.9 56.6 41.7 10663 1145.2 121272.7 519.0 70.4 68.3 66.8 64.3 59.0 11252 1077.0 106706.6 508.9 54.5 69.1 79.8 78.4 67.0 11396 1176.9 119550.7 573.3 60.0 63.0 64.9 68.9 63.6 11578 1079.4 119170.3 556.8 62.8 64.0 71.9 59.7 48.2 11911 1069.6 138227.4 582.1 60.1 67.2 57.0 85.5 69.5 12215 1398.2 150393.8 915.0 89.1 70.6 78.0 46.5 55.3 12576 1106.2 132767.6 714.9 71.1 65.1 70.2 57.9 44.7 12719 1223.4 146946.0 723.9 60.1 81.1 89.9 67.8 36.8 12860 1340.7 205762.6 1227.5 88.3 82.8 86.9 110.0 51.6 12968 1401.7 174078.2 935.4 85.5 76.6 98.3 87.8 71.3 13178 1582.4 142771.4 822.0 70.1 72.1 84.9 55.3 58.7 13560 1323.6 157962.9 647.7 83.6 86.0 89.8 67.1 46.3 13868 1274.7 142559.8 726.4 73.4 62.7 83.8 59.3 34.6 14138 882.3 98421.1 535.9 46.5 46.8 61.0 66.7 62.9 14358 1243.5 191200.3 814.8 110.1 208.4 210.1 238.8 178.6 15092 965.1 133175.5 711.9 61.4 63.6 63.6 64.5 28.7 15280 1069.0 128983.7 701.0 51.4 56.6 59.6 34.4 17.6 15550 1030.7 129589.8 665.0 43.6 47.9 42.7 40.8 31.1 16227 816.9 142115.1 625.0 47.3 92.0 76.9 60.9 30.1 16816 579.1 86710.7 524.2 42.2 56.4 67.6 58.1 41.8 Sand/Conglomeratic Sand (8200-8290)= light to medium light gray with pronounced secondary brownish hue; upper fine to lower medium to trace upper medium; poorly to moderately sorted;angular to sub-angular; moderate to low sphericity; disaggregated; soft;silty/clayey matrix forms small masses of reworked sands in silty matrix; pre-dominantly translucent white to clear colorless quartz;trace to abundant light gray to smokey 23 CANRIG ,eni Eel Petroleum OP05-06, PB1 and PB2 quartz; 70-80% oil staining in samples; 80% even dull yellow sample fluorescence; fast streaming cut fluoresces milky yellowish white;fair brown residue fluoresces dull yellow;slight oil odor; moderately to very calcareous. Sand/Conglomeratic Sand(8290-8380)=light to medium light gray to medium gray; upper medium to lower medium to common upper fine grained; poorly to moderately sorted; annular to sub-angular; moderate sphericity; soft to friable in part; disaggregated; very soft silty masses more abundant within sample interval decreasing in the 8380'sample; predominately translucent white to clear colorless quartz;moderately to very calcareous;trace to abundant shell fragments;slight oil odor; 80-90%even dull yellow sample fluorescence; fast streaming light brown cut fluoresces milky yellowish white; light brown residue fluoresces dull yellow. Sand/Conglomeratic Sand(8380-8450)=medium to light medium gray with secondary brownish hue;lower medium to upper medium grained;trace upper fine and trace lower coarse; poor to moderate sorting;angular to sub-angular; moderate sphericity;very calcareous;dull patchy yellow sample fluorescence;cut fluoresces transparent yellowish white; light brown residue fluoresces dull yellow. OA SAND SUB-LOBE 1 8423.3'MD/-3751.1'TVDSS Sand/Sandstone (8450-8530)=light to light medium gray with pronounced secondary brownish hue; lower fine to upper fine; few upper very fine; well to moderate well sorted; sub-rounded to sub-angular with high sphericity;disaggregated;predominately clear color-less to translucent white quartz;trace orange lithics;trace micro-crystalline pyrite; strong oil odor; 80-90% brown oil staining; 80-90% bright even yellow sample fluorescence;fast streaming brown cut fluoresces bright milky yellow;moderate brown residue fluoresces to a dull yellow. OA SAND SUB-LOBE 2 8497.0'MD/-3763.2'TVDSS OA SAND SUB-LOBE 3 8566.5'MD/-3772.0'TVDSS Sand/Sandstone (8530-8620)=medium to light medium gray with definite secondary brownish hue;friable; disaggregated; lower fine to upper fine grained; scattered medium lower grained well to moderately well sorted; sub-rounded to sub-angular; high to moderately high sphericity; 50 to 60%translucent white quartz; common to abundant clear colorless quartz and medium to light gray lithics; trace dark gray to black lithic/mafic mineral grains; trace medium to dark gray chert; trace to common glauconite and green stained quartz grains; trace pyrite and shell fragments; appears to be principally grain supported; no matrix material noted;abundant free oil in wash water and on shale shakers;good oil sheen on wash water;obvious oil odor at shakers; moderate oil odor on samples;90 to 100%medium brown oil stain on samples; 100%dull yellow- gold sample fluorescence; fast streaming cut to milky yellow white; pronounced brownish residue ring cuts readily to yellow white; moderately calcareous. Sand/Sandstone (8620-8840)= light gray to medium dark gray to translucent; upper very fine to lower fine; very well sorted throughout sample interval; predominantly sub-rounded with high sphericity; approximately 5%moderate green to brilliant green to light bluish green glauconite grains,very fine to fine,sub-rounded with moderate to high sphericity; approximately 10% black mafic grains throughout sample interval, very fine grained; scattered moderate orange pink to moderate reddish orange shell fragments throughout sample interval; slight oil odor; approx 20% brown oil staining on sandstone cuttings; 10-30% patchy dull yellow sample fluorescence;very slow blooming dull white cut fluorescence;pale straw to straw visible cut;pale straw to clear visible residual ring; faint to dull yellow residual fluorescence. Siltstone/Shale(8840-8960)=brownish black to brownish gray to olive gray to medium gray;easily friable to moderately hard to friable; tough and dense to crumbly brittle tenacity; massive tabular wedge ike cuttings habit; dull waxy to vitreous luster;generally a smooth clayey to slightly gritty occasional texture;frequent thin black to occasional reddish brown laminations throughout sample interval; shale abundance increases with depth within this sample interval; slight to fragrant oil odor; no visible oil stain; 30-60% patchy dull to bright orange to yellow sample fluorescence; streaming dull to moderately bright white cut fluorescence; amber to dark brown visible cut; heavy dark straw to amber visible residual ring; moderately bright yellow to orange to 24 CANI IG Eni Petroleum OP05-06, PB1 and PB2 brown residual fluorescence. FAULT 3 8948.0 MD/-3778.2TVDSS Sandstone/Sand (8960-9050) = medium gray to light gray to dusky brownish gray sandstone cuttings; translucent free quartz grains also abundant; upper very fine to lower fine; well to very well sorted; sub- rounded to round angularity with high sphericity; sandstone cuttings vary from easily friable to moderately hard; tough dense to crumbly tenacity; irregular fracture; greasy resinous luster; gritty texture; no visible structures; faint oil odor; most sandstone cuttings have light to dark brown oil staining within the cutting; 30- 90%patchy dull to moderately bright yellow to orange sample fluorescence, increasing with depth;streaming moderately bright white cut fluorescence noted; straw visible cut; light brown visible residue; bright white residual fluorescence. Siltstone(9050-9140)=medium dark gray to olive gray to dark gray throughout sample interval; moderately hard to firm to friable; tough dense to slightly brittle tenacity in part; tabular to somewhat butter curl cuttings habit; waxy dull luster; silty to somewhat gritty texture; dark brown to reddish brown micro laminae present throughout sample interval; moderate oil odor noticeable; no oil staining in siltstone; 50-60% patchy dull to slightly bright yellow to patchy golden sample fluorescence; streaming dull white cut fluorescence; steaming moderate brown visible cut; heavy dark brown residue fluoresce bright yellowish white. OA SAND SUB-LOBE 2 9100.0 MD/-3785.5 TVDSS Sand/Sandstone (9140-9230)=medium light to medium gray to pronounced brownish secondary hue;very fine to fine grained; well sorted; sub-rounded to rounded with moderate to high sphericity; firm to friable; apparently looks to be grain supported;5-10%shell fragments;moderate oil odor present;20-30%dark brown oil staining visible;50-60%patchy to slightly even dull yellow sample fluorescence;fast streaming bright milky white cut fluorescence; fast streaming dark brown visible cut; moderate to heavy dark brown residue; bright white to faint golden yellow residual fluorescence;slightly calcareous/very calcareous in the 9170'sample with shell fragments. Siltstone(9230-9320)=medium dark gray to olive gray to brownish gray overall;tenacity is dense crumbly to slightly brittle;tabular to platy cuttings habit;waxy dull to slightly greasy luster; silty to gritty texture;thin dark brown micro laminae; very slightly to non-calcareous; fair to moderate oil odor; no oil staining visible in siltstone; 40-50% patchy golden yellow to yellow sample fluorescence; slow streaming dull white cut fluorescence;very slow streaming light straw to straw visible cut;very light straw visible residue;faint yellow to orangish yellow residual fluorescence. OA SAND SUB-LOBE 3 9335.0 MD/-3795.1 TVDSS Sand/Sandstone (9320-9410)=medium gray to olive gray to pronounced brownish secondary hue;very fine to fine grained sands;well to moderate well sorted;sub-rounded to rounded with moderate sphericity;firm to friable; apparently looks grain supported; abundant to common pale blue green to grayish blue green glauconite; fair to moderate oil odor;40-50%dark brown oil staining present in sandstones; 40-50% patchy dull yellow sample fluorescence across interval; fast streaming bright milky white cut fluorescence; fast streaming dark brown visible cut;moderate dark brown residue;dull orange yellow residual fluorescence;very slightly calcareous. Sand/Sandstone (9410-9560) = medium light gray to medium dark gray to olive gray throughout sample interval;predominately lower fine to upper fine to locally lower medium grained;well to moderately well sorted; sub-rounded to sub-angular to few rounded; moderate to sub-spheroidal; disaggregated to friable to firm; becomes harder with depth comparing with drill rate; trace to abundant pale green to grayish blue green glauconite;abundant to common shell fragments;>5%shell fragments in the 9500'sample;moderately to very calcareous; fair to moderate oil odor; stain is difficult to identify; may be masked by oil based mud; 50-60% even dull yellow sample fluorescence; fast steaming bright yellowish white cut fluorescence;fast streaming brown visible cut; light to moderate brown residue; dull yellowish white residual fluorescence. 25 CANRIG eni Eni Petroleum OP05-06, PB1 and PB2 Sand/Sandstone (9560-9650)=medium light gray to medium gray to olive gray with pronounced greenish secondary hue throughout sample interval; upper very fine to upper fine grained;well to very well sorted;sub- rounded to sub-angular; moderately high to high sphericity; hard to very firm; disaggregated; abundant to common grayish green to dusky green gives the secondary greenish hue;trace shell fragments;moderate to very calcareous; no visible oil staining; no distinct oil odor; may be masked by oil based mud; 50-60%even dull yellow sample fluorescence; fast streaming dull yellowish white to slightly bluish cut fluorescence; fast streaming slightly amber to dark brown visible cut; faint straw visible residue ring; dull yellow residual fluorescence. Sand/Sandstone (9650-9770) = medium gray to medium dark gray to olive gray; pronounced greenish secondary hue; upper very fine to lower fine to upper fine in parts; very well to well sorted; sub-rounded to rounded to sub-angular; high to moderate high sphericity; disaggregated; firm to moderately hard in part; predominately translucent light gray quartz to grayish green glauconite;secondary greenish hue comes from abundant to common grayish blue green to moderate blue green to dusky green glauconite;very calcareous with violent reaction to HCI;trace to scattered shell fragments; no oil stain visible;faint oil odor;20-30%patchy dull yellow sample fluorescence; slow streaming dull yellowish white cut fluorescence; slow streaming light straw visible cut; faint light straw visible residue; dull yellow residual fluorescence. Sand/Sandstone (9770-9890)=medium gray to olive gray to medium dark gray throughout sample interval; pronounced greenish secondary hue; upper very fine to lower fine grained to upper fine in part;well to very well sorted;sub-rounded to rounded to sub-angular in part;moderately high to high sphericity;disaggregated; friable to firm to slight moderately hard in part; predominately translucent light gray quartz to greenish gray quartz; abundant to common grayish green to grayish blue green to dusky green glauconite; trace very fine grained black lithics give slight salt and pepper appearance; no oil stain visible;faint oil odor above OBM;20- 40% patchy to 100% even dull yellow sample fluorescence; slow streaming dull yellowish white cut fluorescence; light straw to straw visible cut; light straw visible residue; dull yellow residual fluorescence. Sand/Sandstone (9890-10040)=medium gray to translucent to light gray individual sand grains;upper very fine to lower fine;well to very well sorted;predominantly sub-rounded to rounded grains with high to moderate high sphericity; sandstone cuttings are soft and easily friable to moderately hard; approximately 5% brilliant green to moderate green to light bluish green glauconite,fine to very fine,sub-rounded, moderate sphericity; approx 10% very fine grained black lithic grains; slight to fragrant oil odor; no visible oil stain on free sand grains;sandstone cuttings have dark to light brown oil stain when prodded open;sample fluorescence varies from 100% even dull yellow to 20-50% patchy dull to moderately bright yellow to yellowish orange; patchy samples consist of more sandstone cuttings while even samples consist mostly of free sands;slow dull milky white cut fluorescence; straw to pale straw visible cut; light pale straw visible residue; dull white residual fluorescence. Sand/Sandstone (10040-10160) = translucent to smokey gray to medium gray to light gray sand grains; upper very fine to lower fine throughout; very well sorting; sub-rounded with moderate to high sphericity; sandstone cuttings are typically firmly friable to moderately hard with occasional easily friable cuttings; approximately 5%moderate green to light bluish green glauconite,very fine to fine grained,sub-rounded with moderate sphericity; approx 10% black mafic grains throughout sample interval; slight to no oil odor above OBM; sandstone cuttings have light brown to dark brown oil staining within when prodded open; even dull yellowish white sample fluorescence with some depths exhibiting 20-30% patchy dull to moderately bright yellow to yellowish orange;slow streaming dull white cut fluorescence; light amber to amber visible cut;dark straw to light amber visible residue; dull yellowish white residual fluorescence. Sand/Sandstone (10160-10340)=medium gray to light gray to translucent;upper very fine to lower fine;very well sorted;predominantly sub-rounded to rounded;high to moderate sphericity;sandstone cuttings are friable to moderately hard to firmly friable; approx 5% brilliant green to moderate green to bluish green glauconite, very fine to fine, sub-rounded with moderate sphericity; 10-15% black lithics giving salt and pepper appearance with light colored free sand grains; moderate reddish orange to moderate orange pink to pale yellowish orange shell fragments throughout sample interval, peaking in abundance in the 10220-10250 26 CANRIG ,eni Eni Petroleum OP05-06, PB1 and PB2 sample interval and tapering off prior to and after that interval period; slight to no oil odor above OBM; light brown to dark brown oil staining within sandstone cuttings when prodded open; 10-20%very light brown oil staining on free sand grains; 100% even faint to dull yellow sample fluorescence, with occasional samples containing 20-30% patchy dull yellow to orangish yellow; fast blooming moderately bright white cut fluorescence; dark straw visible cut; straw to dark straw visible residue; dull yellowish white residual fluorescence. Sand/Sandstone (10340-10490)= light gray to translucent to medium gray sand grains; upper very fine to lower fine;very well sorted; sub-rounded to rounded to sub-angular; moderate to high sphericity; sandstone cuttings are friable to moderately hard; approx 5% moderate green to light bluish green to brilliant green glauconite,very fine to fine grained,sub-rounded to sub-angular, moderate sphericity; 10%very fine grained black lithics;moderate orange pink to pale yellowish orange shell fragments,<10%;some sandstone cuttings grading into silty sandstone with some sandy siltstone cuttings as well; slight to fragrant oil odor above OBM; light brown oil stain within prodded open sandstone cuttings; 100% even dull yellow sample fluorescence, 10430-10460 sample had approximately 20%dull dark yellow to orangish yellow cuttings;slow streaming faint to dull white cut fluorescence; no/clear visible residue; very faint white residual fluorescence. OA SAND SUB-LOBE 3 10406.0 MD/-3784.8 TVDSS Sand/Sandstone (10490-10640) = medium gray to translucent to very light gray quartz grains; upper very fine to lower fine; very well sorted; sub-rounded to sub-angular; moderate sphericity; sandstone cuttings are friable to moderately hard;sandstone cuttings grade into silty sandstone to sandy siltstone as depth increases throughout this interval;generally hardness increases with silt content; silty sandstone cuttings contain black and dark reddish brown very thin laminations on smooth sides of cuttings; <5% moderate green to brilliant green glauconite, very fine, sub-rounded, moderate sphericity; 10-15% very fine black mafic specks in samples,giving salt and pepper appearance;pale yellowish orange to moderate orange pink shell fragments; slight to slightly fragrant oil odor above OBM; light brown to dark brown oil stain within sandstone and silty sandstone cuttings when prodded open; background sample fluorescence of free sand grains is100%dull to faint yellow to yellowish white,sandstone and siltstone cuttings present patchy dull to moderately bright yellow to orangish yellow fluorescence;streaming bright to moderately bright white cut fluorescence; heavy amber to dark brown visible residual spot; moderately bright dark yellow to orangish yellow residual fluorescence. OA SAND SUB-LOBE 2 10591.0 MD/-3776.2 TVDSS Sand/Sandstone (10640-10790)=very light gray to translucent to light gray sand grains; upper very fine to lower fine throughout sample interval;very well sorted;sub-rounded to sub-angular with moderate sphericity; sandstone cuttings are friable to moderately hard; siltstone and silty sandstone cuttings grading back to sandstone as depth increases; shell fragments increase with depth; approx 5% moderate green to brilliant green glauconite,very fine to fine,sub-rounded,moderate sphericity; 10-15%black lithic grains giving salt and pepper appearance; shell fragments are moderate orange pink to pale yellowish orange in color; slight to fragrant oil odor;free sand grains have no visible oil stain; light brown to dark brown oil stain within sandstone cuttings when prodded open; immediate moderately bright milky white cut fluorescence; straw to dark straw visible cut; straw visible residue; dull to faint white residual fluorescence. Sand/Sandstone (10790-10910)= light gray to translucent to very light gray sand grains; upper very fine to lower fine; very well sorted; sub-angular to sub-rounded with moderate sphericity; intact sandstone cuttings decrease with depth;approximately 5%light bluish green to moderate green to brilliant green glauconite,very fine to fine, sub-angular to sub-rounded, moderate sphericity; 10-20% very fine black mafic grains; pale yellowish orange to moderate orange pink shell fragments throughout sample interval; slight to fragrant oil odor; no visible oil stain on free sand grains; light brown to dark brown oil stain within sandstone cuttings; 100%even dull yellow sample fluorescence;immediate dull to moderately bright milky white cut fluorescence; light amber to amber visible cut; straw to dark straw visible residue; dull white residual fluorescence. Sand(10910-11030)=translucent to light gray to medium gray; upper very fine to lower fine;sub-angular to sub-rounded throughout sample interval; moderate sphericity;approx 5%moderate green to brilliant green to 27 CANRIG ,eni Eni Petroleum OP05-06, PB1 and PB2 light bluish green glauconite,very fine to fine,sub-angular to sub-rounded, moderate sphericity; 10-20%fine grained black lithics giving a salt and pepper appearance;pale yellowish orange to moderate orange pink shell fragments throughout sample interval; slight oil odor; no visible oil staining on sand grains; 100%even dull yellow to yellowish white sample fluorescence; slow blooming dull white cut fluorescence; slow streaming amber visible cut; dark straw to light amber residue; dull white residual fluorescence. Sand (11030-11150)= light gray to medium light gray to slight olive gray throughout sample interval; upper very fine to lower fine to locally upper fine in parts; well to very well sorted; sub-rounded to sub-angular; moderate to high sphericity; disaggregated; pre-dominantly light gray to slightly smokey quartz;abundant to common light blue green to moderate blue green to brilliant green glauconite;trace to abundant pale yellowish orange to moderate orangish pink shell fragments; 10-20% very fine grained black lithics giving salt and pepper appearance; no oil staining visible on loose sand grains;slight oil odor; 100%even dull yellow sample fluorescence; slow streaming dull yellowish white cut fluorescence; slow streaming light amber to slightly amber visible cut; faint straw to light amber residual ring; dull white residual fluorescence; slightly to moderately calcareous. Sand (11150-11240) = translucent to light gray to medium light gray overall; upper