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Home My WebLink About211-0581. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: __ESP Changeout_ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 22,370 feet N/A feet true vertical 3,784 feet N/A feet Effective Depth measured 21,740 feet N/A feet true vertical 3,868 feet N/A feet Perforation depth Measured depth 13,195-22,370 feet True Vertical depth 3,929-3,868 feet Tubing (size, grade, measured and true vertical depth)2-7/8"L-80 9,915' 3,532' 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: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Schrader Bluff 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: Authorized Name and Giorgio Iannucci Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Well Operations Project Manager Contact Phone: 20"0 5210 6890 slotted 154 2163 3847 3671Production Liner 10440 11127 Casing Structural 10440 21325 9.625 5.5 Length 160 2324 20" 13.375 2324 Conductor Surface Intermediate 13.375 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 0355024, 0373301, 0388583, 0390616, 0391283 Nikaitchuq Schrader Bluff Eni US Operating Co. Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 211-058 50-029-23448-00-00 Size 154 measured TVD Plugs Junk measured Burst Collapse 9.625 5.5 3700 Centerpoint Dr. Ste. 500, Anchorage, AK, 99503 3. Address: OP09-S1 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 177 Gas-Mcf MD 26 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 1142 015 418 324-259 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 34 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 2041806 200 Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3300 N/A p k ft t Fra O s 211 6.A G L PG , _ Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov rgio Iannucci By Grace Christianson at 8:08 am, Jun 28, 2024 DSR-7/8/24 RBDMS JSB 070324 2-7/8" 6.4# L80 W563 Production TubingHAL 5-½” Oil Swell Packer2-7/8” x-cplg cable clamps, for ESP Power Cable, (2) 3/8" Chem Line FlatpackOP09-S1Dual Lateral Producer with ESP LiftNikaitchuq Field- Oliktok Point5-½” Silver Bullet Ecc. Nose Guide ShoeAs CompletedJune 2024 Interm. Casing 9-5/8", 40#13,195' MD, 3,929' TVD86º Inc.Slotted Liner,5-½” 15.5 - 17 ppf21,740' MD, 3,868' TVD93º Inc.12,986' MD, 3,908 TVDBaker SLXP Liner Hanger/PackerSurf. Casing13-3/8", 68 # 2,325' MD, 2,159' TVD42º Inc.XN-Nipple: 9868'' MD, 82º Inc12,674' MD, 3,873' TVDL1 - Baker SLXP LH/PKRAs tagged during last WO5-½” Silver Bullet Ecc. Nose Guide Shoe with Bent JointHAL 5-½” Oil Swell Packer12,827-12,843 MD, Casing Exit WindowSlotted Liner,5-½” 15.5 ppf21,460' MD, 3,860' TVD91º Inc.Packer MD(ft)SwellPacker#1 20,075SwellPacker#2 19,685SwellPacker#3 18,110SwellPacker#4 17,280SwellPacker#5 15,545SwellPacker#6 14,43551/2"SwellPkrͲMainBore9917' MD / 3532' TVD Discharge Gauge9918' MD / 3532' TVD Pump 2 Flex 279935' MD / 3535' TVD Pump 19945' MD / 3536' TVD Gas Separator 538GS9951' MD / 3537' TVD Intake9952' MD / 3537' TVD Upper Seal9959' MD / 3538' TVD Lower Seal9965' MD / 3539' TVD Motor 562XP9982' MD / 3542' TVD Intake Gauge9985' MD / 3542' TVD Chem Injection Centralizer9988' MD / 3543' TVD Shroud Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 5/21/2024 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) 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 Temperature (°F) 29.8 Wind NE @ 15 MPH Days LTI (days) 2,448.00 Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Berm containment around rig. Spot cuttings tank and highline skid. Swap rig over to highline power. Fill mud pits with 8.6 PPG brine. Bullhead tubing and A-Annulus with 8.6 PPG 3% KCl/NaCl brine inhibited with biocide. Install BPV and nipple down Xmas tree. Nipple up BOPE. 24h Summary Secure BOPE stack, kill, and choke lines in BOPE enclosure. Orient walker feet to pull off OP18-08. Lay herculite and mats for OP09-S1. Rig down secondary containment around the rig. Walk rig to OP09-S1 and center over well. Berm containment around rig. Pick up rig mats from rig move. Operation at 07.00 Filling mud pits with 