very fine to lower fine grained; well to moderately well sorted; sub-rounded to sub-angular; high to moderate high sphericity; disaggregated; common blue green to brilliant green glauconite throughout; trace very fine grained black lithics;trace to abundant orangish pink shell fragments increasing with depth; no oil staining on sand grains; slight oil odor; 100% even dull yellow sample fluorescence; slow blooming dull yellowish white cut fluorescence; slow streaming dark straw to light amber visible cut; faint light straw to dark straw residue fluoresces dull white; moderately calcareous. Siltstone(11240-11360)=light gray to medium light gray to medium gray throughout sample interval; slight light brown secondary hue;tough dense to slightly brittle tenacity;tabular to slightly wedge like to butter curl cuttings habit; dull waxy to slightly greasy luster; silty to slightly clayey texture to locally gritty in cuttings that are grading toward sandy silt; very thin dark brown micro-laminae visible in some siltstone cuttings; 5-10% yellowish orange to moderate orangish pink shell fragments; very slightly calcareous; slight oil odor; no oil staining in siltstone cuttings;70-80%patchy dull yellow sample fluorescence;very slow streaming faint white cut fluorescence; very slow light pale straw visible cut; light pale straw residue; faint dull yellow residual fluorescence. Sand/Sandstone (11360-11480)=light gray to translucent to medium gray throughout sample interval;upper very fine to lower fine to occasional upper fine grained;well to very well sorted; sub-angular to sub-rounded; high to moderately high sphericity;disaggregated; loose sands;predominately translucent to slightly smokey quartz;trace yellowish orange to moderate orangish pink shell fragments decreasing with depth; 10-20%very fine grained black lithics/mafics; abundant to common pale blue green to moderate blue green glauconite; slight oil odor;trace dark brown oil staining in sandstone cuttings; 100%even dull yellow sample fluorescence; slow blooming dull white cut fluorescence; streaming dark straw to light amber visible cut; light to moderate straw to dark straw residual ring; faint to dull white residual fluorescence; moderate to very calcareous. Sand/Sandstone (11480-11600) = light gray to medium gray to medium dark gray overall; slight greenish secondary hue; upper very fine to lower fine to upper fine in part;very well to well sorted;sub-angular to sub- rounded; moderate sphericity to sub-spheroidal; disaggregated loose sand to soft in the trace sandstone cuttings;translucent to light gray to slightly smokey quartz predominates;trace yellowish orange to moderate orangish pink shell fragments decreasing with depth;trace to abundant very fine grained black lithics/mafics; trace to abundant pale blue green to dusky blue green glauconite;slight to moderate oil odor;no oil staining on sand grains; trace dark brown oil staining in trace sandstone cuttings; 100% even dull yellow sample fluorescence; moderate blooming dull milky white cut fluorescence;moderate blooming amber to light brown visible cut; light to moderate dark straw to light amber residue; dull yellowish white residual fluorescence; slightly to moderately calcareous. OA SAND SUB-LOBE 2 11649.0'MD/-3785.6'TVDSS 28 CANRIG Eni Petroleum ieni OP05-06, PB1 and PB2 Sand/Sandstone (11600-11780) = light gray to medium light gray to light olive gray throughout interval; disaggregated loose sand; upper very fine to lower fine to trace upper fine; well to very well sorted; sub- angular to sub-rounded; moderately to sub-spheroidal; trace to occasional sandstone cuttings; sandstone cuttings very soft to soft; trace pale yellowish orange to moderate orangish pink shell fragments (<5% in samples); predominately translucent light gray to slightly smokey quartz; 10-20% very fine grained black lithics/mafics;gives slight salt and pepper appearance; sub-angular to angular; moderate sphericity;trace to abundant moderate green to moderate blue green glauconite; sub-rounded to rounded to sub-angular; slight oil odor;slight light brown oil stain in sand grains to trace dark brown oil stain in the trace sandstone cuttings; 100%even dull yellow with 30%patchy bright yellow sample fluorescence;slow blooming dull to slightly bright white cut fluorescence;streaming dark straw to light amber visible cut;moderate to heavy dark brown residual ring; dull to slightly bright yellow residual fluorescence. Siltstone(11780-11900)=medium dark gray to brownish gray to slight olive gray throughout sample interval; firm to moderately hard to friable;dense tough to slightly crumbly tenacity;tabular to wedge like cuttings habit; slight butter curling;dull waxy slightly vitreous luster;clayey silty texture;gritty in parts when graded in and out of sand lobes;trace thin micro-laminae noticeable on smooth sides of cuttings; non-calcareous;trace calcite crystals and sandstone cuttings are very slightly to slightly calcareous; slight to fair oil odor within siltstone cuttings; trace oil staining visible; 60-70% patchy dull orangish to golden yellow sample fluorescence; slow streaming dull white cut fluorescence;slow streaming dark amber to light brown visible cut;faint straw to dark straw residue; dull to bright white residual fluorescence. OA SAND SUB-LOBE 3 11876.0'MD/-3799.4'TVDSS Sand/Sandstone (11900-11990)=light gray to medium light gray to medium gray throughout sample interval; upper very fine to lower fine to locally upper fine grained;well to very well sorted;sub-angular to sub-rounded; moderate to high sphericity;disaggregated loose sands with trace to abundant sandstone cuttings;abundant to common black lithics/mafics throughout sample interval; moderate oil odor; no visible oil staining in sand grains; 100% even dull yellow to 50% patchy bright yellow sample fluorescence; streaming dull white cut fluorescence; streaming light amber visible cut; pale straw visible residue; faint yellowish white residual fluorescence. Sand/Sandstone (11990-12170)=medium light gray to translucent to light gray to occasional medium gray sand grains; upper very fine to lower fine; sub-angular to sub-rounded with moderate sphericity; sandstone cuttings decrease in abundance as depth increases;sandstone cuttings are firmly friable to easily friable;<3% glauconite throughout sample interval, translucent brilliant green to moderate green, very fine to fine, sub- angular to angular, moderate to low sphericity; 10-20% black mafic grains, very fine to fine; shell fragments decrease in abundance as depth increases; sizes of fragments vary from fine to medium up to pebble sized; shell fragments vary from moderate orange pink to pale yellowish orange and some larger fragments exhibit milky white opaque layers; slight to no oil odor above OBM; no visible oil staining; 50% even dull and 50% even faint yellow sample fluorescence,with earlier sample intervals containing approximately 20%patchy dull yellow grains; immediate faint to dull white cut fluorescence; dark straw visible cut; medium straw visible residue; faint to dull yellow residual fluorescence. Sand(12170-12290)=medium light gray to light gray to translucent to medium gray; upper very fine to lower fine throughout sample interval; sub-angular to sub-rounded with moderate sphericity; <3%brilliant green to moderate green to translucent light bluish green glauconite, very fine to fine grained, sub-angular to sub- rounded with moderate sphericity; 15-20%black lithics,very fine grained,throughout sample interval giving a salt and pepper appearance; shell fragments appear occasionally at beginning of sample interval and rarely are seen near end of interval;slight oil odor observed above OBM; no visible oil staining present; 100%even dull to faint yellow sample fluorescence; slow streaming dull to faint white cut fluorescence; medium straw visible residue; dull to moderately bright white residual fluorescence. Sand (12290-12380) = medium light gray to translucent to medium gray; upper very fine to lower fine; sub- angular to sub-rounded with moderate sphericity; approximately 5% brilliant green to moderate green to translucent bluish green glauconite,fine to very fine,sub-angular to sub-rounded,moderate sphericity; 10-15% 29 CANRIG lk 1eni Eni Petroleum OP05-06, PB1 and PB2 very fine grained black mafic grains throughout sample interval giving salt and pepper appearance; rare shell fragments observed, <2%; fragrant to slight oil odor; no visible oil staining; 100%even moderately bright to dull yellow sample fluorescence; immediate dull white cut fluorescence; amber to dark amber visible cut; medium straw to dark straw visible residue; moderately bright to dull white residual fluorescence. Sand(12380-12500)=medium gray to light gray to medium light gray; upper very fine to lower fine throughout sample interval;sub-angular to sub-rounded with moderate sphericity;<5%brilliant green to moderate green to translucent light bluish green glauconite, very fine to fine grained, sub-angular to sub-rounded with moderate sphericity; 10-20% black lithics, very fine grained, throughout sample interval giving a salt and pepper appearance;shell fragments appear occasionally;slight to fragrant oil odor above OBM; no visible oil stain; 100% dull yellow sample fluorescence; streaming dull white to milky white cut fluorescence; amber visible cut; light straw visible residue; dull yellowish white residual fluorescence. Sand(12500-12590)=medium light gray to translucent to light gray;upper very fine to lower fine;sub-angular to sub-rounded with moderate sphericity; <5% brilliant green to moderate green to translucent bluish green glauconite throughout sample,fine to very fine,sub-angular to sub-rounded,moderate sphericity; 10-15%very fine grained black mafic grains throughout sample interval giving salt and pepper appearance;fragrant to slight oil odor above OBM; no visible oil staining; 100%even dull yellow sample fluorescence;streaming dull white cut fluorescence; amber visible cut; straw to light straw visible residue; dull white residual fluorescence. Sand (12590-12680)= light gray to translucent to medium light gray throughout sample interval; upper very fine to lower fine; sub-angular to sub-rounded; moderate to high sphericity; 2-4% moderate green to brilliant green to translucent bluish green glauconite, fine to very fine, sub-angular to sub-rounded, moderate sphericity; 10-20%very fine black lithics scattered throughout sample interval; slight to fragrant oil odor; no visible oil staining; 100% even dull yellow sample fluorescence; streaming dull to moderately bright cut fluorescence; amber visible cut; straw visible residue; moderately bright white residual fluorescence. Sand(12680-12770)=translucent to light gray to medium light gray;upper very fine to lower fine;sub-angular to sub-rounded with moderate to high sphericity; approximately 3%translucent light bluish green to brilliant green glauconite, very fine to fine, sub-angular, moderate sphericity; 10-20%very fine to fine grained black lithics;occasional shell fragments throughout sample interval;grades into sandy siltstone as depth increases; firmly friable to moderately hard; slight oil odor; no visible oil staining; 100% even dull yellow sample fluorescence; streaming dull white cut fluorescence; amber to light amber visible cut; dark straw visible residue; moderately bright white residual fluorescence. FAULT 12762.0'MD/-3841.9'TVDSS Sand(12770-12890)=light gray to translucent to medium light gray sand grains;upper very fine to lower fine; sub-angular to sub-rounded with moderate sphericity; <5% bluish green to moderate green glauconite, very fine to fine grained, sub-angular to sub-rounded with moderate sphericity; 15-20% very fine grained black lithics giving salt and pepper appearance; some grading between silty sandstone and sandy siltstone in this depth interval; moderately hard to friable;some very thin black and dark brown laminations noted on cuttings smooth faces; slight to fragrant oil odor; 80-100% even dull yellow to yellowish white sample fluorescence; slow streaming dull white cut fluorescence;dark straw to light amber visible cut;light pale straw to straw visible residue; dull to faint yellowish white residual fluorescence. Siltstone (12800-13010) = brownish black to olive gray to brownish gray to medium gray; firmly friable to moderately hard;predominantly tough and dense to occasionally brittle and crunchy; massive tabular wedge like cuttings habit dull waxy to vitreous luster; generally a silty gritty texture throughout sample interval; frequent very thin black to reddish brown laminations; grades between silty sandstone and sandy siltstone; siltstone quantity steadily decreases over last 100' of sample interval; slight to fragrant oil odor; occasional light brown oil stain on some siltstone cuttings; patchy dull dark yellow sample fluorescence; slow streaming dull white cut fluorescence; straw to dark straw visible cut; light pale straw visible residue; moderately bright white residual fluorescence. 30 CANRIG ,eni Eel Petroleum OP05-06, PB1 and PB2 Sand/Sandstone (13010-13130) = light gray to medium light gray to translucent gray throughout sample interval; upper very fine to lower fine to occasional upper fine grained; well to very well sorted; moderate to high sphericity;disaggregated to loose sand;sub-angular to sub-rounded;translucent to very light gray to light gray quartz predominates;trace to abundant brilliant green to dusky green glauconite;very fine grained;sub- rounded to rounded with high to moderate sphericity; 10-20%very fine grained black lithics/mafics creating a slight salt and pepper appearance; trace orangish pink shell fragments; slight to fair oil odor; trace to slight brown oil staining in scattered sandstone cuttings when prodded and broken open; 100% even dull yellow sample fluorescence;slow streaming dull yellowish white cut fluorescence;slow streaming to faint pale straw to straw visible cut; moderate light straw to straw residual ring; faint yellowish white residual fluorescence; slightly to moderately calcareous within depth interval. Sand/Sandstone (13160-13260)=light gray to translucent to medium light gray throughout sample interval; upper very fine to lower fine grained; grading toward upper fine and even trace lower medium grained at bottom of interval; well to very well sorted; sub-angular to sub-rounded; moderate to high sphericity; disaggregated loose sand grains to friable to firm sandstone cuttings;sandstone cuttings trend from firm/friable to hard with depth; base of interval appears to have slight concentration of concretions; fair to moderate oil odor; no visible oil staining present in sand; 20-30% brown oil staining present in sandstone cuttings; 100% even dull yellow sample fluorescence; steaming dull white cut fluorescence; streaming dark amber to light brown cut; faint straw residue; dull white residual fluorescence. Sand/Sandstone (13260-13430) = light gray to medium light gray to light olive gray throughout sample interval; upper very fine to lower fine to upper fine grained; well to very well sorted; sub-angular to sub- rounded;moderate sphericity to sub-spheroidal;disaggregated loose sand;increase in sandstone cuttings and are firm to moderately hard to hard in parts; slower drill rate coincides with higher amount of concretions; predominantly translucent white to light gray to slightly smokey quartz; trace to common lower fine grained moderate blue green to dusky green glauconite; 10-20% very fine grained black lithics; salt and pepper appearance;trace to abundant yellowish orange to orangish pink shell fragments;slight to fair oil odor; no oil staining on sand grains; 20-30% brown oil staining in sandstone cuttings; 100% even dull yellow sample fluorescence;streaming dull white cut fluorescence;slow streaming straw to light amber visible cut;light straw residual ring fluoresces dull white; slightly to moderately calcareous. OA SAND SUB-LOBE 3 13450.0'MD/-3845.4'TVDSS OA SAND SUB-LOBE 2 13508.0'MD/-3842.6'TVDSS Sand/Sandstone (13430-13520) = light gray to translucent to medium light gray throughout the sample interval; upper very fine to lower fine grained;well to very well sorted;sub-angular to sub-rounded;moderate to high sphericity; loose sand to firm to moderately hard sandstone cuttings;sandstones grade between sitly sandstones and sandy siltstones;siltier cuttings are dense moderately hard to hard; light gray to light grayish brown;thin dark brown micro-laminae can be seen on the smooth sides of siltstone cuttings; 10-20%very fine grained black lithics;<5%moderate blue green to dusky green upper very fine grained glauconite;slight to fair oil odor; no oil staining on sand grains; 20-30%dark brown oil staining in sandstone cuttings when prodded and broken open; 100% even bright yellow to slightly dull white sample fluorescence; slow blooming milky white cut fluorescence; fast streaming amber to light brown visible cut; light to moderate amber residue; dull white residual fluorescence. OA SAND SUB-LOBE 1 13578.0'MD/-3893.2'TVDSS Sand/Sandstone (13550-13640)=light gray to translucent gray to medium light gray overall;upper very fine to lower fine grained; well to very well sorted; sub-angular to sub-rounded; moderate to sub-spheroidal; disaggregated loose sands;sandstones are firm to moderately hard;grades silty sandstone to sandy siltstone; trace yellowish orange to orangish pink shell fragments;slight oil odor; no oil staining; 100%even dull yellow fluorescence; slow streaming dull milky white cut fluorescence; slow streaming light amber cut; faint straw residue fluoresces dull white. 31 CANRIG em Eel Petroleum OP05-06, PB1 and PB2 OA SAND SUB-LOBE 1 13776.0'MD/-3896.5'TVDSS Sand/Sandstone (13640-13790) = medium light gray to translucent to light gray overall; upper very fine to lower fine to trace upper fine;very well to well sorted;sub-rounded to sub-angular;moderate to high sphericity; loose sands;disaggregated;sandstone cuttings are friable to slightly firm;predominantly translucent white to light gray to slightly smokey quartz;trace shell fragments are moderate reddish orange to moderate orangish pink; in the 13760'sample sandstones start to grade toward a friable to moderately hard siltstone;light gray to very light brownish gray; dense to brittle in part; slight to faint oil odor; 10-20% brown oil staining in the sandstone cuttings; 100% even dull yellow sample fluorescence; slow streaming faint milky white cut fluorescence; pale straw to straw cut; light pale straw residue; faint yellowish white residual fluorescence; slightly calcareous. Sand/Sandstone (13790-13880) = light gray to medium light gray to translucent white throughout sample interval; upper very fine to lower fine to occasional upper fine grained;well to very well sorted;sub-angular to sub-rounded; moderate sphericity; friable to soft to firm; light gray to slightly smokey quartz predominates; <5% moderate green to dusky green fine grained glauconite; 5-10%very fine grained black lithics; slight oil odor; no oil staining on sand grains; 10-20%brown oil staining in sandstone cuttings; 100%even dull yellow sample fluorescence;slow streaming dull milky white cut fluorescence;slow pale straw to straw cut;faint pale straw to straw residue; dull white residual fluorescence. Sand/Sandstone (13880-14000) = medium light gray to translucent white to light gray throughout sample interval; upper very fine to lower fine to occasional upper fine; well to very well sorted; sub-angular to sub- rounded;moderate sphericity; loose sand to soft to friable;sandstone cuttings continue to grade between silty sandstone and sandy siltstone; <5%brilliant green to moderate bluish green fine grained glauconite;trace to common very fine grained black lithics/mafics giving slight salt and pepper appearance;slightly to moderately calcareous;faint oil odor; no oil staining in sand grains; 10-20%brown oil staining in sandstone cuttings when broken open; 100%even dull sample fluorescence;slow streaming dull milky white cut fluorescence;very slow streaming straw to light amber cut; very faint pale straw residual ring fluoresces dull white. Sand/Sandstone (14000-14210)=medium light gray to light gray to translucent throughout sample interval for free sand grains; upper very fine to lower fine;very well sorted;sub-angular to sub-rounded with moderate sphericity;sandstone cuttings are dusky yellowish gray to dusky olive gray;easily friable to friable;sandstone cuttings continually grade between silty sandstone to sandy siltstone throughout this sample interval; higher silt contents generally indicate increased hardness; approximately 5% moderate green to brilliant green glauconite, very fine to fine, sub-rounded to sub-angular with moderate sphericity; 10-20% black lithics scattered throughout sample interval giving salt and pepper appearance;approximately 5%moderate orange pink to pale yellowish orange to very pale orange shell fragments varying in size from fine to small pebble; slight to fragrant oil odor observed above OBM; no oil stain visible on free sand grains, light brown to dark brown oil staining within prodded open sandstone cuttings; 100%even dull to moderately bright yellow sample fluorescence,some samples containing higher percentages of sandstone and siltstone cuttings exhibit patchy dull to moderately bright dark yellow to orangish yellow sample fluorescence;streaming bright to dull white cut fluorescence;dark brown visible cut;medium dark straw to light amber visible residue;moderately bright white to yellow residual fluorescence. Sand/Sandstone (14210-14390)=light gray to medium light gray to translucent to medium gray;upper very fine to lower fine; very well sorted; sub-angular to sub-rounded with moderate to high sphericity; sandstone cuttings are olive black to brownish gray;easily friable to firmly friable;occasionally grades between sandstone to silty sandstone to sandy siltstone within sample interval; hardness generally increases with silt content; brilliant green to moderate green glauconite. very fine to fine, sub-angular to sub-rounded with moderate sphericity; approximately 20% black lithics throughout sample interval giving salt and pepper appearance; moderate orange pink to pale yellowish orange shell fragments, increasing in abundance at the end of the sample interval; slight oil odor; no visible oil staining on free sand grains; light brown oil staining within sandstone cuttings when prodded open;all samples within interval have 100%dull to moderately bright yellow to yellowish white sample fluorescence;samples containing sandstone/siltstone cuttings have that percentage of patchy dull dark yellow to orangish yellow sample fluorescence; immediate dull white cut fluorescence; 32 C.ANRIG eni Eni Petroleum OP05-06, PB1 and PB2 amber visible cut; pale straw to clear visible residue; faint white residual fluorescence. OA Sand Sub-Lobe 2 14460.0'MD/-3871.0'TVDSS Siltstone (14350-14500) = medium gray to olive black to brownish gray; moderately hard to friable; harder cuttings tend to have a tougher denser tenacity,whereas softer cuttings are more crumbly and brittle;blocky to occasional planar fracture;tabular wedge like cuttings habit;greasy vitreous to dull waxy luster;texture varies with sand and silt content between silty and gritty; very thin black and dark reddish brown laminations are noticeable on smooth sides of cuttings; slight oil odor; no visible oil staining; dark yellow to orangish yellow sample fluorescence; slow blooming bright bluish white cut fluorescence; dark amber visible cut; medium to heavy light amber visible residue; bright white residual fluorescence. Sand/Sandstone (14390-14660)=light gray to translucent to medium light gray; upper very fine to lower fine; very well sorted;sub-rounded to sub-angular with moderate sphericity;sandstone cuttings are brownish black to olive gray to olive black; easily friable to firmly friable; continually grading between sandstone and silty sandstone and sandy siltstone and siltstone; generally hardness is higher when silt content is higher; moderate green to brilliant green to light bluish green glauconite,very fine to fine,sub-angular to sub-rounded with moderate sphericity; 10-20%very fine to fine grained black lithics; pale yellowish orange to moderate orange pink shell fragments throughout sample interval; slight to fragrant oil odor; slight brownish hue to overall sample possibly attributed to oil stain, could also be due to OBM; prodded open sandstone cuttings exhibit light brown to dark brown oil stain; 100% even dull to moderately bright yellowish white sample fluorescence; sandstone cuttings exhibit patchy dark yellow sample fluorescence; immediate bright to dull white cut fluorescence; dark amber to brown visible cut; light dark straw visible residue; dull white residual fluorescence. Sand/Sandstone (14601-14790)=medium light gray to light gray to translucent;upper very fine to lower fine to upper fine; well to moderately well sorted; sub-angular to sub-rounded; moderate sphericity; sandstones easily friable to friable;approximately 5%brilliant green to dusky green glauconite; 15-20%very fine grained black lithics;trace to occasional yellowish orange to moderate orangish pink shell fragments; slight to fair oil odor; no free oil stain on sand grains; light brown to dark brown oil stain within prodded and broken open sandstone cuttings; 100% even dull yellow sample fluorescence; streaming dull white cut fluorescence; streaming dark straw to light amber visible cut;faint straw to light amber residue;dull yellowish white residual fluorescence. Siltstone(14750-14900)=brownish gray to medium gray to olive black throughout interval;moderately hard to firmly friable to friable; tough dense tenacity on harder cuttings and crumbly or brittle tenacity on softer cuttings;blocky to occasional planar fracture;tabular wedge like cuttings habit;greasy to vitreous exterior with dull waxy interior luster;texture varies according to sand and silt ratio of cuttings between silty and gritty;very thin black to dark brown to reddish brown micro-laminations are visible on smooth faces of cuttings; slight oil odor; some greasy luster staining on cuttings; dark yellow to orangish yellow dull sample fluorescence; slow streaming bright white cut fluorescence;amber to dark amber visible cut;medium light amber visible residue; bright white residual fluorescence. OA SAND SUB-LOBE 2 14912.5'MD/-3890.9 TVDSS Sand/Sandstone (14790-15050)=light gray to medium light gray to translucent throughout sample interval; upper very fine to lower fine; sub-angular to sub-rounded with moderate sphericity; sandstone cuttings are olive black to brownish black to dark gray; easily friable to firmly friable, with hardness generally increasing with silt content;3-5%moderate green to brilliant green to light bluish green glauconite,very fine to fine,sub- angular to sub-rounded with moderate to high sphericity; approx 15% black lithics, very fine to fine; pale yellowish orange to moderate orange pink shell fragments throughout sample interval varying in size from fine to small pebble;slight to fragrant oil odor; no visible oil stain on free sand grains,however a light brownish hue is visible of samples as a whole; sandstone cuttings have light brown to dark brown oil staining within split apart cuttings; immediate dull white cut fluorescence; amber to dark amber visible cut; light straw visible residue; faint white residual fluorescence. 33 CANR10 ,cni Eni Petroleum OP05-06, PB1 and PB2 FAULT 5 15168.5'MD/-3901.6'TVDSS Sand/Sandstone (15050-15200)=medium light gray to light gray to translucent; upper very fine to lower fine; sub-rounded to sub-angular with moderate sphericity; sandstone cuttings are olive gray to olive black to brownish black; easily friable to firmly friable; hardness typically increases as silt content increases; 3-5% translucent bluish green to brilliant green to moderate green glauconite, fine to very fine, sub-angular with moderate sphericity; 10-20%black lithic grains,very fine to fine,predominantly angular,gives salt and pepper appearance;pale yellowish orange to moderate orange pink to grayish orange pink shell fragments throughout sample interval,fine to pebble sized,strong reaction to HCI;slight to fragrant oil odor;no visible oil staining on free sand grains, although an overall light brown hue exists on samples; sandstone cuttings contain light brown to dark brown oil staining within prodded open cuttings; 100% even dull yellowish white sample fluorescence; immediate dull white cut fluorescence;dark straw to light amber visible cut;medium light amber to amber visible residue; moderately bright to bright white residual fluorescence. Sand/Sandstone (15200-15380)=light gray to medium light gray to translucent throughout sample interval; upper very fine to lower fine; very well sorted; sub-angular to sub-rounded with moderate sphericity; sandstone cuttings vary between olive gray and olive black generally;easily friable to friable with some firmly friable cuttings; hardness of sandstone cuttings generally increases as silt content increases within cuttings; some grading to silty sandstone and sandy siltstone;approx 5%moderate green to brilliant green glauconite, very fine to fine, sub-angular to sub-rounded with moderate sphericity; 15-20%very fine to fine grained black lithics throughout sample interval giving salt and pepper appearance; grayish orange pink to pale yellowish orange to moderate orange pink shell fragments, predominantly sized between fine and pebble; slight oil odor; no visible oil staining on free sand grains; light brown to dark brown oil staining within prodded open sandstone cuttings; 100%even dull yellowish white sample fluorescence;streaming dull to moderately bright cut fluorescence;amber to dark amber visible cut;medium amber to light amber visible residue;dull yellowish white residual fluorescence. Sand/Sandstone (15380-15560)=medium gray to light gray to translucent to medium light gray; upper very fine to lower fine throughout sample interval; very well sorted; sub-angular to sub-rounded with moderate sphericity; sandstone cuttings are predominantly olive black to olive gray to brownish gray; easily friable to firmly friable; sandstone grades between silty sandstone and sandy siltstone throughout interval; hardness generally increases with silt content;3-5%moderate green to bluish green to brilliant green glauconite,fine to very fine, sub-angular with moderate sphericity; 10-20%very fine to fine grained black lithics; pale yellowish orange to moderate orange pink to grayish orange pink shell fragments throughout sample interval in varying amounts,size generally ranges between medium and small pebble;very slight oil odor,possibly due to OBM; no visible oil staining on free sand grains, light brownish hue of sample as a whole; sandstone cuttings have light brown to dark brown oil stain within when split open; 100% even dull yellowish white sample fluorescence; immediate dull white cut fluorescence; amber to dark amber visible cut; medium straw to dark straw visible residue; dull white residual fluorescence. Sand(15560'-15650')=medium 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 rounding; well to very well sorted; unconsolidated sand; grain supported; texturally immature; compositionally sub-mature; translucent quartz with light pale yellowish orange hue; light green to green glauconite and black lithics present; very slight oil odor, trace stain on sand grains, light brown, 100%even light green sample fluorescence, immediate bright bluish white streaming to blooming cut fluorescence; amber to dark amber cut; residual cut medium straw to dark straw; dull whit residual fluorescence; porosity and permeability visually good. Sand/Sandstone (15650'-15770')=medium gray to medium light gray with olive gray sub tones;upper very fine to lower fine grained; spherical to sub-discoidal; sub-angular to sub-rounded; very well to well sorted; unconsolidated sand, sandstone is friable; sand grains are matrix supported; texturally immature; compositionally sub-mature; translucent quartz 90% of grains, with green glauconite and reddish brown carbonaceous material; very slight oil odor; no stain on sand or sandstone; patchy 100%fluorescence with uneven intensity which varies from faint to bright; instantaneous blooming cut with streamers visible in the 34 C:ANRIG ,eni Eni Petroleum OP05-06, PB1 and PB2 bright white cut; cut light amber to amber cut; light residual straw to dark straw cut; dull white residual fluorescent cut; porosity and permeability visually good. Sand/Sandstone (15770'-15860')=medium light gray to medium gray with olive gray sub hues;upper very fine to lower fine grains; spherical to sub-discoidal; sub-rounded to sub-angular; very well to well sorted; unconsolidated sand; sandstone is friable; sand grains are matrix supported; texturally immature; compositionally sub-mature; translucent quartz grains with occasional white grains; green glauconite and reddish brown carbonaceous material present; no odor to very faint oil odor; no stain to trace stain in sandstone grains; sample fluorescence 100% even light green grading to 100% patchy faint light green; streaming to blooming bright bluish white fluorescent cut;faint amber to light brown cut; residual cut light straw to dark straw; dull white residual fluorescent cut; porosity and permeability visually good. Sand(15860'-15950')=medium gray to medium light gray with olive gray sub-hues; upper very fine to lower fine grained;spherical to sub-discoidal; sub-angular to sub-rounded;very well to well sorted; unconsolidated sand;very friable sandstone; sandstone matrix supported; texturally immature; compositionally sub-mature; translucent quartz grains;glauconite and reddish brown carbonaceous material; no oil odor; no stain on sand grains, amber grain staining in sandstone; sample fluoresces even to patch to even 100% as the interval progresses; streaming bright white fluorescent cut; faint amber to light brown cut; residual cut light to dark straw; dull white residual fluorescent cut; porosity and permeability visually good. Sand(15950'-16110')=medium light gray and medium gray with light olive sub tone;upper very fine to lower fine grains;spherical to sub-discoidal;sub-angular to sub-rounded;very well to well sorted; unconsolidated sand;very friable sandstone;sandstone matrix supported;matrix silt;texturally immature;compositionally sub- mature;translucent quartz grains;glauconite, reddish brown carbonaceous material and shell fragments;odor none to slight; no stain on sand grains, slight amber stain in sandstone; fluorescence 100% light green with brighter intensity in siltstone/sandstone;streaming to blooming white cut; light brown to amber cut; residual cut dark brown to light brown; residual fluorescence faint white; porosity and permeability visually good. Sand/Sandstone (16110'-16220')=medium light gray to medium gray with greenish gray sub hues; upper very fine to lower fine grained;spherical to sub-discoidal;sub-angular to sub-rounded;well to very well sorted; unconsolidated sand, sandstone is easily friable; sandstone is matrix supported; sandstone matrix contains silt;texturally immature;sub-mature compositionally;green glauconite,reddish brown carbonaceous material and pale yellowish orange shell fragments present; no odor to faint oil odor;no stain on sand grains,faint pale yellowish orange stain within sandstone; 100%even light bright green sample fluorescence;cut fluorescence is streaming to blooming bright bluish white; cut is amber to light brown; residual cut is heavy dark amber; residual fluorescence is dull white; porosity and permeability visually good. OA SAND-LOBE 3 16300.00'MD/-3938.0'TVDSS Sand/Sandstone (16220'-16340)=dark gray to medium dark gray;upper very fine grained;sub-discoidal to spherical; sub-rounded to sub-angular; well to very well sorted; unconsolidated sand, sandstone is easily friable;matrix supported sandstone,sandstone matrix is silt;texturally immature;compositionally sub-mature; green glauconite, reddish brown carbonaceous material and pale yellowish orange shell fragments;no to very faint oil odor; sand grains, no stain, faint amber yellow stain within sandstone; 100%even light bright green sample fluorescence; streaming to blooming bright bluish white fluorescent cut; amber to light brown cut; residual cut heavy dark amber; residual fluorescence dull white; porosity and permeability visually good. OA SAND SUB-LOBE 2 16472.0'MD/-3940.8'TVDSS Siltstone(16350-16500)=olive black to olive gray to brownish gray to medium gray to occasional light gray; moderately hard to firmly friable to easily friable; harder cuttings tend to exhibit a tough dense tenacity,while softer cuttings are more brittle and crunchy; blocky fracture; tabular to wedge like to massive cuttings habit; greasy vitreous exterior luster,waxy dull to frosted interior luster;texture is dependent upon silt to sand ratio, varying between degrees of silty and gritty; very thin black to brown to reddish brown micro-laminations are visible on smooth sides of cuttings; no oil odor above OBM; no visible oil staining;20-50%patchy faint to dull 35 C:ANRIG INt ,end Ent Petroleum OP05-06, PB1 and PB2 white to yellow sample fluorescence;very slow blooming dull to faint white cut fluorescence;straw visible cut; medium pale straw visible residue; dull white residual fluorescence. Sand/Sandstone (16350-16610)=light gray to medium light gray to translucent throughout sample interval; upper very fine to lower fine;very well sorted;sub-angular to sub-rounded with moderate sphericity;sandstone cuttings are olive black to brownish black to brownish gray; easily friable to firmly friable; hardness seems to increase with silt content; sandstone continually grades between silty sandstone and sandy siltstone throughout this sample interval;approximately 5%moderate green to brilliant green fine grained glauconite;5- 20% very fine black mafic grains scattered throughout sample interval; pale yellowish orange to grayish orange pink shell fragments varying in size between fine and small pebble;faint oil odor; no visible oil stain on free sand grains; light brown to dark brown oil staining within sandstone cuttings when prodded open; 100% even dull yellowish white sample fluorescence; immediate dull white cut fluorescence; straw to dark straw visible cut; light dark straw visible residue; faint to dull yellowish white residual fluorescence. Sand/Sandstone (16610-16790)=medium light gray to translucent to light gray throughout sample interval; upper very fine to lower fine;very well sorted;sub-angular to sub-rounded with moderate sphericity;sandstone cuttings are olive gray to olive black to brownish black; easily friable to firmly friable; hardness typically increases with silt content; sandstone grades into silty sandstone to occasionally sandy siltstone; moderate green to brilliant green to translucent bluish green glauconite, approximately 5%; 15-25%of free grains are very fine to fine sized black mafics, angular to sub-angular;varying quantities throughout sample interval of pale yellowish orange to grayish orange pink to moderate orange pink shell fragments,sized from fine to small pebble; slight oil odor above OBM; no visible oil staining on free sand grains, although a light brown hue is visible of sample as a whole;sandstone cuttings contain light brown to dark brown oil staining within when split open; 100% even dull yellowish white sample fluorescence; streaming dull to moderately bright white cut fluorescence; amber to dark amber visible cut; light straw to dark straw visible residue; dull yellowish white residual fluorescence. Sand/Sandstone (16790-17000)=light gray to medium light gray to translucent to medium gray; upper very fine to lower fine; very well sorted; sub-angular to sub-rounded with moderate sphericity; sandstone is olive gray to olive black to brownish gray;easily friable to friable;sandstone has silt matrix and grades between silty sandstone and sandy siltstone, eventually grading to siltstone near the end of this sample interval; hardness typically increases simultaneously with silt content; approx 3-5%glauconite; 15-25%black lithics throughout sample interval giving salt and pepper appearance; pale yellowish orange to grayish orange pink shell fragments; slight to fragrant oil odor; no visible oil staining on free sand grains; light brown to dark brown oil staining within prodded open sandstone cuttings; 100% even dull yellowish white sample fluorescence; streaming dull white cut fluorescence;amber visible cut;straw visible residue;dull white residual fluorescence. OA SAND-LOBE 1 16895.0'MD/-3947.0'TVDSS Siltstone(16880-17035)=brownish gray to medium dark gray to olive black;moderately hard to firmly friable to easily friable;tough dense to brittle and crunchy tenacity; blocky fracture;tabular to wedge like to massive cuttings habit;greasy vitreous exterior to waxy dull earthy interior luster;silty to gritty texture;very thin black to brown to reddish brown laminations are visible on smooth surfaces of cuttings;slight to no oil odor; no visible oil stain; even faint yellowish white sample fluorescence; slow streaming dull white cut fluorescence; amber visible cut; medium straw visible residue; dull yellowish white residual fluorescence. 3.3.2 PB1 Carbonaceous Shale(6160-6220) = reddish brown to brownish black throughout sample interval; moderately firm to firm to locally hard; brittle; splintery to slightly blocky fracture; wedge like almost bladed cuttings habit; earthy resinous luster; mottled texture; thin micro laminae present in larger pieces; strong reaction to hcl still in part due to mud additive; 5-10%dull yellow fluorescence may be due to mud additive or dead oil. 36 CANRIG _e,i Eni Petroleum OP05-06, PB1 and PB2 Sand/Sandstone(6220-6340)= light gray to medium light gray to brownish gray throughout sample interval; lower fine to lower medium grained; moderate well to well sorted; subrounded to subangular to locally rounded in part; moderate to high sphericity; disaggregated loose sand to scattered soft sandstones; intact sandstones contains light to dark brown oil staining visible in sample tray 10%; 50-60% translucent to colorless to white quartz; common light gray to smokey quartz; trace to common light brown to dark gray minerals; slightly calcareous; 10% patchy dull orange sample fluorescence; slow dull white cut fluorescence; slow pale straw cut; light pale straw residue; faint orangish yellow residual fluorescence from dead oil or mud products. Sand/Sandstone(6340-6460)= light to medium light gray with a secondary brownish hue; lower fine to lower medium to slightly upper very fine in part; moderate well to well sorted; subrounded to subangular to few rounded grains; moderate to high sphericity; disaggregated; slightly calcareous; predominately translucent frosty quartz to clear transparent to light smokey gray; 20-30% light brown oil staining present in sample interval; trace individual pyrite grains; 10-20% brownish black to grayish black lithics/minerals; trace orange and pale green to light green lithics; no odor present; 20-30% patchy dull orange sample fluorescence decreasing to 10%with depth in interval; slow faint yellowish white cut fluorescence; light pale straw visible cut; faint orangish yellow residual cut fluorescence; fluorescence may be dead oil or mud additive. Sand/Sandstone(6440-6610)= light to medium light brownish gray; soft to dis-aggregated; friable; moderately well to well sorted; occurs as moderate beds vertically sorted; fine upper to medium lower and fine lower in the upper portion; medium lower to fine upper and medium upper at the base; sub-angular to angular; predominantly translucent white to clear colorless and slightly smokey quartz; 20 to 30% medium to dark and light gray lithics; trace to common dark gray to black mafic mineral/lithics; trace very hard pyritic ironstone; trace blue-gray and brown grains; appears to be primarily matrix supported but matrix is very hydrophilic and or so pulverized in drilling that it is lost into the mud system; moderate amounts of silt are present in the unwashed sample but are immediately lost in sample preparation; 10 to 20% transparent brown stain; 40 to 100%dull greenish yellow sample fluorescence; slow streaming cut to medium yellow; slight brownish residue fluoresces dull yellow and cuts to medium yellow; no oil odor; mud fluoresces 100% medium yellow; trace to slightly calcareous. Sand/Sandstone(6610-6760)= light to medium light gray with a slight brownish secondary hue; soft to dis-aggregated; sample recovered as a slurry of loose sand in loose silt; friable in part;well to moderately well sorted; vertical sorting in moderate beds;fine upper to medium lower and fine lower at the top of beds grading to medium lower to fine upper at the base; trace medium upper grains; primarily translucent white to clear colorless occasionally smokey quartz; 20 to 30%medium to dark and light gray lithics;trace dark gray and black lithic/mafic mineral grains;trace fractured pyritic ironstone fragments;trace to common brown grains; scattered green-gray and blue gray grains; trace white calcite; 5% brown stained sand and occasional clumps of sand grains; 100% dull greenish yellow fluorescence in drilling mud; 100% dull to very dull greenish yellow sample fluorescence; slow streaming to slow crush cut to medium yellow; slight brownish residue cuts to medium yellow; no oil odor; very slightly calcareous. Sand/Sandstone(6760-6880)= medium light to light gray with a slight brownish secondary hue; soft to dis-aggregated; well to moderately well sorted; sub-angular to angular; fine upper to medium lower and fine lower grain; trace medium upper particularly along lower bedding contacts; predominantly translucent white to clear colorless and smokey quartz; 20 to 30 % medium to light and dark gray lithics; common black mafic mineral grains and pyritic coal fines; trace pyritic iron-stone fragments; trace blue-gray and greenish gray grains; trace pyrite; <5% brown oily stain on sand grains; trace clumpy oil stained sand; 100%of dull to very dull yellow sample fluorescence; slight slow streaming cut to medium yellow; slight brown residue cuts to medium yellow; no oil odor; very slightly calcareous. Sand/Sandstone(6940-7036) = medium gray to light gray to slight secondary olive hue; lower medium to upper fine;well to moderate well sorted;sub-angular to angular; moderate sphericity;soft to dis-aggregated; trace pyrite grains;trace pyritic coal;20-30%brownish black to dark black lithics;<5%light brown oil staining; 50%dull yellow sample fluorescence; slow streaming light yellow cut; light brown residual fluorescence; no odor. 37 CANRIG Eni Petroleum OP05-06, PB1 and PB2 3.3.3 PB2 Sand/Sandstone(14660-14840) = medium light gray to light gray to translucent throughout sample interval for free sand grains; upper very fine to lower fine; very well sorted; sub-angular to sub-rounded with moderate sphericity; sandstone cuttings are dusky yellowish gray to dusky olive gray; easily friable to friable; sandstone cuttings grade between silty sandstone and sandy siltstone throughout the sample interval; hardness typically increases with silt content; approximately 5% moderate green to light bluish green to brilliant green glauconite, very fine to fine, sub-angular to sub-rounded with moderate sphericity; 15-20% black lithic grains throughout sample interval, fine to very fine grained; moderate orange pink to pale yellowish orange to very pale orange shell fragments varying in size from fine to small pebble; slight to fragrant oil odor; no visible free oil stain on sand grains; light brown to dark brown oil stain within prodded open sandstone cuttings; 100% even dull yellowish white sample fluorescence; patchy dull dark yellow sample fluorescence when sandstone and siltstone cuttings are present; immediate bright white cut fluorescence; amber to dark brown visible cut; medium light amber to amber visible residue; bright white residual fluorescence. Siltstone(14850-15000)=dark gray to olive black to brownish gray to light gray; hard to friable to some soft cuttings; tenacity varies from tough and dense to crumbly and brittle; blocky to occasional planar fracture; massive tabular wedge like cuttings habit; greasy vitreous to dull waxy and earthy luster; texture varies with silt to sand ratio between clayey silty to silty gritty; very thin black to dark brown to reddish brown micro-laminations visible on smooth surfaces of cuttings; slight oil odor; oil staining tough to distinguish with dark colored cuttings, no visible stain on lighter colored cuttings; even dull yellowish white sample fluorescence; slow streaming dull white cut fluorescence; dark brown visible cut; moderate dark brown residual ring; bright yellowish white to white residual fluorescence. Sand/Sandstone(14840-15080)= light gray to translucent to medium light gray; upper very fine to lower fine; very well sorted; sub-angular to sub-rounded with moderate to high sphericity; sandstone cuttings tend to be easily friable to firmly friable; 5% moderate green to brilliant green glauconite; 15% black lithics throughout sample interval giving salt and pepper appearance; pale yellowish orange to moderate orange pink shell fragments throughout entire interval in varying amounts; slight oil odor; no visible oil staining on free sand grains, however an overall brownish hue is noticeable on samples, which could be attributed to OBM; light brown to dark brown oil stain within sandstone cuttings when split open; 100%even dull yellowish white sample fluorescence; slow streaming dull to moderately bright white cut fluorescence; amber visible cut; moderate to slightly heavy brown to dark brown residue; bright yellowish white to white residual fluorescence. Siltstone(15080-15170) =medium dark gray to olive black to brownish gray throughout sample interval; cuttings are predominantly dense to slightly brittle and crumbly; tabular to slightly platy cuttings habit; dull waxy to greasy luster; texture varies throughout sample interval on sand content from clayey silty to silty gritty; trace yellowish orange to moderate orangish pink shell fragments scattered throughout; slight to fair oil odor; no oil staining visible in siltstone cuttings; 100% even dull sample fluorescence; slow streaming dull milky white cut fluorescence; light amber to amber visible cut; fair to light amber residual ring; dull yellowish white residual fluorescence. Sand/Sandstone(15170-15290)= light to translucent white to medium light gray throughout sample interval; lower fine to upper fine to scattered lower medium grained; well to moderately well sorted; sub- angular to sub-rounded to occasional angular; moderate to high sphericity; dis-aggregated; loose sands to soft friable sandstone cuttings; trace moderate orangish pink shell fragments predominantly translucent white to light gray to clear colorless quartz; 5% moderate bluish green to dusky green fine grained glauconite; sub-rounded; sandstone cuttings are medium gray to medium dark gray with brownish gray secondary hues; slight oil odor; no oil staining on loose sand grains; 20% dark brown oil staining in sandstone cuttings; 100%even dull yellow sample fluorescence; streaming dull milky white cut fluorescence; slow streaming amber visible cut. 38 CANRIG ,eni Eni Petroleum OP05-06, PB1 and PB2 Siltstone (15290-15433) = medium dark gray to brownish black to brownish gray to slight olive gray throughout sample interval; siltstone cuttings are soft to friable to some slightly firm; tenacity varies between dense tough to crumbly and brittle; irregular to earthy fracture; dull waxy to slightly greasy vitreous luster; silty gritty texture; siltstone grades from sandy siltstone to silty sandstone; depending on sand content siltstones seem to trend toward very fine grained sandstones in some samples; very slight to no oil odor; <10%oil staining visible; 100%even very dull yellow sample fluorescence; very slow faint to dull milky yellowish white cut fluorescence;faint pale straw to straw visible cut; faint pale straw residue fluoresces dull yellowish white. 39 CANRIG _e i Eni Petroleum OP05-06, PB1 and PB2 3.4 Connection Gas Summary 1 Unit=0.05% Methane Equivalent Depth (ft) Background Units C-1 C-2 C-3 C-4 C-5 Gas Above MD TVDSS (Units) Background (ppm) (ppm) (ppm) (ppm) (ppm) Note: No connection gasses were observed. 3.5 Trip/Wiper Gas Summary 1 Unit=0.05% Methane Equivalent Depth at Trip(ft) Trip To Depth (ft) Max Gas Pumps Off Comments MD TVDSS MD TVDSS (units) (hours) 2425 -2151 706 -640 181 Run 13-3/8" Casing 7260 -3465 5824 -3047 24 Short trip. 8600 -3765 _ 2415 -2142 109 Run 9-5/8"Casing. 17035 -3928 8635 -3772 321 TD Well. 40 CANRIG IA ,eai Eni Petroleum OP05-06, PB1 and PB2 3.6 Iso-Tube Sample Chromatography Sample Depth Total C_1 CC=2 CC=3 C=41 C-4n CC-5i C-5n Gas MD TVDSS (units) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) 8800 -3779 326 70786 399 51 27 27 14 8078 -3671 605 113441 1308 832 572 725 499 301 9000 -3785 435 22115 22 4 3 0 0 0 9500 -3780 52 33424 71 37 27 20 14 12 10008 -3788 940 88664 95 78 95 82 99 0 10500 -3774 605 94120 399 60 68 57 76 63 11000 -3774 880 104415 521 64 65 72 73 60 11500 -3756 490 54041 255 27 27 26 34 29 12000 -3789 1026 130536 521 52 63 54 72 63 12510 -3827 880 106134 594 63 49 52 45 40 13000 -3846 967 129030 712 60 69 55 81 58 13500 -3814 245 29248 122 14 14 16 10 5 14000 -3833 550 72659 382 35 33 43 39 31 14590 -3864 505 79352 389 37 66 38 31 20 15000 -3885 315 45292 208 26 30 29 30 19 (P B-2) 15000 -3885 616 100090 478 36 35 33 37 0 15550 -3910 841 105591 544. 39 40 41 68 63 16000 -3921 686 99446 515 43 53 54 73 30 16508 -3931 504 72872 375 27 39 41 39 22 17000 -3940 30 6156 14 8 13 14 13 10 17035 -3928 8 6931 0 0 0 0 0 0 41 CANRIG eni Eni Petroleum OP05-06, PB1 and PB2 3.7 Sampling Program And Sample Dispatch Sample Program Dry samples: (2 sets) Every 30'from 1000'to TD (17,035' MD). No Wet Samples Iso-Tubes: Every 500' in production interval; 8686'to TD (17,035' MD). Iso-Jars: Every 500' in production interval; 8686'to TD (17,035' MD). Sample Dispatch Set Processed As Frequency* Interval* Dispatched to Washed-and-dried 30'/20' Fugro Data Solutions A Reference Samples, per plan 1000'—8686' 3311 S. US Hwy 77 Set Owner: ENI Schulenburg, TX 78956 Washed-and-dried AOGCC B Reference Samples, per p an 1000'—8686' 333 W. 7TH Ave., Suite 100 Set Owner: State of Alaska Anchorage,AK 99501 Washed, Spin-dried Fugro Data Solutions 0' C Reference Samples(vials), per plan 8686'—17035' 3311 S. US Hwy 77 Set Owner: ENI Schulenburg, TX 78956 Washed, Spin-dried AOGCC 30' D Reference Samples (vials), per plan 8686'—17035' 333 W. 7TH Ave., Suite 100 Set Owner: State of Alaska Anchorage,AK 99501 Iso-Jars Weatherford Laboratories E Mud Samples 500' 8686'—17035' 8845 Fallbrook Drive Owner: ENI Houston, TX 77064 Iso-Tubes Weatherford Laboratories F Gas Samples 500' 8686'—17035' 8845 Fallbrook Drive Owner: ENI Houston, TX 77064 • Sample frequency and interval may be altered locally according to on-site geologist. 42 CANRIG ,eni Eni Petroleum OP05-06, PB1 and PB2 4 PRESSURE / FORMATION STRENGTH DATA 4.1 Pore Pressure Gradient Evaluation Formation Primary Secondary Top Of Interval Pore Pressure Trend Indicators Litho loqv (%) Litholoqv(%) ,(1 (EMW, ppq) MD TVDSS Min Max Trend Permafrost Sd/Cgl 60% Sltst/Clyst 40% 8.8 9.3 Up BG,CG, MW Ugnu Sd/Cgl 60% Clyst/Sltst/Sh 2195 -1988.2 9.0 9.5 Up BG,CG,TG, MW 40/o Schrader Bluff Sd/Sltst 80% Sltst 20% 7314 -3496 8.7 9.4 Even BG, CG, TG, MW 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight(MW)and effective circulating density(ECD), including increases in background gas(BG),appearance and trends of connection gas(CG), lost circulation(LC),and magnitudes of trip gas(TG)and wiper gas(WG). Regional pore pressure trends from sonic data,provided by client,and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Epoch, and then modified using the indicators described above, and DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD—(0.6-((.001*TLGSU)+(0.05*DX))) The formula has certain limitations,such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However,the formula proved useful in helping establish a PPG range,when establishing trends, as with DXC data, with data points in shale intervals. 43 CANRIG ,eni En! Petroleum OP05-06, PB1 and PB2 5 DRILLING DATA 5.1 Daily Activity Summary 8/11/2010; Complete rig move. Rig up for surface hole. Complete picking up 5"drill pipe and BHA#1. Spud meeting as of midnight. 8/12/2010; Complete rigging up. Wash down to conductor bottom. Drilled out of conductor while picking up BHA#1 as hole was made. Continued drilling to current depth as of report 8/13/2010;Drilled ahead from 940'to TD at 2425'. Reamed the dog leg around 1850'-1950'. Hit TD and began circulating to clean hole. 8/14/2010; Circulate hole clean at TD by pumping 4 bottoms up and a sweep. Back-ream from 2425'to 680' with a max gas of 924u. Circulate and run in hole to 2425'.Circulate hole clean pump another sweep. Pull out of hole and lay down BHA. Rig up for casing. Begin running in hole with 13 3/8"casing. Run casing to 1700'as of report 8/15/2010; Run in 13 3/8"casing to 2415'MD. Rig up cementing equipment and cement. Plugs bumped and held. Nipple down BOP, installed wellhead and began to nipple up BOP. 8/16/2010; Finish nipple up BOP and run BOP test. Pick up BHA#3 and run in hole. Perform shallow test at 1040'. Cut and slip drill line and service top drive. Run in hole to 2250'and successfully test casing pressure to 2500 psi for 30 minutes. Run in hole and tag plug. Drill on plug as of report. 8/17/2010; Drilled out of shoe and made new hole to 2450'. Displaced mud. Performed LOT to a value of 11.0EMW. Drilled ahead with no issues to current depth as of report. 8/18/2010; Drill ahead without any issues.Max gas of 427 units at depth of 6246'. Continuing to drill ahead as of report. 8/19/2010; Drilled ahead from 6250'to 6878'. Ran into directional issues.Began pulling out of hole.Ran into a couple tight spots around 4670'md. Began back reaming to shoe. Continue to pull out of hole as of report. 8/20/2010;Circulate hole clean at surface casing shoe.Pulled out of hole and laid down directional assembly. Pick up back up directional tools and run in hole. Shallow test MWD tools. Run in hole to 6876'md and circulate. Drill 6878'-6894'md. Troubleshoot tools. Drill ahead to 6944'md as of report 8/21/2010; Drilled ahead to 7036'md. Could not get the desired turn rate. Decision was made to pull out and pick up mud motor. Run in hole to sidetrack at about 6250'md.Run in hole to depth of 4500'md as of midnight. 8/22/2010; Run in hole. Build trough from 6207'to 6239'md. Perform open hole sidetrack at 6239'md. Time drill and drill to 6846'md as of report. 8/23/2010; Drilled ahead from 6846' to 7164'. Had electrical problem in early AM but got worked out. Continued drilling to 7260'md. Run short trip back reaming to 5820'md. Run in hole from 5820'to 7260'md. Continue drilling and sliding from 7260'to 7612'md as of report. 8/24/2010;Continued drilling ahead from 7612'to 8217'md. Back reamed from 8217'to 7260'. Run in hole to 8217'to pump sweep. Continued drilling to 8407'md. Top drive being serviced as of report. 44 C ANIRIG Jeni Eni Petroleum OP05-06, PB1 and PB2 8/25/2010; Finished servicing the top drive. Drill ahead from 8407'to 8686'md. Circulate 3 bottoms up. Back ream out of hole from 8686'md to 5345'md as of midnight. 8/26/2010; Completed back reaming to surface casing shoe. Circulate bottoms up. Cut and slip drill line and service top drive. Run in hole back to bottom. Circulating 3 bottoms up as of report. Max trip gas 109u. 8/27/2010; Completed circulating hole clean. Pull out of hole from 8686'md to surface. Lay down BHA. Change rams and test. Rig up 9 5/8"casing equipment. Run in hole with 9 5/8"casing to 1871'as of midnight. 8/28/2010; Continued running in hole with 9 5/8"casing to 2410'md and circulated bottoms up. Run in hole to 4300'md and then 6420'md circulating bottoms up both depths. Run casing to 8671'md. Circulated and reciprocated pipe. Conditioned mud for cement job. Rig down casing equipment. Install casing pack off as of midnight. 8/29/2010;Test pack off.Change rams to 4.5"-7"variable.Run in hole 24 stands and lay down bad hard band. Service rig. Load drill pipe. Pick up 5"drill pipe.Service iron roughneck.Continue picking up 5"drill pipe as of midnight. 8/30/2010;Continue to pick up 5"drill pipe.Circulate through drill pipe. Pullout of hole and rack back drill pipe. Continue to pick up and rack back drill pipe. Rig up BOP testing equipment and begin BOP test as of midnight. 8/31/2010; Completed testing of BOP. Pressure test casing to 3000 psi for 30 minutes. Pick up BHA#6. Shallow test BHA. Service rig. Run in hole with 5" drill pipe to 7418' and tag cement. Drill out cement from 7418'to 8380'as of midnight. 9/01/2010;Continued to drill out cement to 8584'. Circulate bottoms up then test 9 5/8"casing to 3000 psi for 30 minutes. Service rig. Drill out shoe to 20'of new hole to 8706'. Circulate bottoms up and perform Leak Off Test to EMW 12.07 ppg. Drill ahead to 9540'md as of midnight. 9/02/2010; Continued drilling ahead from 9560' to current depth of 11601'md as of midnight. High gas recorded for last 24 hours is 1292u. 9/03/2010;Continue drilling from 11601'md to 13613'md with no issues as of midnight. Daily high gas peak of 1582u. 9/04/2010;Continue drilling ahead from 13613'md to 15433'md with a high gas peak of 1274u at 13868'md.At 15433'md drilled past fault at 15190'md and was decided to back ream to 14508'md and sidetrack as of midnight. 9/05/2010; Directional work from 14571'to 14604';rotary drill from 14604'to 15815',pump weighted sweep @ 15433'; generators down for one(1) hour; Rotary drill from 15815'to 16118'. 9/06/2010; Rotary drill from 16118'to 17035',circulate and condition mud, pump weighted sweep,back ream out of hole 9/07/2010; Back ream from 13709'to 8635'(casing shoe);circulate and condition drilling fluid(CBU x3);pump high weight sweep; cut/slip drilling line; calibrate blocks;trip in hole from 8635'to 16920',filling pipe every 20 stands, wash and ream from 16198'to 16920'; circulate and condition drilling fluid; pump weighted sweep; CBU x3-4; clean pits; prep for drilling fluid displacement. 9/08/2010; Circulate and condition hole; displace to oil base; pooh from 16765'to 16288',flow check: small flow;wash ream in hole from 16288'to 16920';circulate and condition bottoms up @ 16920'; monitor hole for 20 min,flow back 2.6 bbls; build volume,weight up to 9.0 heave in/out;trip out of hole from 16920'to 11988' 45 CANRIG Eni Petroleum OP05-06, PB1 and PB2 9/09/2010; Ream/wash out of hole from 11988'to 8635'; clean drill floor, prep to lay down pipe, lay down 5" drill pipe from 8635'to 3647';trip out of hole, stand back 30 stands of drill pipe; lay down BHA; monitor well: static; pick up and stand back 48 joints heavy weight drill pipe; rig up to run liner 9/10/2010; Continue running liner; make up liner setting sleeve and pick up;make up 5 1/2"liner hanger; run liner on drill piper; circulate and condition; drop ball and pump on seat to set packer;test packer on backside to 1500 psi for 10 min; record on chart. 9/11/2010; Pressure test casing shoe; test liner packer @ 1500 psi for 10 min, test good; circulate and condition, CBU @ 8431'; lay down drill pipe;service top drive/block/draw works; lay down drill pipe;trip out of hole; rig up cased hole logging tools; run cased hole logging tools in hole; log cased hole. 9/12/2010; Continue running cased hole logs; rig down cased hole logging tools; service top drive, crown, draw works, change out saver sub, grease gripper and re-torque torque tub rails;trip in hole with mule shoe, 41 stands, letdown 123 joints; run in hole with 40 stands, lay down 90 joints. 9/13/2010; Finish laying down 5"drill pipe; make up and rig up submersible pump; stand back submersible pump; test BOPs; reload pipe shed with 5"drill pipe; finish testing; pick up and make up baker fishing tools with junk basket; run junk basket in hole on 5"drill pipe. 9/14/2010; Pick up drill pipe from 807'to 8083'; circulate and condition at 8038', drop ball and pump down; ream and wash Hole from 8038'to 8467';trip in hole to 8494';trip out of hole; lay down BHA, clean metal off magnets; clean Junk baskets; cut and slip drill line; inspect draw works; wait on third party tools (string magnets); pick up Drill pipe; pick up and make up casing brush, string magnets mule shoe; trip in hole to 1009'. 9/15/2010; Continue to run in hole with magnet BHA;wash and ream from 8092'to 8494';begin to pooh;pipe skate malfunction; rack D/P in derrick;clean an document metal shavings(4-6 lbs total,two runs); run in hole to 8029'; circulate and wash to 8220'; continue to repair pipe skate. 9/16/2010; repair pipe skate and associated equipment;change out skate fluids;change out pulsation damper on Pump#1; wash ream from 8220'to 8348'; monitor well for 15 minutes; pull out of hole, lay down 5" drill pipe; clean BHA and remove metal shavings/cuttings. 9/17/2010; Pick up and rig up completion tools; pick up and make up down hole completion pumps; run in hole with down hole pumps; cable damaged;wait for tools. 46 CANRIG Plit Eni Petroleum OP05-06, PB1 and PB2 5.2 Survey Data 5.2.1 Main Wellbore Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) 0100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 138.71 0.22 230.69 138.71 -0.24 -0.17 -0.21 0.16 202.20 1.41 120.20 202.19 -0.42 -0.64 0.37 2.36 234.08 1.69 120.22 234.06 -0.50 -1.07 1.12 0.88 294.65 2.52 114.78 294.59 -0.59 -2.08 3.10 1.41 359.20 2.65 118.48 359.07 -0.68 -3.39 5.70 0.33 411.41 2.55 110.67 411.23 -0.68 -4.37 7.85 0.70 449.69 2.49 110.68 449.47 -0.56 -4.97 9.42 0.16 542.11 3.65 112.75 541.76 -0.31 -6.81 14.01 1.26 633.65 6.98 109.82 632.89 0.28 -9.83 21.94 3.65 731.32 9.55 107.70 729.54 1.79 -14.30 35.24 2.65 825.72 12.06 106.35 822.26 4.21 -19.46 52.17 2.67 922.45 15.90 102.05 916.11 8.62 -25.07 74.83 4.11 984.33 16.43 100.21 975.54 12.69 -28.39 91.73 1.19 1079.98 18.24 95.20 1066.85 21.12 -32.15 119.96 2.45 1176.06 23.25 91.62 1156.68 33.63 -34.05 153.91 5.38 1272.31 26.96 88.77 1243.82 50.69 -34.12 194.73 4.05 1366.84 27.65 88.56 1327.82 69.78 -33.11 238.08 0.74 1462.64 28.87 88.62 1412.20 89.81 -31.99 283.42 1.27 1559.14 26.71 89.19 1497.56 109.46 -31.12 328.40 2.26 1653.29 25.12 88.74 1582.24 127.39 -30.39 369.54 1.70 1748.35 26.65 89.26 1667.76 145.44 -29.67 411.03 1.63 1844.28 25.41 88.69 1753.96 163.77 -28.92 453.13 1.32 1940.72 30.98 86.32 1838.93 184.72 -26.85 498.62 5.89 2037.72 35.99 84.50 1919.81 211.02 -22.51 551.94 5.27 2132.12 39.79 83.43 1994.29 240.74 -16.40 609.57 4.09 2228.30 44.45 83.18 2065.61 274.43 -8.87 673.62 4.85 2347.28 50.94 82.99 2145.65 320.67 1.72 760.93 5.46 2497.59 50.94 83.51 2240.37 381.73 15.44 876.83 0.27 2593.21 53.96 84.09 2298.64 420.75 23.62 952.19 3.19 2689.09 57.57 84.02 2352.57 461.26 31.83 1031.02 3.77 2784.13 61.11 82.94 2401.03 503.76 41.13 1112.23 3.85 2879.73 65.06 81.84 2444.30 549.44 52.43 1196.70 4.26 2974.59 69.63 78.66 2480.83 599.09 67.29 1282.93 5.72 3070.29 74.08 77.82 2510.63 653.25 85.82 1371.94 4.72 3166.36 76.04 77.24 2535.40 709.45 105.87 1462.57 2.12 3260.85 77.12 76.53 2557.33 765.92 126.72 1552.08 1.36 3355.75 77.26 74.56 2578.37 824.47 149.82 1641.68 2.03 Measured .1 Inclination I Azimuth I True I Vertical I Latitude I Departure I Dogleg 47 CANRIG la ,eni Eni Petroleum OP05-06, PB1 and PB2 Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth(ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 3450.75 77.33 71.57 2599.27 886.14 176.81 1730.33 3.07 3547.20 77.09 71.92 2620.62 950.35 206.28 1819.65 0.43 3642.54 76.92 72.56 2642.06 1013.18 234.61 1908.12 0.68 3738.69 77.32 72.14 2663.49 1076.43 263.03 1997.44 0.60 3834.30 76.68 72.17 2685.00 1139.54 291.58 2086.11 0.67 3930.73 76.94 74.78 2707.00 1201.52 318.28 2176.11 2.65 4026.23 76.89 75.19 2728.63 126107 342.38 2265.96 0.42 4122.34 77.09 77.13 2750.26 1319.53 364.78 2356.88 1.98 4217.61 77.18 73.09 2771.48 1378.83 388.64 2446.62 4.14 4314.08 77.24 70.91 2792.84 1442.74 417.71 2536.08 2.20 4410.25 76.89 73.74 2814.37 1506.02 446.17 2625.38 2.89 4505.97 77.24 73.47 2835.80 1567.45 472.50 2714.88 0.46 4601.43 77.00 76.76 2857.09 1626.86 496.40 2804.80 3.37 4697.43 77.27 78.86 2878.46 1683.16 516.16 2896.27 2.15 4794.49 77.71 74.05 2899.50 1741.92 538.35 2988.36 4.86 4890.31 77.82 76.48 2919.81 1801.52 562.17 3078.92 2.48 4985.37 77.53 73.92 2940.10 1860.70 585.89 3168.70 2.65 5080.52 77.70 73.51 2960.51 1921.77 611.95 3257.90 0.46 5176.54 77.68 73.42 2980.98 1983.72 638.64 3347.84 0.09 5272.49 77.47 75.25 3001.63 2044.53 663.95 3438.06 1.88 5367.61 77.68 76.26 3022.09 2103.03 686.80 3528.09 1.06 5463.25 77.44 76.03 3042.70 2161.36 709.17 3618.77 0.34 5559.13 77.76 77.69 3063.29 2218.93 730.45 3709.95 1.72 5654.54 77.67 77.52 3083.59 2275.28 750.46 3801.01 0.20 5750.17 78.03 76.75 3103.25 2317.78 753.11 3896.63 1.57 5845.60 77.07 77.46 3123.82 2374.75 773.91 3987.47 1.24 5942.37 77.02 76.97 3145.51 2432.27 794.78 4079.43 0.50 6038.13 77.13 77.15 3166.93 2489.39 815.68 4170.40 0.22 6133.92 77.25 76.40 3188.17 2546.92 837.05 4261.33 0.77 6230.38 76.07 75.91 3210.43 859.5 859.5 4352.46 1.32 6326.48 76.22 74.24 3233.44 883.53 883.53 4442.61 1.69 6423.65 75.1 72.28 3257.51 910.64 910.64 4532.76 2.27 6519.47 74.57 71.94 3282.58 939.05 939.05 4620.77 0.65 6614.72 74.66 72.01 3307.85 967.47 967.47 4708.1 0.12 6709.49 73.17 72.02 3334.1 995.58 995.58 4794.71 1.57 6742.26 73.26 72.31 3343.57 1005.19 1005.19 4824.58 0.89 6806.98 74.01 70.91 3361.8 1024.79 1024.79 4883.5 2.38 6902.84 73.99 70.62 3388.22 1055.14 1055.14 4970.5 0.3 48 CANRIG Unuice.."Il..,...1.a.,1.au. eni Eni Petroleum OP05-06, PB1 and PB2 Surveys(continued) Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) 0100ft) , 3450.75 77.33 71.57 2599.27 886.14 176.81 1730.33 3.07 3547.20 77.09 71.92 2620.62 950.35 206.28 1819.65 0.43 3642.54 76.92 72.56 2642.06 1013.18 234.61 1908.12 0.68 3738.69 77.32 72.14 2663.49 1076.43 263.03 1997.44 0.60 3834.30 76.68 72.17 2685.00 1139.54 291.58 2086.11 0.67 3930.73 76.94 74.78 2707.00 1201.52 318.28 2176.11 2.65 4026.23 76.89 75.19 _.2728.63 126107 342.38 2265.96 0.42 4122.34 77.09 77.13 2750.26 1319.53 364.78 2356.88 1.98 4217.61 77.18 73.09 _2771.48 1378.83 388.64 2446.62 4.14 4314.08 77.24 70.91 2792.84 1442.74 417.71 2536.08 2.20 4410.25 76.89 73.74 2814.37 1506.02 446.17 2625.38 2.89 4505.97 77.24 73.47 2835.80 1567.45 472.50 2714.88 0.46 4601.43 77.00 76.76 2857.09 1626.86 496.40 2804.80 3.37 4697.43 77.27 78.86 2878.46 1683.16 516.16 2896.27 2.15 4794.49 77.71 74.05 2899.50 1741.92 538.35 2988.36 4.86 4890.31 77.82 76.48 2919.81 1801.52 562.17 3078.92 2.48 4985.37 77.53 73.92 2940.10 1860.70 585.89 3168.70 2.65 5080.52 77.70 73.51 2960.51 1921.77 611.95 3257.90 0.46 5176.54 77.68 73.42 2980.98 1983.72 638.64 3347.84 0.09 5272.49 77.47 75.25 3001.63 2044.53 663.95 3438.06 1.88 5367.61 77.68 76.26 3022.09 2103.03 686.80 3528.09 1.06 5463.25 77.44 76.03 3042.70 2161.36 709.17 3618.77 0.34 5559.13 77.76 77.69 3063.29 2218.93 730.45 3709.95 1.72 5654.54 77.67 77.52 3083.59 2275.28 750.46 3801.01 0.20 5750.17 78.03 76.75 3103.25 2317.78 753.11 3896.63 1.57 5845.60 77.07 77.46 3123.82 2374.75 773.91 3987.47 1.24 5942.37 77.02 76.97 3145.51 2432.27 794.78 4079.43 0.50 6038.13 77.13 77.15 3166.93 2489.39 815.68 4170.40 0.22 6133.92 77.25 76.40 3188.17 2546.92 837.05 4261.33 0.77 6233.48 73.49 72.93 3213.32 2608.96 862.49 4354.20 5.06 6239.00 73.28 72.90 3214.90 2612.50 864.05 4359.26 _3.89 6328.25 69.84 72.35 3243.13 2669.32 889.32 4440.05 3.89 6425.08 71.06 69.27 3275.54 2732.69 919.32 4526.21 3.25 6520.86 69.79 63.90 3307.65 2799.93 955.15 4608.99 5.45 6616.77 69.85 62.46 3340.74 2870.49 995.77 4689.33 1.41 6712.20 70.03 60.92 3373.47 2942.18 1038.28 4768.24 1.53 6807.74 68.96 56.00 3406.95 3016.62 1085.06 4844.49 4.95 6903.49 72.38 51.66 3438.66 3095.60 1138.39 4917.37 5.57 49 CANRIG Oft Eni Petroleum ieni OP05-06, PB1 and PB2 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+),S(-) E(+),W(-) (°/100ft) 7190.09 75.15 40.41 3517.86 3352.90 1331.24 5113.44 3.58 7282.13 75.12 35.12 3541.48 3439.56 1401.54 5167.90 5.56 7377.53 75.42 31.29 3565.75 3530.81 1478.72 5218.41 3.90 6999.27 73.87 46.59 3466.48 3179.09 1198.35 4986.64 5.30 7095.12 74.26 43.81 3492.80 3265.46 1263.29 5052.03 2.82 7190.09 75.15 40.41 3517.86 3352.90 1331.24 5113.44 3.58 7282.13 75.12 35.12 3541.48 3439.56 1401.54 5167.90 5.56 _ 7377.53 75.42 31.29 3565.75 3530.81 1478.72 5218.41 3.90 7573.99 74.62 21.89 3615.06 3720.69 1648.91 5302.79 4.39 7668.37 75.62 17.04 3639.31 3811.48 1734.88 5333.17 5.08 7764.85 78.26 11.94 3661.12 3903.90 1825.84 5356.65 5.83 7859.15 77.82 6.81 3680.67 3992.80 1916.83 5371.67 5.34 7956.48 76.94 3.09 3701.95 4082.13 2011.44 5379.87 3.84 _8051.57 76.09 359.12 3724.13 4166.79 2103.87 5381.66 4.16 8147.84 77.17 1.20 3746.39 4251.92 2197.52 5381.93 2.38 8243.63 76.89 0.98 3767.89 4337.39 2290.85 5383.70 0.37 8339.37 78.18 1.11 3788.56 4422.95 2384.31 5385.41 1.35 8434.60 79.63 0.39 3806.88 4508.29 2477.75 5386.63 1.69 _ 8531.87 82.08 0.64 3822.34 4595.82 2573.77 5387.49 2.53 _ 8618.26 87.28 0.20 3830.35 4674.13 2659.76 5388.12 6.04 8730.86 92.08 2.22 3830.98 4777.29 2772.30 5390.50 4.62 8765.38 91.82 1.90 3829.80 4809.11 2806.77 5391.74 1.19 8860.82 89.01 0.96 3829.11 4896.71 2902.17 5394.12 3.10 8957.45 87.34 359.18 3832.19 4984.44 2998.74 5394.24 2.53 9052.99 87.05 356.98 3836.86 5069.67 3094.11 5391.04 2.32 9148.64 87.41 357.54 3841.49 5154.39 3189.54 5386.48 0.70 _ 9243.85 88.38 359.92 3844.98 5239.85 3284.65 5384.37 2.70 9339.58 86.78 359.15 3849.03 5326.35 3380.29 5383.59 1.85 9435.11 87.11 359.21 3854.12 5412.37 3475.67 5382.23 0.35 9529.30 88.49 1.02 3857.73 5497.88 3569.79 5382.42 2.42 9626.52 90.14 1.90 3858.90 5587.14 3666.97 5384.89 1.92 9721.98 90.36 2.52 3858.48 5675.28 3762.35 5388.58 0.69 _ 9817.20 90.39 2.42 3857.86 5763.36 3857.48 5392.68 0.11 9913.80 91.53 3.06 3856.24 5852.88 3953.96 5397.30 1.35 _10008.82 92.04 0.77 3853.28 5940.38 4048.87 5400.47 2.47 10106.08 92.56 0.17 3849.37 6028.93 4146.05 5401.27 0.82 50 CANRIG itik ,eni Eni Petroleum OP05-06, PB1 and PB2 Surveys(continued Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+),S(-) E(+),W(-) 0100ft) 10200.55 92.40 0.48 3845.29 6114.84 4240.43 5401.80 0.37 10297.08 91.70 358.69 3841.83 6202.11 4336.89 5401.10 1.99 10390.84 91.64 358.66 3839.10 6286.26 4430.58 5398.94 0.07 10488.29 93.19 359.83 3834.99 6374.10 4527.93 5397.62 1.99 10584.57 92.64 357.92 3830.10 6460.58 4624.07 5395.76 2.06 10681.22 89.90 355.37 3827.95 6545.76 4720.51 5390.11 3.87 10776.31 90.02 354.33 3828.02 6628.16 4815.22 5381.57 1.10 10390.84 91.64 358.66 3839.10 6286.26 4430.58 5398.94 0.07 10488.29 93.19 359.83 3834.99 6374.10 4527.93 5397.62 1.99 10584.57 92.64 357.92 3830.10 6460.58 4624.07 5395.76 2.06 10681.22 89.90 355.37 3827.95 6545.76 4720.51 5390.11 3.87 10776.31 90.02 354.33 3828.02 6628.16 4815.22 5381.57 1.10 10871.26 90.05 353.66 3827.96 6709.71 4909.64 5371.64 0.71 10967.26 89.88 352.76 3828.02 6791.49 5004.97 5360.29 0.95 11062.69 89.11 351.50 3828.86 6871.83 5099.49 5347.22 1.55 11158.65 88.22 350.38 3831.10 6951.49 5194.23 5332.12 1.49 11254.64 88.74 349.05 3833.64 7030.02 5288.64 5314.99 1.49 11350.36 89.88 348.93 3834.80 7107.64 5382.59 5296.71 1.20 11446.26 89.84 349.35 3835.03 7185.57 5476.77 5278.64 0.44 11542.24 89.16 350.98 3835.87 7264.54 5571.33 5262.25 1.84 11637.39 87.46 351.36 3838.68 7343.73 5665.31 5247.65 1.83 11733.92 85.67 352.87 3844.46 7424.83 5760.75 5234.43 2.42 11828.78 86.93 355.31 3850.58 7506.21 5854.90 5224.68 2.89 11925.86 87.04 355.42 3855.69 7590.65 5951.53 5216.85 0.16 12019.61 86.93 355.03 3860.62 7672.08 6044.82 5209.06 0.43 12116.73 86.15 352.43 3866.48 7755.11 6141.18 5198.47 2.79 12210.69 86.61 351.84 3872.41 7834.06 6234.07 5185.64 0.80 12303.95 86.04 351.73 3878.39 7912.10 6326.18 5172.34 0.62 12401.23 86.98 353.59 3884.31 7994.32 6422.48 5159.94 2.14 12495.95 87.94 357.13 3888.51 8076.72 6516.78 5152.28 3.87 12592.20 89.04 358.06 3891.05 8162.30 6612.91 5148.25 1.50 12687.62 88.38 357.30 3893.20 8247.21 6708.23 5144.39 1.05 12783.53 87.73 358.28 3896.45 8332.61 6804.01 5140.69 1.23 12879.99 86.90 356.67 3900.97 8418.21 6900.27 5136.44 1.88 12976.36 88.78 356.74 3904.60 8503.17 6996.40 5130.91 1.95 13070.15 89.74 356.75 3905.81 8585.93 7090.03 5125.59 1.02 13166.37 89.85 357.66 3906.16 8671.21 7186.14 5120.89 0.95 13262.14 _ 91.13 358.06 3905.34 8756.59 7281.83 5117.32 1.40 51 CANRIG Ilifi ,eni Eni Petroleum OP05-06, PB1 and PB2 Surveys(continued Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+),S(-) E(+),W(-) (°/100ft) 13358.11 91.67 357.43 3903.00 8842.03 7377.70 5113.54 0.86 13453.44 93.01 357.64 3899.10 8926.70 7472.86 5109.45 1.42 13549.15 92.63 359.05 3894.39 9012.29 7568.41 5106.69 1.52 13646.19 89.81 359.09 3892.33 9099.69 7665.41 5105.11 2.91 13741.66 86.61 358.87 3895.31 9185.58 7760.80 5103.41 3.36 13836.64 87.47 0.44 3900.21 9271.44 7855.65 5102.84 1.88 13932.84 88.59 3.11 3903.52 9359.92 7951.74 5105.82 3.01 14028.70 87.65 1.42 3906.67 9448.41 8047.47 5109.61 2.02 14124.08 88.19 359.35 3910.13 9535.20 8142.78 5110.25 2.24 14219.86 87.88 359.68 3913.41 9621.76 8238.50 5109.44 0.47 14316.16 87.44 359.08 3917.35 9708.67 8334.71 5108.40 0.77 14412.06 86.67 0.08 3922.27 9795.32 8430.48 5107.69 1.31 14508.05 87.02 1.46 3927.53 9882.86 8526.31 5108.98 1.49 14603.67 85.96 2.36 3933.06 9970.68 8621.66 5112.16 1.45 14698.62 86.85 359.56 3939.02 10057.35 8716.4 5113.75 3.09 14794.37 87.87 357.81 3943.43 10143.24 8812.02 5111.55 2.11 14889.62 89.66 358.45 3945.48 10228.34 8907.19 5108.45 2 14985.53 88.81 359.45 3946.76 10314.65 9003.08 5106.69 1.37 15081.37 86.6 358.71 3950.6 10400.93 9098.82 5105.15 2.43 15176.53 85.6 359.03 3957.07 10486.32 9193.74 5103.28 1.1 15272.42 87.96 0.79 3962.46 10573.16 9289.47 5103.13 3.07 15369.07 85.86 0.44 3967.67 10661.2 9385.97 5104.17 2.2 15466.29 87.18 0.27 3973.57 10749.55 9483 5104.77 1.37 15560.83 85.72 0.33 3979.42 10835.41 9577.36 5105.26 1.55 15656.73 86.62 0.77 3985.83 10922.66 9673.04 5106.18 1.04 15750.97 88.94 1.95 3989.48 11009.06 9767.17 5108.42 2.76 15846.65 87.61 2.14 3992.36 11097.26 9862.75 5111.83 1.4 15943.73 89.22 2.47 3995.04 11186.92 9959.71 5115.73 1.69 16039.08 89.75 3.16 3995.9 11275.34 10054.94 5120.42 0.91 16136.28 91.45 4.68 3994.88 11366.15 10151.9 5127.06 2.35 16230.52 90.98 2.37 3992.88 11453.95 10245.93 5132.85 2.5 16325.44 89 0.42 3992.9 11541.06 10340.81 5135.16 2.93 16420.93 88.63 359.19 3994.87 11627.59 10436.28 5134.84 1.34 16517.24 89.46 0.12 3996.48 11714.77 10532.57 5134.26 1.29 16612.85 88.92 0.27 3997.83 11801.69 10628.17 5134.58 0.59 16708.98 87.24 359.33 4001.05 11888.77 10724.24 5134.25 2 16804.73 89.89 0.43 4003.45 11975.58 10819.95 5134.05 3 16900.82 92.07 0.7 4001.81 12063.19 10916.02 5135 2.29 16970.55 94.01 1.59 3998.11 12126.97 10985.63 5136.39 3.06 52 CANRIG ,eni Eel Petroleum OP05-06, PB1 and PB2 5.2.2 PB1 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 6230.38 76.07 75.91 3210.43 859.5 859.5 4352.46 1.32 6326.48 76.22 74.24 3233.44 883.53 883.53 4442.61 1.69 6423.65 75.1 72.28 3257.51 910.64 910.64 4532.76 2.27 6519.47 74.57 71.94 3282.58 939.05 939.05 4620.77 0.65 6614.72 74.66 72.01 3307.85 967.47 967.47 4708.1 0.12 6709.49 73.17 72.02 3334.1 995.58 995.58 4794.71 1.57 6742.26 73.26 72.31 3343.57 1005.19 1005.19 4824.58 0.89 6806.98 74.01 70.91 3361.8 1024.79 1024.79 4883.5 2.38 6902.84 73.99 70.62 3388.22 1055.14 1055.14 4970.5 0.3 6935.73 74.09 69.9 3397.27 1065.83 1065.83 5000.27 2.11 6967.36 74.47 69.45 3405.84 1076.4 1076.4 5028.82 1.82 5.2.3 PB2 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 14603.21 88.37 2.56 3931.33 9970.52 8621.34 5112.32 1.81 14698.13 .... 87.14 2.80 3935.05 10058.39 8716.08 5116.75 1.32 14794.14 85.84 2.69 3940.93 10147.21 8811.79 5121.34 1.36 14889.52 85.32 3.03 3948.28 10235.42 8906.77 5126.09 0.65 14985.16 _ 85.67 3.84 3955.79 10324.21 9001.94 5131.80 0.92 15081.54 85.08 2.85 3_963.56 10413.62 9097.85 5137.40 1.19 15177.42 87.01 0.44 3970.18 10501.56 9193.45 5140.15 3.22 15273.44 85.55 358.87 3976.41 10588.30 9289.26 5139.57 2.23 15369.45 82.63 357.91 3986.29 10673.83 9384.71 5136.89 3.20 53 CANRIG v Ln 1 u Q I W p U p " Qp Q m N I- cS F-° in V Z, Z , Z O N ' O c + Q O T O 05 d " c) O 0 L() < r N I` O r N T ,- T T T N T Lo Ln T L. N 2 N v 1.0 `o two d d LC) C) a) a) CO Ls-) co N- N- LL N Nr T N O) CI w ' O Ln co N- co d ,- d- cc N co 0 = N CO O CC) N a Q = O C\ M cc tri- m LL X N X 4 � cc X M � cc A N T � Mrs � � Mlc '4 E. In, VJ O `� COT c>or 0 X O co N T 1.. N O _ d C") M 13 ' T Eg co IV to co co o 8= 4 7 O N N N Z co O� N 1 N CO LI- i in I- NX U) rn NJ N U) 2 1 0 >, -0C) - _CC D 0 C 0 CC D o 0 CO X 0 aC 0 21- = 2 = 0 = tea = 2 = tea 2 cc O 0 N N N N 'r. CO N N N co T T T T I CU m 3 7 T N M Ln 3 Z G' m m m m m y _ ) z z z z z Z m a II II II o Z m m c) d Ce m M 6 LID U3 ' 0 0 0 " 0 0 0 0 0 0 0 0 0 0 0 0 + N CO CO CO CO CO CO U nr nr co M N N N :=' CO 7- co C.) = a) a O E ' O 0 0 ' ' 000000000000 CD a) , O O Ul 00000 (t) O00Cn00 ca ~ CO N r Cn O r r r O 7- 7- r 0 0 0 m 7 0 0 U N r r ("LO L- e_ L ' O ' O N ti CO M CO a0 O O) I- O U O a O 2 00 rn ad aoO) O) O) aornrnrnornrnrnrn a) a) a r cr II )5 O H C _ J ' d' CO CO ' ' C() N N U) N — CC) U) 00 CC) K) I� W O O LI_ H N N . r M r r (Ni r r ti r I` r Z•ci T- r T- r r 0 LL II wz O ' (- M O ' ' (00 N N CM M 0) 0) 0) 0) O) O 0 O) O) O) C) O) CA O) C)) O M M M co 8 co 8 M M 8 M M ' r Cf) N ' ' U) r N Cn I I E o O r ° O O O r 0 0 0 0 0 0 2 O O O •U u) C N U) ' O O O ' ' CC) O O U) 0 0 0 U) to O O O Ia) O 0 Oe M I� O 4 I` Cn LO Cn ui O O co O CO CO N N 3 a) a) N N m O "a co d J ' N N ' ' N CO O) CO I- 0 CO O O N O N C _ 73 W I` O Co (n (n i (n Cn (n (n (n (n Cn a) 2 co = T}, O II lc° = C 70 ' O) N- co) N N CO r N O) U) U) r N CO co 0 O O L U CO M M N M N N N N co N N t Il Co J 8 N 4 r CO LO co O O O O N II 0 CO W M M M T- N N r — co N co N N T- 8 co M Cr) co Cr) O a0 00 N co N O N- H II II _ 0 M N N r i e O U It i- V a a N O O) r N O r N- O) CA CO r M U) N-O >. co N O N N N N r r N N cc) N N r N N N > , O N M M M M N C) O N CO LO CO LO CO N 0 N- 0 Z v CO 73 J �' N s N In N O) CO r , , I , I , I , co lam(') Co = f/) N r a) N II N C O N N O O O J "a N I 00 O M Co LC l) O N r r O r N N V- N N r 0 -a p 0 p 2 Q w co O) O) co a) O) d) O) O) O) O) 0) 0) O) O) O) O) U 3 (n AII II '13 73 0 Cn O) CO CO CO O) + 0 0 1- 0 V- N CO O) O) 0) Q) = Q CO O N O) O) O) O r CO CO N N O N M M M M O LJL U) 17 r co — — — — co N M M CO co co co co CO i .a N N N N N M M C`') CO) CD) M C') C') Cc) (c) C') C a X I—. O CO (- LO LO U) CO O CO CO CO CO N 0- CO O CO CO N W Cfl O r N N N CO U) 0- 0- M r O CO CO 00 CO 0 r CO co V' nr co N CO CO O CO CO N• CO CO CO CO 3 0 N N N N Co CO O N- CO N- CO CO CO CO CO T a)t) N N •y 't 2 t o o co C.) O O O O O O O O O O O O O O O O O O .or) N C• W 0 0 0 0 O 0 O O O O O O O 0 O O 0 O o > m Oa N N N N N N N N N N N N N N N N N N ~ �+ C ..7-7 i Q r N CO M) CO I- 00 07 O r N M nr M) CO (- co 3 C O N N N N N N N N N = 00 Cl.) V � a) CO CO CO CO CO CO 00 00 OO CA OO CO OO O CO 00 CO 00 y l,_ d I>I II II II 12 > CO > Cl_ = Q 2 > n- >- Tr K) co LID O r O C'') c0 CO r r >, O . 1 . r N N E CO CV 0 0 0 0 0 j W a ai 0 0 .- r .- .- ooiaiaiaiaioiciaiaiai c a) a - - . , 0 E a) a) W .0 N CO U) a) CO U) N- CO M CO M M M M M CY) C.,) C'�) c "a 1— M .0 1 U7 CO a) U) O M r M CO CO'CO CO CO 'Cr 1' - " 5 O N J k 00t- rrrr Mrrrrrrrrrr = � mc i Cn i J ... 0 O O O 0 0000000',00000000 0 o a) o _ 0 0 0 0 0000000000000000 a) a) CaL U co 0 0 0 oo �n � 000000000000 Lo 7 re; v ;Tr v ,171. v i Lo U) U) U) to U n i in U . < II o . c =' J W o0u_ O ) N ) II J i CO UO O N N N N N r r r r r LL Q d Q O r • r r c; (NJ r r r r• r W Z O • - N- r N r a) CO O a) 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N N N r N U) U) U) U) U) U) U) U) U) U) U) Fr)._ —R N-CO N-a N-r rN- 0 C 0 co 0 0 0 0 0 0 0 U) 0 0 0 0 U) 0 E a a o 0 as C v 0 Ui O Ui O CO CO CO CO x 0 0 0 0 0 0 0 0 0 0 a) c N m O "a m - a J CO 0 0 0 0 0 c >+ I = LL M T= N II CO , L N 7 + N CO M O CO r CO O L O U N IX 0 co N - N M N M N U) U) U) M M - 0_ 0 d J CCO CO O r O O co M co M M M M co M M M W r r N N N N N II II O 0 � N M © � i co CO M M M M Cr) N N N N N m i..-: 'ci o- . . c U ci- O O. O N Cfl U) M 0 r- 0 co CO CO N- ti r- ti CO r- CO CO r- .- r r r N r N r +-' C a) > r O Co Co N- 0 CO r- CO N 1r 1 1r r 0 0 0 O o a N N N N N M N N N N N N N N N N N N N N o 1.0 C) M - - . . -a 0 r- co a _ CO N M a) 0 r� CO 0 ti O) r i i i i i i i i CO O > v a) N- CO a) co a) co c co II _ _ rn c CO O c00o ? la CD CO r- co r` CO CO r- CO O) O co co O O a) o co 2 a co co co co 03 co co co co Cb CM 0) ai C3) ai ai ai ai ai of �? '= cn 2 a II a) O Oaa 0 CM M aM) a M O U) O N a) N) aN) N N a) N) N) )N N) N) aN) a)N 0 CO 0) co co co co co 0) CA 0) a) Cr) 0) 0) O a) 0) 0) 0) 0) a) a) ` M M C') V) V) M CY) M CY) Cam) M V) CY) M M M C") V1 M C',) H C V O O. 4 r M M CO U) U) U U) U) U) U) U) U) U) U U) O W Q co 2 2 O r co r co co co co co co co co co co co M w r - Co Co ' = 0 0 0 0 0 0 0 0 0 0 0 0 0 co 03 co r M U) CD r- r- N- r- N- r- r- N- r- N- N- r ,N CO u) CL 0 0 0 0 0 00000000000000 0 N > > 'o c W 0 0 0 0 0 000000000000000 0 a) � d ~ N N N N N N N N N N N N N N N N N N N N 'ar a ., ,,- a) 0 = — N U, U, N— CO a) 0 N U) U, N co = C (c O •• a) O r r N M 0 8 0 r` 0 8 O r N M t- CO a as a) ✓ N M M O O O O O O O O O r r r r r r r r > u_ ii 57 co CO CO a) a) a7 a) a) O O a) O a) O a) a) a) a) a) a) i II II II II 10 id ieni Eni Petroleum OP05-06, PB1 and PB2 6 DAILY REPORTS 57 CANRIG Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT Ell OP05-06 REPORT FOR S.Beauchamp/S.Bowe/A.Buchanan DATE Aug 11,2010 DEPTH 160 PRESENT OPERATION Spud TIME 24:00:00 YESTERDAY 160 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA NA NA NA NA 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 NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 160' MW 8.8 VIS - PV - YP - FL - Gels - CL- - FC - SOL - SD - OIL - MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 0 CUTTING GAS NA @ NA @ NA WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH 0 ETHANE(C-2) NA @ NA @ NA AVG 0 PROPANE(C-3) NA @ NA @ NA CURRENT 0 BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0 PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY Complete rig move.Rig up for surface hole.Complete picking up 5"drill pipe and BHA#1.Spud meeting as of midnight. EPOCH PERSONNEL ON BOARD 2 DAILY COST DML-$2245;RigWatch -$1450 REPORT BY Z.Beekman file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\20100812.h... 8/12/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH VHNikaitchuq DAILY WELLSITE REPORT OP05-06 REPORT FOR S.Beauchamp/D.Smith/A.Buchanan DATE Aug 20,2010 DEPTH 6944' PRESENT OPERATION Drilling TIME 24:00:00 YESTERDAY 6878' 24 HOUR FOOTAGE 66' CASING INFORMATION 20"@ 160' 13 3/B"@ 2415' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6902.84 73.99 70.62 3388.22 SURVEY DATA 6806.98 74.01 70.91 3361.80 6742.31 7325 71.44 3343.78 6709.49 73.16 71.28 3334.30 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 121/4" Hycalog MSF619M 225748 6x16 6878' - 66' 3 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 119.1 @ 6933.00000 24.0 @ 6920.00000 91.4 5642067 FT/HR SURFACE TORQUE 12589 @ 6913.00000 9530 @ 6894.00000 10450.5 10768.47363 AMPS WEIGHT ON BIT 26 @ 6878.00000 0 @ 6891.00000 4.9 7.58343 KLBS ROTARY RPM 102 @ 6902.00000 79 @ 6914.00000 99.4 100.14041 RPM PUMP PRESSURE 1781 @ 6930.00000 9 @ 6878.00000 1750.4 1753.85339 PSI DRILLING MUD REPORT DEPTH 6944' MW 9.1 VIS - PV 15 YP 21 FL 4.6 Gels 10/25/29 CL- 1100 FC 1/- SOL 5.5 SD 0.15 OIL 3/92 MBL 12.5 pH 8.8 Ca+ 60 CCI - MWD SUMMARY INTERVAL 2425'TO 6944' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 16 @ 6900.00000 0 @ 6944.00000 5,0 TRIP GAS 72 CUTTING GAS 0 @ 6944.00000 0 @ 6944.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 5787 @ 6900.00000 158 @ 6888.00000 1430.8 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 6944.00000 0 @ 6944.00000 0.0 AVG 0 PROPANE(C-3) 0 @ 6944.00000 0 @ 6944.00000 0.0 CURRENT 0 BUTANE(C-4) 0 @ 6944.00000 0 @ 6944.00000 0.0 CURRENT BACKGROUND/AVG 0/16 PENTANE(C-5) 0 @ 6944.00000 0 @ 6944.00000 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY Circulate hole clean at surface casing shoe.Pulled out of hole and laid down directional assembly.Pick up back up directional tools and run in hole.Shallow test MWD tools.Run in hole to SUMMARY 6876'md and circulate.Drill 6878'-6894'md.Troubleshoot tools.Drill ahead to 6944'md as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;Rig Watch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/21/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT El OP05-06 REPORT FOR S.Beauchamp/D.Smith/A.Buchanan DATE Aug 21,2010 DEPTH 7036' PRESENT OPERATION Kickoff for sidetrack TIME 24:0040 YESTERDAY 6944' 24 HOUR FOOTAGE 92' CASING INFORMATION 20"@ 160' 13 3/8"@ 2415' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6902.84 73.99 70.62 3388.22 SURVEY DATA 6806.98 74.01 70.91 3361.80 6742.31 73.25 71.44 3343.78 6709.49 73.16 71.28 3334.30 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12 1/4" Hycalog MSF619M 225748 6x16 6878' 7036' 158' 5.5 - Sidetrack DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 327.7 @ 6989.00000 11.8 @ 6980.00000 124.8 12484646 FT/HR SURFACE TORQUE 12819 @ 6969.00000 9228 @ 6994.00000 11144.4 11424.51465 AMPS WEIGHT ON BIT 20 @ 6981.00000 0 @ 6986.00000 9.1 12431374 KLBS ROTARY RPM 120 @ 7030.00000 58 @ 6972.00000 103.2 120.11667 RPM PUMP PRESSURE 1816 @ 6982.00000 1707 @ 7034.00000 1775.1 1724.69983 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 2425'TO 7036' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 7 @ 7001.00000 0 @ 6976.00000 3.2 TRIP GAS 16 CUTTING GAS 0 @ 7036.00000 0 @ 7036.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 1284 @ 7001.00000 41 @ 6976.00000 563.6 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 7036.00000 0 @ 7036.00000 0.0 AVG 0 PROPANE(C-3) 0 @ 7036.00000 0 @ 7036.00000 0.0 CURRENT 0 BUTANE(C-4) 0 @ 7036.00000 0 @ 7036.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 7036.00000 0 @ 7036.00000 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY Drilled ahead to 7036'md.Could not get the desired turn rate.Decision was made to pull out and pick up mud motor.Run in hole to sidetrack at about 6250'md.Run in hole to depth of SUMMARY 4500'md as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch -$1450 REPORT BY Z.Beekman file://C:\Documents and Settings\EpochAdmin\Desktop\ENI OP05-06 PB 1\20100821.htm 8/22/2010 Daily Report Page 1 of 1 ENI Petroleum n EPOCH VHNikaitchuq DAILY WELLSITE REPORT 0P05-06 REPORT FOR J.Keener/D.Smith/A.Buchanan DATE Aug 22,2010 DEPTH 6846' PRESENT OPERATION Drilling TIME 24:00:00 YESTERDAY 6207' 24 HOUR FOOTAGE 639' CASING INFORMATION 20"@ 160' 13 3/8"@ 2415' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6807.74 68.93 57.96 3407.2 SURVEY DATA 6712.2 69.98 62.89 3373.66 6616.77 69.81 64.65 3340.85 6520.86 69.75 6622 3307.7 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12 1/4" Hughes MX-1L 5171601 1520,3518 6207' - 639' 22 - 3 121/4" Hycalog MSF619M 225748 6x16 6878' 7036' 158' 5.5 0-0-WT-A Tool Failure DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 335.6 @ 6454.00000 1.6 @ 6245.00000 122.3 65.53865 FT/HR SURFACE TORQUE 11040 @ 6817.00000 1245 @ 6340.00000 2588.8 0.00000 AMPS WEIGHT ON BIT 25 @ 6816.00000 0 @ 6627.00000 8.4 11.79532 KLBS ROTARY RPM 125 @ 6209,00000 0 @ 6504.00000 16.4 0.00000 RPM PUMP PRESSURE 2191 @ 6235.00000 1111 @ 6406.00000 1512.0 1592.53149 PSI DRILLING MUD REPORT DEPTH 6846' MW 9.1 VIS - PV 12 YP 19 FL 5.0 Gels 8/19/25 CL- 1050 FC 1/- SOL 5.0 SD 0.1 OIL 6/93 MBL 11 pH 9.8 Ca+ 40 CCI - MWD SUMMARY INTERVAL 2425'TO 6846' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 415 @ 6238.00000 0 @ 6840.00000 38.1 TRIP GAS 0 CUTTING GAS 0 @ 6846.00000 0 @ 6846.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 93558 @ 6238.00000 98 @ 6840.00000 8533.0 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 6846.00000 0 @ 6846.00000 0.0 AVG 0 PROPANE(C-3) 0 @ 6846.00000 0 @ 6846.00000 0.0 CURRENT 0 BUTANE(C-4) 0 @ 6846.00000 0 @ 6846.00000 0.0 CURRENT BACKGROUND/AVG 16/10 PENTANE(C-5) 0 0 6846.00000 0 0 6846.00000 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY SUMMARY Run in hole.Build trough from 6207'to 6239'md.Perform open hole sidetrack at 6239'md.Time drill and drill to 6846'md as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/23/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT El OP05-06 REPORT FOR J.Keener/D.Smith/A.Buchanan DATE Aug 23,2010 DEPTH 7612' PRESENT OPERATION Drilling TIME 24:00:00 YESTERDAY 6846' 24 HOUR FOOTAGE 766' CASING INFORMATION 20"@ 160' 13 3/8"@ 2415' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7573.99 74.57 21.87 3615.46 SURVEY DATA 7476.51 75.87 2655 3590.58 7377.53 75.38 31.98 3565.98 7282.13 75.08 35.77 3541.65 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 121/4" Hughes MX-1L 5171601 1020,3018 6207' - 1405' 35 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1081.6 @ 7367.00000 65.0 @ 6882.00000 169.2 136.56187 FT/HR SURFACE TORQUE 11342 @ 751350000 964 @ 6947.00000 2233.8 050000 AMPS WEIGHT ON BIT 38 @ 7557.00000 0 @ 7462.00000 17.6 1.14105 KLBS ROTARY RPM 54 @ 7212.00000 0 @ 7057.00000 9.5 0.00000 RPM PUMP PRESSURE 2314 @ 7596.00000 1521 @ 6860.00000 1931.3 2079.73853 PSI DRILLING MUD REPORT DEPTH 7612' MW 9.2 VIS 66 PV 18 YP 29 FL 4.6 Gels 12/30/41 CL- 1100 FC 2/- SOL 6.0 SD 0.1 OIL 3/91 MBL 14.5 pH 9.8 Ca+ 40 CCI - MWD SUMMARY INTERVAL 2425'TO 7612' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 517 @ 7232.00000 0 @ 6847.00000 99.4 TRIP GAS 0 CUTTING GAS 0 @ 7612.00000 0 @ 761250000 0.0 WIPER GAS 24 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 87245 @ 7232.00000 101 @ 6847.00000 18475.6 CONNECTION GAS HIGH 0 ETHANE(C-2) 966 @ 7232.00000 0 @ 6893.00000 165.3 AVG 0 PROPANE(C-3) 639 @ 7232.00000 0 @ 6893.00000 83.8 CURRENT 0 BUTANE(C-4) 798 @ 7232.00000 0 @ 6893.00000 121.6 CURRENT BACKGROUND/AVG 12/75 PENTANE(C-5) 6217 @ 7232.00000 0 @ 6970.00000 467.6 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 90%,Sandstone 10% DAILY ACTIVITY Drilled ahead from 6846'to 7164'.Had electrical problem in early AM but got worked out.Continued drilling to 7260'md.Run short trip back reaming to 5820'md.Run in hole from 5820'to SUMMARY 7260'md.Continue drilling and sliding from 7260'to 7612'md as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;Rig Watch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/24/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT HI OP05-06 REPORT FOR J.Keener/D.Smith/A.Buchanan DATE Aug 24,2010 DEPTH 8407' PRESENT OPERATION Drilling TIME 24:00:00 YESTERDAY 7612' 24 HOUR FOOTAGE 795' CASING INFORMATION 20"@ 160' 13 3/8"@ 2415' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8243.63 76.84 359.94 3768.12 SURVEY DATA 8147.84 77.13 359.96 3746.55 8051.57 76.04 357.29 3724.21 7956.48 76.94 2.56 3701.99 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12 1/4" Hughes MS-1L 5171601 1020,3x18 6207' - 2200' 45 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 829.6 @ 7743.00000 22.7 @ 7746.00000 142.4 65.60715 FT/HR SURFACE TORQUE 19225 @ 7633.00000 391 @ 8122.00000 5994.1 13482.85742 AMPS WEIGHT ON BIT 31 @ 7632.00000 0 @ 7804.00000 17.3 19.63668 KLBS ROTARY RPM 85 @ 8192.00000 1 @ 7717.00000 27.5 47.43965 RPM PUMP PRESSURE 2447 @ 8309.00000 32 @ 8122.00000 2238.0 2289.21680 PSI DRILLING MUD REPORT DEPTH 8407' MW 9.2 VIS 59 PV 15 YP 28 FL 5.0 Gels 13/26/42 CL- 1100 FC 2/- SOL 6.5 SD 0.1 OIL 3/91 MBL 17.5 pH 10.0 Ca+ 30 CCI - MWD SUMMARY INTERVAL 2425'TO 8407' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 782 @ 7906.00000 0 @ 7797.00000 172.6 TRIP GAS 0 CUTTING GAS 0 @ 8407.00000 0 @ 8407.00000 0.0 WIPER GAS 47 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 145834 @ 7906.00000 119 @ 7797.00000 31118.3 CONNECTION GAS HIGH 0 ETHANE(C-2) 1854 @ 7907.00000 1 @ 7797.00000 350.6 AVG 0 PROPANE(C-3) 1025 @ 7907.00000 0 @ 7797.00000 197.0 CURRENT 0 BUTANE(C-4) 1671 @ 7907.00000 1 @ 7797.00000 377.4 CURRENT BACKGROUND/AVG 40/100 PENTANE(C-5) 986 @ 7927.00000 0 @ 7797.00000 270.9 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Siltstone,Conglomeratic Sand PRESENT LITHOLOGY Sand 60%,Siltstone 30%,Conglomeratic Sand 10% DAILY ACTIVITY Continued drilling ahead from 7612'to 8217'md.Back reamed from 8217'to 7260'.Run in hole to 8217'to pump sweep.Continued drilling to 8407'md.Top drive being serviced as of SUMMARY report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/25/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT El OP05-06 REPORT FOR J.Keener/D.Smith/A.Buchanan DATE Aug 25,2010 DEPTH 8686' PRESENT OPERATION Back Reaming TIME 24:00:00 YESTERDAY 8407' 24 HOUR FOOTAGE 279' CASING INFORMATION 20"@ 160' 13 3/8"@ 2415' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8686.00 89.50 0.20 383225 SURVEY DATA 8618.26 87.28 0.20 3830.35 8531.87 82.08 0.64 3822.34 8434.60 79.63 0.39 3806.88 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12 1/4" Hughes MX-1L 5171601 1020,3518 6207' 8686' 2479' 52 - TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 410.8 @ 8409.00000 56.0 @ 8462.00000 165.0 141.71500 FT/HR SURFACE TORQUE 13482 @ 8407.00000 4669 @ 8537.00000 30862 0.00000 AMPS WEIGHT ON BIT 45 @ 8408.00000 0 @ 8409.00000 14.8 18.91600 KLBS ROTARY RPM 49 @ 8459.00000 1 @ 8588.00000 12.2 0.00000 RPM PUMP PRESSURE 2475 @ 8429.00000 1256 0 8408.00000 2350.3 2335.61400 PSI DRILLING MUD REPORT DEPTH 8686' MW 9.4 VIS 66 PV 16 YP 31 FL 5.0 Gels 14/38/48 CL- 1100 FC 2/- SOL 6.5 SD 0.1 OIL 3/91 MBL 18 pH 9.9 Ca+ 30 CCI - MWD SUMMARY INTERVAL 2425'TO 8686' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 1368 @ 8571.00000 28 @ 8412.00000 554.0 TRIP GAS- CUTTING GAS 0 @ 8686.00000 0 @ 8686.00000 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 254319 @ 8570.00000 5285 @ 8412.00000 90382.9 CONNECTION GAS HIGH 20 ETHANE(C-2) 4995 @ 8570.00000 32 @ 8412.00000 1243.2 AVG 20 PROPANE(C-3) 1141 @ 8570.00000 13 @ 8412.00000 290.7 CURRENT 0 BUTANE(C-4) 1933 @ 8570.00000 34 @ 8412.00000 513.6 CURRENT BACKGROUND/AVG 0/- PENTANE(C-5) 955 @ 8570.00000 37 @ 8412.00000 266.8 HYDROCARBON 1 7190'-7260';2.7895'-7962';3.8427'-8686' SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 1.7195-7260';2. 1.Sand/Sandstone 2. 1.517 1.medium light gray sand with pronounced brownish secondary hue;friable;moderately well to well sorted;medium lower to medium upper and coarse 7895'-7962';3. Sand/Conglomeratic Sand 2.782 lower;translucent white to colorless quartz;100%to 30%brown oil stain;100 to 40%medium yellow sample fluorescence;fast streaming cut to milky 8427'-8686' 3.Sand/Sandstone 3. yellow white.2.medium light gray with slight brownish secondary hue;dis-aggregated;friable;medium upper to lower;well sorted;sub-angular to 1368 angular;20 to 30%dull yellow to dull gold sample fluorescence;fast streaming cut to yellow white;faint brownish residue ring cuts readily to yellow white; slightly to moderately calcareous.3.medium to light medium gray with a definite secondary brownish hue;friable;dis-aggregated;lower fine to upper fine grained;scattered medium lower;well sorted;to moderately well sorted;sub-rounded to sub-angular;high to moderately high sphericity;50 to 60% translucent white quartz;common to abundant clear colorless quartz and medium to light gh ray!Ethics;trace dark gray to black mafic/mineral grains;trace medium to dark gray chert;trace to common glauconite and ghreen stained quartz;trace pyrite and shell fragments;appears to be principally grain supported;no matrix material noted;abundant free oil on wash water and on shale shakers;good oil sheen on wash water;obvious oil odor at shakers; moderate oil odor from samples;90 to 100%medium brown oil stain on samples;100%dull yellow gold sample fluorescence;fast streaming cut to milky yellow white;pronounced brownish residue ring cuts readily to yellow white;moderately calcareous. LITHOLOGY Sand PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY SUMMARY Finished servicing the top drive.Drill ahead from 8407'to 8686'md.Circulate 3 bottoms up.Back ream out of hole from 8686'md to 5345'md as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/26/2010 Daily Report Page 1 of 1 ENI Petroleum a EPOCH Nikaitchug DAILY WELLSITE REPORT OP05-06 REPORT FOR J.Keener/D.Smith/A.Buchanan DATE Aug 26,2010 DEPTH 8686' PRESENT OPERATION POOH TIME 24:00:00 YESTERDAY 8686' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160' 13 3/8"@ 2415' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8686.00 89.50 0.20 3832.25 SURVEY DATA 8618.26 8728 0.20 383035 8531.87 82.08 0.64 3822.34 8434.60 79.63 0.39 3806.88 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 121/4" Hughes MX-1L 5171601 1520,3518 6207' 8686' 2479' 52 - TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA NA @ NA NA NA FT/HR SURFACE TORQUE NA @ NA NA @ NA NA NA AMPS WEIGHT ON BIT NA @ NA NA @ NA NA NA KLBS ROTARY RPM NA @ NA NA @ NA NA NA RPM PUMP PRESSURE NA @ NA NA @ NA NA NA PSI DRILLING MUD REPORT DEPTH 8686' MW 9.2 VIS 56 PV 15 YP 23 FL 5.2 Gels 12/24/33 CL- 1050 FC 2/- SOL 6.0 SD 0.1 OIL 3/91 MBL 17.5 pH 9.7 Ca. 20 CCI - MWD SUMMARY INTERVAL 2425'TO 8686' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA NA @ NA NA TRIP GAS 109 CUTTING GAS NA @ NA NA @ NA NA WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) NA @ NA NA @ NA NA CONNECTION GAS HIGH 0 ETHANE(C-2) NA @ NA NA @ NA NA AVG 0 PROPANE(C-3) NA @ NA NA @ NA NA CURRENT 0 BUTANE(C-4) NA @ NA NA @ NA NA CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) NA @ NA NA @ NA NA HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY Completed back reaming to surface casing shoe.Circulate bottoms up.Cut and slip drill line and service top drive.Run in hole back to bottom.Circulating 3 bottoms up as of report. SUMMARY Max trip gas 109u. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/27/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT OP05-06 REPORT FOR J.Keener/S.Bowe/A.Buchanan DATE Aug 27,2010 DEPTH 8686' PRESENT OPERATION RIH w/9 5/8"Csg TIME 24:00:00 YESTERDAY 8686' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160' 13 3/8"@ 2415' - DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8686.00 89.50 0.20 383225 SURVEY DATA 8618.26 87.28 0.20 3830.35 8531.87 82.08 0.64 382224 8434.60 79.63 0.39 3806.88 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB/C PULLED 4 12 1/4" Hughes MX-1L 5171601 1020,3018 6207' 8686' 2479' 52 2-3-BT-2-E-3-C12 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA NA @ NA NA NA FT/HR SURFACE TORQUE NA @ NA NA @ NA NA NA AMPS WEIGHT ON BIT NA @ NA NA @ NA NA NA KLBS ROTARY RPM NA @ NA NA @ NA NA NA RPM PUMP PRESSURE NA @ NA NA @ NA NA NA PSI DRILLING MUD REPORT DEPTH 8686' MW 9.2 VIS 57 PV 16 YP 25 FL 5.0 Gels 10/22/29 CL- 1000 FC 2/- SOL 6.0 SD - OIL 3/91 MBL 17.5 pH 9.7 Ca, 20 CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA NA @ NA NA TRIP GAS- CUTTING GAS NA @ NA NA @ NA NA WIPER GAS 35 CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA NA @ NA NA CONNECTION GAS HIGH- ETHANE(C-2) NA @ NA NA @ NA NA AVG- PROPANE(C-3) NA @ NA NA @ NA NA CURRENT- BUTANE(C-4) NA @ NA NA @ NA NA CURRENT BACKGROUND/AVG 0/- PENTANE(C-5) NA @ NA NA @ NA NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY Completed circulating hole clean.Pull out of hole from 8686'md to surface.Lay down BHA.Change rams and test.Rig up 9 5/8"casing equipment.Run in hole with 9 5/8"casing to SUMMARY 1871'as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3000;RigWatch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/28/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT Ei OP05-06 REPORT FOR J.Keener/S.Bowe/A.Buchanan DATE Aug 28,2010 DEPTH 8686' PRESENT OPERATION Well Head Work TIME 24:00:00 YESTERDAY 8686' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160'13 3/8"@ 2415' 9 5/8"@ 8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8686.00 89.50 020 383225 SURVEY DATA 8618.26 8728 0.20 3830.35 8531.87 82.08 0.64 3822.34 8434.60 79.63 0.39 3806.88 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12 1/4" Hughes MX-1L 5171601 1020,3x18 6207' 8686' 2479' 52 2-3-BT-2-E-3-Cl2 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 8686 MW 9.1 VIS 48 PV 12 YP 17 FL 5.2 Gels 7/15/20 CL- 1000 FC 2/- SOL 6.0 SD - OIL 3/91 MBL 17 pH 9.0 Ca-I- 20 CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS- CUTTING GAS NA @ NA @ NA WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH - ETHANE(C-2) NA @ NA @ NA AVG- PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0/- PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY Continued running in hole with 9 5/8"csg to 2410'md and circulated bosoms up.Run in hole to 4300'md and then 6420'md circulating bottoms up both depths.Run csg to 8671'rod. SUMMARY Circulated and reciprocated pipe.Conditioned mud for cement job.Rig down csg equipment.Install csg pack off as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$2845;Rig Watch -$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/29/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT OP05-06 REPORT FOR J.Keener/S.Bowe/A.Buchanan DATE Aug 29,2010 DEPTH 8686' PRESENT OPERATION Pick Up Drill Pipe TIME 24:00:00 YESTERDAY 8686' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160'13 3/8"@ 2415'9 5/8"@ 8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8686.00 89.50 020 3832.25 SURVEY DATA 8618.26 87.28 020 3830.35 8531.87 82.08 0.64 3822.34 8434.60 79.63 0.39 3806.88 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12 1/4" Hughes MX-1L 5171601 1020,3x18 6207' 8686' 2479' 52 2-3-BT-2-E-3-Cl2 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 8686' MW 8.9 VIS - PV 21 YP 9 FL - Gels 4/6/7 CL- 51000 FC - SOL 6.0 SD - OIL 79/21 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS- CUTTING GAS NA @ NA @ NA WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH - ETHANE(C-2) NA @ NA @ NA AVG- PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0/- PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY Test pack off.Change rams to 4.5"-7"variable.Run in hole 24 stands and lay down bad hard band.Service rig.Load drill pipe.Pick up 5"drill pipe.Service iron roughneck.Continue SUMMARY picking up 5"drill pipe as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch-$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/30/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT Ell OP05-06 REPORT FOR S.Beauchamp/S.Bowe/A.Buchanan DATE Aug 12,2010 DEPTH 940.00000 PRESENT OPERATION Drilling TIME 24:00:00 YESTERDAY 160.00000 24 HOUR FOOTAGE 780 CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 987.33 16.5 100.18 975.55 SURVEY DATA 922.45 15.9 102.05 916.13 825.72 12.06 106.35 822.27 792.45 11.01 104.9 789.67 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" Hughes MX1 MT 6080471 1x16,3x20 160' 780' 6:58:58 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 802.9 @ 305.00000 40.4 @ 618.00000 127.7 99.71854 FT/HR SURFACE TORQUE 5064 @ 887.00000 444 @ 466.00000 335.7 0.00000 AMPS WEIGHT ON BIT 25 @ 498.00000 0 @ 281.00000 12.3 15.98383 KLBS ROTARY RPM 43 @ 690.00000 1 @ 887.00000 62 0.00000 RPM PUMP PRESSURE 969 @ 883.00000 502 @ 281.00000 638.8 858.12445 PSI DRILLING MUD REPORT DEPTH 938' MW 9.0 VIS 95 PV 10 YP 42 FL - Gels 33/38/39 CL- 2600 FC -/- SOL 3 SD 0.1 OIL -/97 MBL 24 pH 8.4 Ca-, 120 CCI - MWD SUMMARY INTERVAL 160'TO 940' TOOLS Gyro-pulse,Gamma,Resistivity GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 940.00000 0 @ 428.00000 0 TRIP GAS 0 CUTTING GAS 0 @ 940.00000 0 @ 940.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 0 @ 940.00000 0 @ 940.00000 0 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 940.00000 0 @ 940.00000 0 AVG 0 PROPANE(C-3) 0 @ 940.00000 0 @ 940.00000 0 CURRENT 0 BUTANE(C-4) 0 @ 940.00000 0 @ 940.00000 0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 940.00000 0 @ 940.00000 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY Complete rigging up.Wash down to conductor bottom.Drilled out of conductor while picking up BHA#1 as hole was made.Continued drilling to current depth as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$2845;RigWatch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/13/2010 Daily Report Page 1 of 1 ENI Petroleum El EPOCH Nikaitchuq DAILY WELLSITE REPORT OP05-06 REPORT FOR J.Keener/S.Bowe/A.Buchanan DATE Aug 30,2010 DEPTH 8686' PRESENT OPERATION BOP Test TIME 24:00:00 YESTERDAY 8686' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160'13 3/8"@ 2415'9 5/8"@ 8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8686.00 89.50 0.20 383225 SURVEY DATA 8618.26 8728 0.20 3830.35 8531.87 82.08 0.64 3822.34 8434.60 79.63 0.39 3806.68 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12 1/4" Hughes MX-1L 5171601 1020,3018 6207' 8686' 2479' 52 2-3-BT-2-E-3-Cl2 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 8686' MW 8.8 VIS - PV 20 YP 12 FL - Gels 4/7/8 CL- 51000 FC - SOL 5.9 SD - OIL 79/21 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS- CUTTING GAS NA @ NA @ NA WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH - ETHANE(C-2) NA @ NA @ NA AVG- PROPANE(C-3) NA @ NA @ NA CURRENT- BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0- PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY Continue to pick up 5"drill pipe.Circulate through drill pipe.Pullout of hole and rack back drill pipe.Continue to pick up and rack back drill pipe.Rig up BOP testing equipment and SUMMARY begin BOP test as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch -$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/31/2010 Daily Report Page 1 of 1 ENI Petroleum EpoCH Nikaitchuq DAILY WELLSITE REPORT OP05-06 REPORT FOR J.Keener/S.Bowe/A.Buchanan DATE Aug 31,2010 DEPTH 8686' PRESENT OPERATION Drilling Cement TIME 24:00:00 YESTERDAY 8686' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160'13 3/8"@ 2415'9 5/8"@ 8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8686.00 89.50 020 3832.25 SURVEY DATA 8618.26 87.28 0.20 3830.35 8531.87 82.08 0.64 3822.34 8434.60 79.63 029 3806.68 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB/C PULLED 5 81/2" Hycalog RSR616M-F8 226446 6014 8686' - - 0 - - 4 12 1/4" Hughes MX-1L 5171601 1020,3018 6207' 8686' 2479' 52 2-3-BT-2-E-3-C12 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA 0 NA NA FT/HR SURFACE TORQUE NA 0 NA 0 NA NA AMPS WEIGHT ON BIT NA 0 NA 0 NA NA KLBS ROTARY RPM NA 0 NA 0 NA NA RPM PUMP PRESSURE NA 0 NA 0 NA NA PSI DRILLING MUD REPORT DEPTH 8686' MW 8.7 VIS 93 PV 26 YP 16 FL - Gels 12/18/22 CL- 53000 FC - SOL 8.0 SD - OIL 78/22 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA 0 NA 0 NA TRIP GAS- CUTTING GAS NA 0 NA 0 NA WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) NA 0 NA 0 NA CONNECTION GAS HIGH - ETHANE(C-2) NA 0 NA 0 NA AVG- PROPANE(C-3) NA 0 NA 0 NA CURRENT- BUTANE(C-4) NA 0 NA 0 NA CURRENT BACKGROUND/AVG 0/- PENTANE(C-5) NA @ NA 0 NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY Completed testing of BOP.Pressure test casing to 3000 psi for 30 minutes.Pick up BHA#6.Shallow test BHA.Service rig.Run in hole with 5"drill pipe to 7418'and tag cement.Drill out SUMMARY cement from 7418'to 8380'as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3125;RigWatch-$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 9/1/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH VHNikaitchuq DAILY WELLSITE REPORT OP05-06 REPORT FOR J.Keener/S.Bowe/A.Buchanan DATE Sep 01,2010 DEPTH 9560' PRESENT OPERATION Drilling TIME 24:00:00 YESTERDAY 8686' 24 HOUR FOOTAGE 874' CASING INFORMATION 20"@ 160'13 3/8"@ 2415'9 5/8"@ 8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9435.11 87.14 359.28 3853.72 SURVEY DATA 9339.58 86.81 358.49 3848.68 9243.85 88.41 0.11 3844.69 9148.64 87.44 358.0 3841.24 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" Hycalog RSR616M-F8 226446 6x14 8686' - 874' 9.85 - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 282.8 @ 9108.00000 16.4 @ 8961.00000 151.2 141.09666 FT/HR SURFACE TORQUE 10844 @ 9552.00000 3546 @ 8713.00000 7272.3 8076.20264 AMPS WEIGHT ON BIT 18 @ 8686.00000 0 @ 9468.00000 4.9 0.79920 KLBS ROTARY RPM 123 @ 9380.00000 38 @ 8703.00000 98.7 120.19688 RPM PUMP PRESSURE 3071 @ 9447.00000 2321 @ 9172.00000 2819.6 2985.08667 PSI DRILLING MUD REPORT DEPTH 9540' MW 8.8 VIS 79 PV 26 YP 15 FL 4.8 Gels 11/16/18 CL- 58000 FC -/2 SOL 5.55 SD - OIL 79/21 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 8686 TO 9560 TOOLS Periscope,Telescope,ADM GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 857 @ 9114.00000 6 @ 8980.00000 335.6 TRIP GAS- CUTTING GAS 0 @ 9560.00000 0 @ 9560.00000 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 149369 @ 9114.00000 1264 @ 8979.00000 53146.5 CONNECTION GAS HIGH 42 ETHANE(C-2) 1379 @ 8686.00000 2 @ 9011.00000 208.0 AVG- PROPANE(C-3) 359 @ 8686.00000 0 @ 9011.00000 52.7 CURRENT- BUTANE(C-4) 815 @ 8686.00000 0 @ 9042.00000 63.2 CURRENT BACKGROUND/AVG 450/300 PENTANE(C-5) 498 @ 8686.00000 0 @ 8952.00000 23.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone,Sand,Siltstone PRESENT LITHOLOGY Sandstone 50%,Sand 40%,Silstone 10% DAILY ACTIVITY Continued to drill out cement to 8584'.Circulate bottoms up then test 9 5/8"casing to 3000 psi for 30 minutes.Service rig.Drill out shoe to 20'of new hole to 8706'.Circulate bottoms up SUMMARY and perform Leak Off Test to EMW 12.07 ppg.Drill ahead to 9540'md as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3125;RigWatch-$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 9/2/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT OP05-06 REPORT FOR J.Keener/S.Bowe/A.Buchanan DATE Sep 02,2010 DEPTH 11601' PRESENT OPERATION Drilling TIME 24:00:00 YESTERDAY 9560' 24 HOUR FOOTAGE 2041' CASING INFORMATION 20"@ 160'13 3/8"@ 2415'9 5/8"@ 8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11637.39 87.49 351.63 3837.67 SURVEY DATA 11542.24 89.18 350.1 3834.9 11446.26 89.87 349.59 3834.11 11350.36 89.9 349.04 3833.91 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" Hycalog RSR616M-F8 226446 6x14 8686' - 2915' 23.1 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 301.6 @ 10257.00000 18.3 @ 9758.00000 182.0 188.31282 FT/HR SURFACE TORQUE 12735 @ 9871.00000 7545 @ 9566.00000 9537.8 10418.11816 AMPS WEIGHT ON BIT 17 @ 9871.00000 0 @ 9923.00000 3.1 4.51043 KLBS ROTARY RPM 133 @ 10760.00000 80 @ 9768.00000 129.5 130.42561 RPM PUMP PRESSURE 3330 @ 11508.00000 2385 @ 9690.00000 3068.4 3257.24536 PSI DRILLING MUD REPORT DEPTH 11601' MW 8.7 VIS 80 PV 27 YP 13 FL 4.0 Gels 13/21/23 CL- 46000 FC -/- SOL 8.0 SD - OIL 77/23 MBL - pH - Ca-, - CCI - MWD SUMMARY INTERVAL 8686'TO 11601' TOOLS Periscope,Telescope,ADM GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 1292 @ 10104.00000 2 @ 10300.00000 664.6 TRIP GAS - CUTTING GAS 0 @ 11601.00000 0 @ 11601.00000 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 163837 @ 9660.00000 366 @ 10300.00000 84014.9 CONNECTION GAS HIGH 42 ETHANE(C-2) 837 @ 10104.00000 1 @ 10300.00000 391.0 AVG 31 PROPANE(C-3) 529 @ 9804.00000 0 @ 10300.00000 74.2 CURRENT 40 BUTANE(C-4) 481 @ 9804.00000 0 @ 10300.00000 120.5 CURRENT BACKGROUND/AVG 558/800 PENTANE(C-5) 375 @ 9804.00000 0 @ 10300.00000 102.5 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 90%,Sandstone 10% DAILY ACTIVITY SUMMARY Continued drilling ahead from 9560'to current depth of 11601'md as of midnight.High gas recorded for last 24 hours is 1292u. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3125;RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 9/3/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT Ell OP05-06 REPORT FOR J.Keener/S.Bowe/A.Buchanan DATE Sep 03,2010 DEPTH 13613' PRESENT OPERATION Drilling TIME 24:00:00 YESTERDAY 11601' 24 HOUR FOOTAGE 2012' CASING INFORMATION 20"@ 160' 13 3/'8"@ 2415' 9 5/8"@ 8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13646.19 89.84 358.55 3890.89 SURVEY DATA 13549.15 92.65 358.74 3892.99 13453.44 93.04 357.85 3897.74 13358.11 91.7 357.79 3901.69 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" Hycalog RSR616M-F8 226446 6x14 8686' - 4927' 36.6 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 364.6 @ 13040.00000 16.5 @ 12453.00000 181.9 260.00702 FT/HR SURFACE TORQUE 15831 @ 13592.00000 9595 @ 11740.00000 11309.9 12051.53711 AMPS WEIGHT ON BIT 17 @ 11602.00000 0 @ 12014.00000 3.5 8.50123 KLBS ROTARY RPM 134 @ 12285.00000 65 @ 13015.00000 127.5 130.41594 RPM PUMP PRESSURE 3706 @ 13417.00000 2692 @ 12048.00000 3336.5 3698.92749 PSI DRILLING MUD REPORT DEPTH 13613' MW 8.8 VIS 97 PV 30 YP 20 FL 4.0 Gels 18/27/30 CL- 41000 FC -/2 SOL 8.5 SD - OIL 72 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 8686'TO 13613' TOOLS Periscope,Telescope,ADN GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 1582 @ 13178.00000 12 @ 12657.00000 738.3 TRIP GAS- CUTTING GAS 0 @ 13613.00000 0 @ 13613.00000 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 205762 @ 12860.00000 1466 @ 12657.00000 90944.5 CONNECTION GAS HIGH 115 ETHANE(C-2) 1243 @ 12861.00000 7 @ 12657.00000 443.2 AVG 40 PROPANE(C-3) 260 @ 13059.00000 0 @ 12657.00000 48.5 CURRENT 0 BUTANE(C-4) 559 @ 13059.00000 1 @ 12657.00000 114.6 CURRENT BACKGROUND/AVG 46/500 PENTANE(C-5) 515 @ 13059.00000 1 @ 12657.00000 88.8 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 90%,Sandstone 10% DAILY ACTIVITY SUMMARY Continue drilling from 11601'md to 13613'md with no issues as of midnight.Daily high gas peak of 1582u. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3125;Rig Watch-$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 9/4/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT PI OP05-06 REPORT FOR J.Keener/S.Bowe/A.Buchanan DATE Sep 04,2010 DEPTH 15433' PRESENT OPERATION Preparing for sidetrack TIME 24:00:00 YESTERDAY 13613' 24 HOUR FOOTAGE 1820' CASING INFORMATION 20"@ 160'13 3/8"@ 2415'9 5/8"@ 8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15369.45 82.63 357.91 3986.29 SURVEY DATA 15273.44 85.55 358.87 3976.41 15177.42 87.01 0.44 3970.18 15081.54 85.08 2.85 3963.56 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" Hycalog RSR616M-F8 226446 6x14 8686' - 6747' 48.1 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 321.8 @ 13675' 22.7 @ 14725' 193.4 175.74944 FT/HR SURFACE TORQUE 16584 @ 15181' 10586 @ 13826' 12628.6 13253.12109 AMPS WEIGHT ON BIT 17 @ 15192' 0 @ 14348' 6.2 8.96744 KLBS ROTARY RPM 133 @ 13810' 67 @ 14723' 128.4 130.61644 RPM PUMP PRESSURE 3886 @ 15277' 2939 @ 14206' 3663.0 3784.22754 PSI DRILLING MUD REPORT DEPTH 15433' MW 8.8 VIS 86 PV 28 YP 17 FL 4.0 Gels 17/26/28 CL- 42500 FC -/2 SOL 8.0 SD - OIL 74/26 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL 8686'TO 15433' TOOLS Periscope,Telescope,ADN GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 1274 @ 13868' 2 @ 15406' 446.9 TRIP GAS - CUTTING GAS 0 @ 15424' 0 @ 15424' 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 191200 @ 14358' 1597 @ 14276' 64368.9 CONNECTION GAS HIGH 68 ETHANE(C-2) 846 @ 13843' 0 @ 15402' 294.1 AVG 32 PROPANE(C-3) 110 @ 14358' 0 @ 14276' 322 CURRENT 0 BUTANE(C-4) 418 @ 14358' 2 @ 14725' 86.5 CURRENT BACKGROUND/AVG 15/350 PENTANE(C-5) 417 @ 14358' 2 @ 15200' 78.8 HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Siltstone,Sandstone,Sand PRESENT LITHOLOGY Siltstone 80%,Sandstone 10%,Sand 10% DAILY ACTIVITY Continue drilling ahead from 13613'md to 15433'md with a high gas peak of 1274u at 13868'md.At 15433'md drilled past fault at 15190'md and was decided to back ream to 14508'md SUMMARY and sidetrack as of midnight. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3125;Rig Watch -$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 9/5/2010 Daily Report Page 1 of 1 ENI Petroleum LI EPOCH DAILY WELLSITE REPORT OPO5-06 REPORT FOR DATE Sep 05,2010 DEPTH 16118.00000 PRESENT OPERATION DRILLING TIME 24:00:00 YESTERDAY 15433.00000 24 HOUR FOOTAGE 685 CASING INFORMATION 20"@ 160' 13 3/8"@ 2415'9 5/8"@ 8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 16039.08 899.77 247 3995.67 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" HYCALOG RSR616M-F8 226446 6x14 8686' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 714.1 @ 16020.00000 12.2 @ 15565.00000 190.6 83.83827 FT/HR SURFACE TORQUE 17596 @ 15437.00000 9795 @ 15955.00000 13385.4 16315.37402 AMPS WEIGHT ON BIT 24 @ 15530.00000 0 @ 15911.00000 7.2 17.65957 KLBS ROTARY RPM 132 @ 15740.00000 48 @ 15974.00000 116.6 119.28697 RPM PUMP PRESSURE 4033 @ 15862.00000 2175 @ 15931.00000 3660.7 3905.57666 PSI DRILLING MUD REPORT DEPTH MW 8.7 VIS 90 PV 27 YP 20 FL 3.0 Gels 17/28/31 CL- 41500 FC /2 SOL 8 SD OIL 74 MBL pH Ca-) CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 1030 @ 15550.00000 2 @ 15563.00000 460.0 TRIP GAS 0 CUTTING GAS 0 @ 16118.00000 0 @ 16118.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 129589 @ 15550.00000 263 @ 15563.00000 61035.0 CONNECTION GAS HIGH 0 ETHANE(C-2) 664 @ 15550.00000 1 @ 15563.00000 299.2 AVG 460 PROPANE(C-3) 48 @ 15851.00000 0 @ 15563.00000 23.9 CURRENT 548 BUTANE(C-4) 148 @ 15851.00000 0 @ 15563.00000 65.1 CURRENT BACKGROUND/AVG 500 PENTANE(C-5) 131 @ 15499.00000 0 @ 15563.00000 49.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND 80%,SANDSTONE 10%,SILTSTONE 10% PRESENT RTED;MATRIX SILT;TEXTURALLY IMMATURE;COMPOSITIONALLY SUB-MATURE;TRANSLUCENT QUARTZ GRAINS;GLAUCONITE,REDDISH BROWN CARBONACEOUS LITHOLOGY MATERIAL AND SHELL FRAGMENTS;ODOR NONE TO SLIGHT;NO STAIN ON SAND GRAINS,SLIGHT AMBER STAIN IN SANDSTONE;FLUORESCENC DAILY ACTIVITY DIRECTIONAL WORK FROM 14571'TO 14604';ROTARY DRILL FROM 14604'TO 15815',PUMP WEIGHTED SWEEP @ 15433';GENERATORS DOWN FOR ONE(1)HOUR; SUMMARY ROATRAY DRILL FROM 15815'TO 16118'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3405, RW$1450 REPORT BY TOLLEF WINSLOW file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 9/6/2010 Daily Report Page 1 of 1 ENI Petroleum H EPOCH DAILY WELLSITE REPORT OPOS-06 REPORT FOR BEAUCHAMP/BOWE/BUCHANAN DATE Sep 06,2010 DEPTH 17035.00000 PRESENT OPERATION WIPER TRIP TIME 24:00:00 YESTERDAY 16118.00000 24 HOUR FOOTAGE 917 CASING INFORMATION 20"@ 160' 13 3/8"@ 2415 9 5/8"@ 8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13970' 93.90 1.59 3997' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 1/2" HYCAOLOG RSR616M-F8 226446 6x14 8686' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 222.0 @ 16298.00000 9.2 @ 16143.00000 148.6 115.28217 FT/HR SURFACE TORQUE 17792 @ 16257.00000 12371 @ 16152.00000 15146.6 14905.52930 AMPS WEIGHT ON BIT 20 @ 16123.00000 0 @ 16724.00000 7.0 10.64106 KLBS ROTARY RPM 135 @ 16563.00000 80 @ 16195.00000 128.6 130.37860 RPM PUMP PRESSURE 4161 @ 16325.00000 1396 @ 16419.00000 3852.3 4008.30786 PSI DRILLING MUD REPORT DEPTH 17035/3992 MW 8.8 VIS 87 PV 28 YP 18 FL 4.0 Gels 16/26/28 CL- 44000 FC /2 SOL 8 SD OIL 80/20 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 816 @ 16227.00000 7 @ 17032.00000 271.6 TRIP GAS 0 CUTTING GAS 0 @ 17035.00000 0 @ 17035.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 142115 @ 16227.00000 1813 @ 16908.00000 45483.9 CONNECTION GAS HIGH 0 ETHANE(C-2) 629 @ 16507.00000 0 @ 17034.00000 211.2 AVG 400 PROPANE(C-3) 62 @ 16482.00000 0 @ 17034.00000 21.1 CURRENT 0 BUTANE(C-4) 168 @ 16227.00000 0 @ 17034.00000 54.3 CURRENT BACKGROUND/AVG 33 PENTANE(C-5) 102 @ 16507.00000 0 @ 16945.00000 37.6 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE 80%,SAND 20% SILTSTONE=BROWNISH GRAY TO MEDIUM DARK GRAY TO OLIVE BLACK;MODERATELY HARD TO FIRMLY FRIABLE TO EASILY FRIABLE;TOUGH DENSE TO BRITTLE AND NT CRUNCHY TENACITY;BLOCKY FRACTURE;TABULAR TO WEDGELIKE TO MASSIVE CUTTINGS HABIT;GREASY VITREOUS EXTERIOR TO WAXY DULL EARTHY INTERIOR LUSTER; PRESENT T SILTY TO GRITTY TEXTURE;VERY THIN BLACK TO BROWN TO REDDISH BROWN LAMINATIONS ARE VISIBLE ON SMOOTH SURFACES OF CUTTINGS;SLIGHT TO NO OIL ODOR;NO VISIBLE OIL STAIN;EVEN FAINT YELLOWISH WHITE SAMPLE FLUORESCENCE;SLOW STREAMING DULL WHITE CUT FLUORESCENCE;AMBER VISIBLE CUT;MEDIUM STRAW VISIBLE RESIDUE;DULL YELLOWISH WHITE RESIDUAL FLUORESCENCE. DAILY ACTIVITY SUMMARY ROTARY DRILL FROM 16118'TO 17035',CIRUCLATE AND CONDITION MUD,PUMP WEIGHTED SWEEP,BACK REAM OUT OF HOLE. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$4335, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 9/7/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT El I OP05-06 REPORT FOR BEAUCHAMP/BOWE/BUCHANA DATE Sep 07,2010 DEPTH 17035.00000 PRESENT OPERATION PREP TO DISPLACE DRILLING FLUID TIME 24:00:00 YESTERDAY 17035.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"2415'9 5/8"@8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13970' 93.9 1.59 3997' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" HYCALOG RSR616M-F8 226446 6x14 8686' 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 17035/3993 MW 8.9 VIS PV 22 YP 6 FL Gels 3/3/4 CL- 171000 FC / SOL 9 SD OIL 50/50 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 321 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 25 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE 80%,SAND 20% SILTSTONE(16880-17035)=BROWNISH GRAY TO MEDIUM DARK GRAY TO OLIVE BLACK;MODERATELY HARD TO FIRMLY FRIABLE TO EASILY FRIABLE;TOUGH DENSE TO PRESENT BRITTLE AND CRUNCHY TENACITY;BLOCKY FRACTURE;TABULAR TO WEDGE LIKE TO MASSIVE CUTTINGS HABIT;GREASY VITREOUS EXTERIOR TO WAXY DULL EARTHY LITHOLOGY T INTERIOR LUSTER;SILTY TO GRITTY TEXTURE;VERY THIN BLACK TO BROWN TO REDDISH BROWN LAMINATIONS ARE VISIBLE ON SMOOTH SURFACES OF CUTTINGS;SLIGHT TO NO OIL ODOR;NO VISIBLE OIL STAIN;EVEN FAINT YELLOWISH WHITE SAMPLE FLUORESCENCE;SLOW STREAMING DULL WHITE CUT FLUORESCENCE;AMBER VISIBLE CUT; MEDIUM STRAW VISIBLE RESIDUE;DULL YELLOWISH WHITE RESIDUAL FLUORESCENCE. DAILY ACTIVITY BACK REAM FROM 13709'TO 8635'(CASING SHOE);CIRUCLATE AND CONDITION DRILLING FLUID(CBU X3);PUMP HIGH WEIGHT SWEEP;CUT/SLIP DRILLING LINE;CALIBRATE SUMMARY BLOCK;TRIP IN HOLE FROM 8635'TO 16920',FILLING PIPE EVERY 20 STANDS,WASH AND REAM FROM 16198'TO 16920';CIRUCLATE AND CONDITION DRILLING FLUID;PUMP WEIGHTED SWEEP;CBU X3-4;CLEAN PITS;PREP FOR DRILLING FLUID DISPLACEMENT. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$4335, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 9/8/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT El OP05-06 REPORT FOR BEAUCHAMP/BOWE/BUCHANAN DATE Sep08,2010 DEPTH 17035.00000 PRESENT OPERATION POOH TIME 24:00:00 YESTERDAY 17035.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"2415'9 5/8"@8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13970' 93.9 1.59 3997' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" HYCALOG RSR616M-F8 226446 6x14 8686' 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 17035/3993 MW 9.0 VIS PV 24 YP 6 FL Gels 3/3/4 CL- 152000 FC / SOL 7 SD OIL 50/50 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 436 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 SILTSTONE 80%,SAND 20% SILTSTONE=BROWNISH GRAY TO MEDIUM DARK GRAY TO OLIVE BLACK;MODERATELY HARD TO FIRMLY FRIABLE TO EASILY FRIABLE;TOUGH DENSE TO BRITTLE AND PRESENT CRUNCHY TENACITY;BLOCKY FRACTURE;TABULAR TO WEDGE LIKE TO MASSIVE CUTTINGS HABIT;GREASY VITREOUS EXTERIOR TO WAXY DULL EARTHY INTERIOR LUSTER; LITHOLOGY SILTY TO GRITTY TEXTURE;VERY THIN BLACK TO BROWN TO REDDISH BROWN LAMINATIONS ARE VISIBLE ON SMOOTH SURFACES OF CUTTINGS;SLIGHT TO NO OIL ODOR;NO VISIBLE OIL STAIN;EVEN FAINT YELLOWISH WHITE SAMPLE FLUORESCENCE;SLOW STREAMING DULL WHITE CUT FLUORESCENCE;AMBER VISIBLE CUT;MEDIUM STRAW VISIBLE RESIDUE;DULL YELLOWISH WHITE RESIDUAL FLUORESCENCE. DAILY ACTIVITY CIRCULATE AND CONDITION HOLE;DISPLACE TO OIL BASE;POOH FROM 16765'TO 16288',FLOW CHECK:SMALL FLOW;WASH REAM IN HOLL FROM 16288'TO 16920'; SUMMARY CIRCULATE AND CONDITION BOTTOMS UP @ 16920';MONITOR HOLE FOR 20 MIN,FLOW BACK 2.6 BBLS;BUILD VOLUME,WEIGHT UP TO 9.0 HEAVE IN/OUT;TRIP OUT OF HOLE FROM 16920'TO 11988' EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$4335, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\Daily Report... 9/9/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT HI OP05-06 REPORT FOR S.Beauchamp/D.Smith/A.Buchanan DATE Aug 13,2010 DEPTH 2425' PRESENT OPERATION Circulating Hole Clean TIME 24:00:00 YESTERDAY 940' 24 HOUR FOOTAGE 1485' CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2425.00 50.94 82.99 2194.63 SURVEY DATA 2347.28 50.94 82.99 2145.65 2228.30 44.45 83.18 2065.61 2132.12 39.79 83.43 1994.29 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" Hughes MX1 MT 6080471 1016,3x20 160' 2425' 2265' 22:06:24 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 324.3 @ 1544.00000 27.4 @ 1000.00000 120.9 165.78793 FT/HR SURFACE TORQUE 16514 @ 1316.00000 3 @ 1370.00000 1004.5 5217.84766 AMPS WEIGHT ON BIT 27 @ 2396.00000 0 @ 1567.00000 15.9 20.95174 KLBS ROTARY RPM 46 @ 2091.00000 0 @ 2231.00000 9.9 42.78368 RPM PUMP PRESSURE 1522 @ 2396.00000 691 @ 978.00000 1081.4 1355.68347 PSI DRILLING MUD REPORT DEPTH 2425' MW 9.3 VIS 80 PV 12 YP 30 FL - Gels 23/32/37 CL- 1200 FC 3/- SOL 7 SD 0.15 OIL -/93 MBL 15 pH 9.0 Ca+ 60 CCI - MWD SUMMARY INTERVAL 940'TO 2425' TOOLS Gamma,Resistivity GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 485 @ 1842.00000 0 @ 1247.00000 136.2 TRIP GAS 0 CUTTING GAS 0 @ 2425.00000 0 @ 2425.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 97345 @ 1842.00000 0 @ 1053.00000 27530.6 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 1924.00000 0 @ 1053.00000 0 AVG 0 PROPANE(C-3) 0 @ 1055.00000 0 @ 1053.00000 0 CURRENT 49 BUTANE(C-4) 0 @ 1055.00000 0 @ 1053.00000 0 CURRENT BACKGROUND/AVG 30/70 PENTANE(C-5) 0 @ 1055.00000 0 @ 1053.00000 0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Claystone,Sand PRESENT LITHOLOGY Claystone 70%,Sand 30% DAILY ACTIVITY SUMMARY Drilled ahead from 940'toTD at 2425'.Reamed the dog leg around 1850'-1950'.Hit TD and began circulating to clean hole. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$2845;RigWatch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/14/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT HI OP05-06 REPORT FOR BEAUCHAMP/BOWE/BUCHANAN DATE Sep 09,2010 DEPTH 17035.00000 PRESENT OPERATION: RUNNING PRODUCTION LINER TIME 24:00:00 YESTERDAY 17035.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"2415 9 5/8"@8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13970' 93.9 1.59 3997' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" HYCALOG RSR616M-F8 226446 6x14 8686' 17035' 9179' 69.07 1-1-CT-S-X-I-NO-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 MW 9.0 VIS PV 24 YP 7 FL Gels 3/3/4 CL- 152000 FC SOL 7 SD OIL 50/50 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 SILTSTONE 80%,SAND 20% PRESENT SILTSTONE=BROWNISH GRAY TO MEDIUM DARK GRAY TO OLIVE BLACK;MODERATELY HARD TO FIRMLY FRIABLE TO EASILY FRIABLE;TOUGH DENSE TO BRITTLE AND LITHOLOGY CRUNCHY TENACITY;BLOCKY FRACTURE;TABULAR TO WEDGE LIKE TO MASSIVE CUTTINGS HABIT;GREASY VITREOUS DAILY ACTIVITY REAM/WASH OUT OF HOLE FROM 11988'TO 8635';CLEAN DRILL FLOOR,PREP TO LAY DOWN PIPE,LAYDOWN 5"DRILL PIPE FROM 8635'TO 3647';TRIP OUT OF HOLE,STAND SUMMARY BACK 30 STANDS OF DRILL PIPE;LAY DOWN BHS;MONITOR WELL:STATIC;PICK UP AND STAND BACK 48 JOINTS HEAVEY WEIGHT DRILL PIPE;RIG UP TO RUN LINER EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125;RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\Desktop\20100906.htm 9/10/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH OCH DAILY WELLSITE REPORT OP05-06 REPORT FOR BEAUCHAMP/SMITH/BUCHANAN DATE Sep10,2010 DEPTH 17035.00000 PRESENT OPERATION TEST PACKER TIME 24:00:00 YESTERDAY 17035.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"2415'9 5/8"@8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13970' 93.9 1.59 3997' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" HYCALOG RSR616M-F8 226446 6x14 8686' 17035' 9179' 69.07 1-1-CT-D-C-I-NO-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 MW 9.0 VIS PV 24 VP 8 FL Gels 3/3/5 CL- 152000 FC SOL 7 SD OIL 50/50 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 SILTSTONE 80%,SAND 20% PRESENT SILTSTONE=BROWNISH GRAY TO MEDIUM DARK GRAY TO OLIVE BLACK;MODERATELY HARD TO FIRMLY FRIABLE TO EASILY FRIABLE;TOUGH DENSE TO BRITTLE AND LITHOLOGY CRUNCHY TENACITY;BLOCKY FRACTURE;TABULAR TO WEDGE LIKE TO MASSIVE CUTTINGS HABIT;GREASY VITREOUS DAILY ACTIVITY CONTINUE RUNNIN GLINER;MAKE UP LINER SETTING SLEAVE AND PICK UP;MAKE UP 5 1/2"LINER HANGER;RUN LNER ON DRIL PIPER;CIRUCLATE AND CONDITION; SUMMARY DROP BALL AND PUMP ON SEAT TO SET PACKER;TEST PACKER ON BACKSIDE TO 1500 psi FOR 10 MIN;RECORD ON CHART. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125;RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\Desktop\20100910.htm 9/11/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT Ell OP05-06 REPORT FOR BEAUCHAMP/SMITH/BUCHANAN DATE Sep 10,2010 DEPTH 17035.00000 PRESENT OPERATION LOGGING WITH CASED HOLE TOOLS TIME 24:00:00 YESTERDAY 17035.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"2415'9 5/8"@8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13970' 93.9 1.59 3997' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" HYCALOG RSR616M-F8 226446 6x14 8686' 17035' 9179' 69.07 1-1-CT-D-C-I-NO-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 17035/3992 MW 9.0 VIS PV 24 YP 8 FL Gels 3/3/5 CL- 152000 FC SOL 7 SD OIL 50/50 MBL pH Ca-u 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 SILTSTONE 80%,SAND 20% PRESENT SILTSTONE=BROWNISH GRAY TO MEDIUM DARK GRAY TO OLIVE BLACK;MODERATELY HARD TO FIRMLY FRIABLE TO EASILY FRIABLE;TOUGH DENSE TO BRITTLE AND LITHOLOGY CRUNCHY TENACITY;BLOCKY FRACTURE;TABULAR TO WEDGE LIKE TO MASSIVE CUTTINGS HABIT;GREASY VITREOUS DAILY ACTIVITY PRESSURE TEST CASING SHOE;TEST LINER PACKER @ 1500 PSI FOR 10 MIN,TEST GOOD;CIRCULATE AND CONDITION,CBU @ 8431';LAYDOWN DRILL PIPE;SERVICE TOP SUMMARY DRIVE/BLOCK/DRAWORKS;LAYDOWN DRILL PIPE;TRIP OUT OF HOLE;RIG UP CASED HOLE LOGGING TOOLS;RUN CASED HOLE LOGGING TOOLS IN HOLE;LOG CASED HOLE. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125;RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\Desktop\20100911.htm 9/12/2010 Daily Report Page 1 of 1 ENI Petroleum DAILY WELLSITE REPORT EPOCH OP05-06 REPORT FOR BEAUCHAMP/SMITH/BUCHANAN DATE Sep 12,2010 DEPTH 17035.00000 PRESENT OPERATION LAY DOWN 5"DRILL PIPE TIME 24:00:00 YESTERDAY 17035.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"2415 9 5/8"@8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13970' 93.9 1.59 3997' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 1/2" HYCALOG RSR616M-F8 226446 6x14 8686' 17035' 9179' 69.07 1-1-CT-D-C-I-NO-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 17035/3992 MW 9.0 VIS PV 24 YP 7 FL Gels 3/3/5 CL- 153000 FC SOL 7 SD OIL 50/50 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 SILTSTONE 80%,SAND 20% PRESENT SILTSTONE=BROWNISH GRAY TO MEDIUM DARK GRAY TO OLIVE BLACK;MODERATELY HARD TO FIRMLY FRIABLE TO EASILY LITHOLOGY FRIABLE;TOUGH DENSE TO BRITTLE AND CRUNCHY TENACITY;BLOCKY FRACTURE;TABULAR TO WEDGE LIKE TO MASSIVE CUTTINGS HABIT;GREASY VITREOUS DAILY ACTIVITY CONTINUE RUNNING CASED HOLE LOGS;RIG DOWN CASED HOLE LOGGING TOOLS;SERVICE TOP DRIVE,CROWN,DRAW SUMMARY WORKS,CHANGE OUT SAVER SUB,GREASE GRIPPER AND RETOURQUE TOURQUE TUB RAILS;TRIP IN HOLE WITH MULE SHOE, 41 STANDS,LAYDOWN 123 JOINTS;RUN IN HOLE WITH 40 STANDS,LAY DOWN 90 JOINTS. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125; RIGWATCH $1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\Desktop\20100912.htm 9/13/2010 Daily Report Page 1 of 1 EM Petroleum DAILY WELLSITE REPORT EPOCH OP05-06 REPORT FOR BEAUCHAMP/SMITH/BUCHANAN DATE Sep 13,2010 DEPTH 17035.00000 PRESENT OPERATION RUNNING IN HOLE WITH JUNK BASKET TIME 24:00:00 YESTERDAY 17035.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"2415'9 5/8"@8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13970' 93.9 1.59 3997' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 1/2" HYCALOG RSR616M-F8 226446 6x14 8686' 17035' 9179' 69.07 1-1-CT-D-C-I-NO-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 17035/3992 MW 9.1 VIS PV 21 YP 6 FL Gels 2/3/4 CL- 150000 FC SOL 7 SD OIL 50/50 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 SILTSTONE 80%,SAND 20% PRESENT SILTSTONE=BROWNISH GRAY TO MEDIUM DARK GRAY TO OLIVE BLACK;MODERATELY HARD TO FIRMLY FRIABLE TO EASILY LITHOLOGY FRIABLE;TOUGH DENSE TO BRITTLE AND CRUNCHY TENACITY;BLOCKY FRACTURE;TABULAR TO WEDGE LIKE TO MASSIVE CUTTINGS HABIT;GREASY VITREOUS DAILY ACTIVITY FINSIH LAYING DOWN 5"DRILL PIPE;MAKE UP AND RIG UP SUBMERSIBLE PUMP;STAND BACK SUBMERSIBLE PUMP;TEST SUMMARY BOP'S;RELOAD PIPE SHED WITH 5"DRILL PIPE;FINISH TESTING;PICK UP AND MAKE UP BAKER FISHING TOOLS WITH JUNK BASKET;RUN JUNK BASKET IN HOLE ON 5"DRILL PIPE. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125; RIGWATCH $1450 REPORT BY TOLLEF WINSLOW file://C:\Documents and Settings\EpochAdmin\Desktop\20100906.htm 9/14/2010 Daily Report Page 1 of 1 ENI Petroleum DAILY WELLSITE REPORT EPOCH OP05-06 REPORT FOR BEAUCHAMP/SMITH DATE Sep 14,2010 DEPTH 17035 PRESENT OPERATION RUNNING IN HOLE WITH MAGNET BHA TIME 24:00:00 YESTERDAY 17035 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2415'9 5/8"@ 8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13970' 93.9 1.59 3997' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 1/2" HYCALOG RSR616M-F8 226446 6x14 8686' 17035' 9179' 69.07 1-1-CT-D-C-I-NO-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 MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY PICK UP DRILL PIPE FROM 807'TO 8083';CIRUCLATE AND CONDITION AT 8038',DROP BALL AND PUMP DOWN;REAM AND WASH ACTIVITY HOLE FROM 8038'TO 8467';TRIP IN HOLE TO 8494';TRIP OUT OF HOLE;LAY DOWN BHA,CLEAN METAL OFF MAGNETS;CLEAN SUMMARY JUNK BASKETS;CUT AND SLIP DRILL LINE;INSPECT DRAW WORKS;WAIT ON THIRD PARTY TOOLS(STRING MAGNETS);PICK UP DRILL PIPE;PICK UP AND MAKE UP CASING BRUSH,STRING MAGNETS MULE SHOE;TRIP IN HOLE TO 1009'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125; RIGWATCH $1450 REPORT BY TOLLEF WINSLOW file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 9/15/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT OP05-06 REPORT FOR BEAUCHAMP/SMITH DATE Sep 15,2010 DEPTH 17035 PRESENT OPERATION REPAIR PIPE SKATE TIME 24:00:00 YESTERDAY 17035 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160'13 3/8"@ 2415'9 5/8"@ 8671' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 13970' 93.9 1.59 3997' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 81/2" HYCALOG RSR616M-F8 226446 6x14 8686' 17035' 9179' 69.07 1-1-CT-D-C-I-NO-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 17035/3992 MW 9.1 VIS PV 20 YP 6 FL Gels 2/3/3 CL- 151000 FC SOL 7 SD OIL 46.5/53.5 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 CONTINUE TO RUN IN HOLE WITH MAGNET BHA;WASH AND REAM FROM 8092'TO 8494';BEGIN TO POOH;PIPE SKATE MALFUNCTION;RACK DP IN DERICK;CLEAN AN SUMMARY DOCUMENT METAL SHAVINGS(4-6 LBS TOTAL,TWO RUNS);RUN IN HOLE TO 8029';CIRUCLATE AND WASH TO 8220';CONTINUE TO REPAIR PIPE SKATE. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125;RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 9/16/2010 Daily Report Page 1 of 1 ENI Petroleum DAILY WELLSITE REPORT EPOCH OP05-06 REPORT FOR BEACHAMP/MORRIS DATE Sep 16,2010 DEPTH 17035.00000 PRESENT OPERATION RIG UP TO RUN 4 1/2"COMPLETION TIME 24:00:00 YESTERDAY 17035.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2415'9 5/8"@ 8671' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 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 9.1 VIS PV 20 YP 6 FL Gels 2/3/4 CL- 152000 FC SOL 7 SD OIL 46.5 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 REPAIR PIPE SKATE AND ASSOCIATED EQUIPMENT;CHANGE OUT SKATE FLUIDS;CHANGE OUT PULSASTION DAMPNER ON SUMMARY PUMP#1;WASH REAM FROM 8220'TO 8348';MONITOR WELL FOR 15 MINUTES;PULL OUT OF HOLE,LAY DOWN 5"DRILL PIPE; CLEAN BHA AND REMOVE METAL SHAVINGS/CUTTIN EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125, RIGWATCH $1450 REPORT BY TOLLEF WINSLOW file://C:\DOCUMENTS AND SETTINGSTPOCHADMIN\DESKTOP\NAB245-E - ENI ... 9/17/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH VHDAILY WELLSITE REPORT OP05-06 REPORT FOR BEACHAMP/MORRIS DATE Sep 17,2010 DEPTH 17035.00000 PRESENT OPERATION WAITING ON THIRD PARTY TOOLS/RUNNING COMPLETIONTOTOTOLLEF TIME 24:00:00 YESTERDAY 17035.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160'13 3/8"@ 2415'9 5/8"@ 8671' 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 9.1 VIS PV 20 YP 7 FL Gels 2/3/3 CL- 153000 FC SOL 7 SD OIL 46.5 MBL pH Can 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 LITHO LOGY PRESENT LITHOLOGY DAILY ACTIVITY PICK UP AND RIG UP COMPLETION TOOLS;PICK UP AND MAKE UP DOWN HOLE COMPLETION PUMPS;RUN IN HOLE WITH DOWN HOLE PUMPS;CABLE DAMAGED, SUMMARY WAIT FOR TOOLS. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML$3125, RIGWATCH$1450 REPORT BY TOLLEF WINSLOW file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\DESKTOP\NAB245-E- ENI ... 9/18/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT OP05-06 REPORT FOR S.Beauchamp/D.Smith/A.Buchanan DATE Aug 14,2010 DEPTH 2425' PRESENT OPERATION Running Casing TIME 24:00:00 YESTERDAY 2425' 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2425.00 50.94 82.99 2194.63 SURVEY DATA 234728 50.94 82.99 2145.65 2228.30 44.45 83.18 2065.61 2132.12 39.79 83.43 1994.29 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" Hughes MX1 MT 6080471 1016,3x20 160' 2425' 2265' 22:06:24 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT/HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 2425' MW 9.6 VIS 112 PV 13 YP 29 FL 6.2 Gels 23/31/4,3 CL- 1150 FC 3/- SQL 10 SD -/90 OIL 0.2 MBL 16 pH 8.4 Ca+ 60 CCI - MWD SUMMARY INTERVAL 940'TO 2425' TOOLS Gamma,Resistivity GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS 924 CUTTING GAS NA @ NA @ NA WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) NA @ NA @ NA CONNECTION GAS HIGH 0 ETHANE(C-2) NA @ NA @ NA AVG 0 PROPANE(C-3) NA @ NA @ NA CURRENT 0 BUTANE(C-4) NA @ NA @ NA CURRENT BACKGROUND/AVG 0 PENTANE(C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Claystone,Sand PRESENT LITHOLOGY Claystone 70%,Sand 30% DAILY ACTIVITY Circulate hole clean at TD by pumping 4 bottoms up and a sweep.Backream from 2425'to 680'with a may gas of 924u.Circulate and run in hole to 2425'.Circulate hole clean pump another SUMMARY sweep.Pull out of hole and lay down BHA.Rig up for casing.Begin running in hole with 133/8"casing.Run casing to 1700'as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$2845;Rig Watch -$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/15/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT Ell OP05-06 REPORT FOR S.Beauchamp/D.Smith/A.Buchanan DATE Aug 15,2010 DEPTH 2425' PRESENT OPERATION N/U BOP TIME 24:00:00 YESTERDAY 2425' 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2415' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2425.00 50.94 82.99 2194.53 SURVEY DATA 2347.28 50.94 82.99 2145.65 2228.30 44.45 83.18 2065.61 2132.12 39.79 83.43 1994.29 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" Hughes MX1 MT 6080471 1516,3x20 160' 2425' 2265' 22:06:24 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA NA @ NA NA NA FT/HR SURFACE TORQUE NA @ NA NA @ NA NA NA AMPS WEIGHT ON BIT NA @ NA NA @ NA NA NA KLBS ROTARY RPM NA @ NA NA @ NA NA NA RPM PUMP PRESSURE NA @ NA NA @ NA NA NA PSI DRILLING MUD REPORT DEPTH 2425' MW 9.5 VIS - PV 13 YP 4 FL - Gels 1/1/2 CL- - FC - SOL - SD - OIL - MBL - pH - Ca.. - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA NA @ NA NA TRIP GAS 0 CUTTING GAS NA @ NA NA @ NA NA WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) NA @ NA NA @ NA NA CONNECTION GAS HIGH 0 ETHANE(C-2) NA @ NA NA @ NA NA AVG 0 PROPANE(C-3) NA @ NA NA @ NA NA CURRENT 0 BUTANE(C-4) NA @ NA NA @ NA NA CURRENT BACKGROUND/AVG 0 PENTANE(C-5) NA @ NA NA @ NA NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Claystone,Sand PRESENT LITHOLOGY Claystone 70%,Sand 30% DAILY ACTIVITY SUMMARY Run in 13 3/8"casing to 2415'MD.Rig up cementing equipment and cement.Plugs bumped and held.Nipple down BOP,installed wellhead and began to nipple up BOP. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3195;Rig Watch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/16/2010 Daily Report Page 1 of 1 ENI Petroleum Ul EPOCH Nikaitchuq DAILY WELLSITE REPORT OP05-06 REPORT FOR S.Beauchamp/D.Smith/A.Buchanan DATE Aug 16,2010 DEPTH 2425' PRESENT OPERATION Drilling Out TIME 24:00:00 YESTERDAY 2425' 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2425' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2425.00 50.94 82.99 2194.53 SURVEY DATA 2347.28 50.94 82.99 2145.65 2228.30 44.45 83.18 2065.61 2132.12 39.79 83.43 1994.29 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 121/4" Hughes QD605X 7022287 4x16,3x13 2425' - 0' 0 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA NA @ NA NA NA FT/HR SURFACE TORQUE NA @ NA NA @ NA NA NA AMPS WEIGHT ON BIT NA @ NA NA @ NA NA NA KLBS ROTARY RPM NA @ NA NA @ NA NA NA RPM PUMP PRESSURE NA @ NA NA @ NA NA NA PSI DRILLING MUD REPORT DEPTH 2425' MW 9.5 VIS - PV 13 YP 6 FL - Gels 1/1/2 CL- - FC - SOL - SD - OIL - MBL - pH 8.0 Ca+ - CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS NA @ NA NA @ NA NA TRIP GAS 0 CUTTING GAS NA @ NA NA @ NA NA WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) NA @ NA NA @ NA NA CONNECTION GAS HIGH 0 ETHANE(C-2) NA @ NA NA @ NA NA AVG 0 PROPANE(C-3) NA @ NA NA @ NA NA CURRENT 0 BUTANE(C-4) NA @ NA NA @ NA NA CURRENT BACKGROUND/AVG 0 PENTANE(C-5) NA @ NA NA @ NA NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION • LITHOLOGY Claystone,Sand PRESENT LITHOLOGY Claystone 70%,Sand 30% DAILY ACTIVITY Finish nipple up BOP and run BOP test.Pick up BHA#3 and run in hole.Perform shallow test at 1040'.Cut and slip drill line and service top drive.Run in hole to 2250'and successfully test SUMMARY casing pressure to 2500 psi for 30 minutes.Run in hole and tag plug.Drill on plug as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;Rig Watch -$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTSWIY WEL... 8/17/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT OP05-06 REPORT FOR S.Beauchamp/D.Smith/A.Buchanan DATE Aug 17,2010 DEPTH 4388' PRESENT OPERATION Drilling TIME 24:00:00 YESTERDAY 2425' 24 HOUR FOOTAGE 1963' CASING INFORMATION 20"@ 160' 13 3/8"@ 2415' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4410.25 76.88 73.75 2813.77 SURVEY DATA 4314.08 77.25 70.63 2792.24 4217.61 77.2 72.88 2770.9 4122.34 77.11 76.93 2749.71 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 121/4" Hughes OD605X 7022287 4x16,3x13 2425' - 1963' 12:44:43 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 362.2 @ 3244.00000 27.4 @ 2426.00000 214.4 0.00000 FT/HR SURFACE TORQUE 14923 @ 3842.00000 2562 @ 2487.00000 6019.4 0.00000 AMPS WEIGHT ON BIT 20 @ 2425.00000 0 @ 2589.00000 7.2 0.00000 KLBS ROTARY RPM 150 @ 3774.00000 42 @ 2425.00000 117.9 0.00000 RPM PUMP PRESSURE 1652 @ 4325.00000 519 @ 2661.00000 12023 0.00000 PSI ' DRILLING MUD REPORT DEPTH 4388' MW 9.0 VIS - PV 7 YP 21 FL 6.2 Gels 9/14/16 CL- 500 FC 1/- SOL 4.5 SD 0.05 OIL 3/93 MBL 3.5 pH 9.5 Can 60 CCI - MWD SUMMARY INTERVAL 2425'TO 4388' TOOLS Gamma,Resistivity GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 187 @ 2996.00000 0 @ 2427.00000 51.9 TRIP GAS 0 CUTTING GAS 0 @ 4388.00000 0 @ 4388.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 37406 @ 2996.00000 73 @ 2427.00000 10902.4 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 4388.00000 0 @ 4388.00000 0.0 AVG 0 PROPANE(C-3) 0 @ 4388.00000 0 @ 4388.00000 0.0 CURRENT 0 BUTANE(C-4) 0 @ 4388.00000 0 @ 4388.00000 0.0 CURRENT BACKGROUND/AVG 33/45 PENTANE(C-5) 0 @ 4388.00000 0 @ 4388.00000 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 60%,Sandstone 40% DAILY ACTIVITY SUMMARY Drilled out of shoe and made new hole to 2450'.Displaced mud.Performed LOT to a value of 11.0EMW.Drilled ahead with no issues to current depth as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch -$1450 REPORT BY Z. Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/18/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT PI OP05-06 REPORT FOR S.Beauchamp/D.Smith/A.Buchanan DATE Aug 18,2010 DEPTH 6250' PRESENT OPERATION Drilling TIME 24:00:00 YESTERDAY 4388' 24 HOUR FOOTAGE 1862' CASING INFORMATION 20"@ 160' 13 3/8"@ 2415' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6230.38 76.07 75.28 3211 SURVEY DATA 6133.92 77.24 75.53 3188.73 6038.13 77.12 76.57 3167.48 5942.37 77.01 76.34 3146.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 121/4" Hughes QD605X 7022287 4x16,3x13 2425' - 3825' 34.5 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 296.1 @ 4487.00000 9.7 @ 4952.00000 164.2 169.64464 FT/HR SURFACE TORQUE 12860 @ 5887.00000 4863 @ 4475.00000 8527.5 9224.71680 AMPS WEIGHT ON BIT 18 @ 6208.00000 0 @ 5634,00000 9.4 7.03777 KLBS ROTARY RPM 148 @ 4537.00000 58 @ 4950.00000 129.1 121.15932 RPM PUMP PRESSURE 2214 @ 6162.00000 1125 @ 4400.00000 1923.6 2157.25317 PSI DRILLING MUD REPORT DEPTH 6250' MW 9.2 VIS - PV 13 VP 22 FL 5.6 Gels 9/24/31 CL- 1000 FC 1/- SOL 7 SD 0.1 OIL 3/90 MBL 12 pH 92 Car. 60 CCI - MWD SUMMARY INTERVAL 2425'TO 6250' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 427 @ 6246.00000 7 @ 5350.00000 58.7 TRIP GAS 0 CUTTING GAS 0 @ 6250.00000 0 @ 6250.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 94517 @ 6245.00000 1401 @ 5350.00000 12644.9 CONNECTION GAS HIGH 36 ETHANE(C-2) 0 @ 6250.00000 0 @ 6250.00000 0.0 AVG 0 PROPANE(C-3) 0 @ 6250.00000 0 @ 6250.00000 0.0 CURRENT 1 BUTANE(C-4) 0 @ 6250.00000 0 @ 6250.00000 0.0 CURRENT BACKGROUND/AVG 34/50 PENTANE(C-5) 0 @ 6250,00000 0 @ 6250.00000 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Sandstone PRESENT LITHOLOGY Sand 60%,Sandstone 40% DAILY ACTIVITY SUMMARY Drill ahead without any issues.Max gas of 427 units at depth of 6246'.Continueing to drill ahead as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML-$3045;RigWatch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/19/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT OP05-06 REPORT FOR S.Beauchamp/D.Smith/A.Buchanan DATE Aug 19,2010 DEPTH 6878' PRESENT OPERATION POOH TIME 24:00:00 YESTERDAY 6250' 24 HOUR FOOTAGE 628' CASING INFORMATION 20"@ 160' 13 3/8"@ 2415' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6742.31 73.25 71.44 3343.78 SURVEY DATA 6709.49 73.16 7128 3334.30 6614.72 74.65 70.88 3308.03 6519.47 74.55 71.98 3282.73 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" Hughes OD605X 7022287 4x16,3x13 2425' 6878' 4453' 44.5 - Steering Tool DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 389.6 @ 6596.00000 8.4 @ 6832.00000 139.7 6828492 FT/HR SURFACE TORQUE 18264 @ 6787.00000 6144 @ 6733.00000 9003.2 0.00000 AMPS WEIGHT ON BIT 26 @ 6875.00000 0 @ 6676.00000 7.6 26.95561 KLBS ROTARY RPM 134 @ 6660.00000 55 @ 6506.00000 109.8 0.00000 RPM PUMP PRESSURE 2220 @ 6687.00000 9 @ 6878.00000 1980.3 9.03855 PSI DRILLING MUD REPORT DEPTH 6878' MW 9.1 VIS - PV 12 YP 20 FL 5.9 Gels 9/16/22 CL- 1100 FC 1/- SOL 5.5 SD 0.2 OIL 3/92 MBL 12 pH 9.4 Caa 60 CCI - MWD SUMMARY INTERVAL 2425'TO 6878' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 405 @ 6256.00000 1 @ 6735.00000 91.7 TRIP GAS 0 CUTTING GAS 0 @ 6878.00000 0 @ 6878.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 96378 @ 6411.00000 233 @ 6735.00000 187032 CONNECTION GAS HIGH 48 ETHANE(C-2) 8 @ 6518.00000 0 @ 6568.00000 0.2 AVG 35 PROPANE(C-3) 0 @ 6878.00000 0 @ 6878.00000 0.0 CURRENT 0 BUTANE(C-4) 23 @ 6518.00000 0 @ 6568.00000 0.7 CURRENT BACKGROUND/AVG 0/16 PENTANE(C-5) 0 @ 6878.00000 0 @ 6878.00000 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand PRESENT LITHOLOGY Sand 100% DAILY ACTIVITY Drilled ahead from 6250'to 6878'.Ran into directional issues.Began pulling out of hole.Ran into a couple tight spots around 4670'md.Began backreaming to shoe.Continue to pull out SUMMARY of hole as of report. EPOCH PERSONNEL ON BOARD 4 DAILY COST DMI-$3045;RigWatch-$1450 REPORT BY Z.Beekman file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 8/20/2010 m 0 2 0) 0 r 0 CO 0, OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format.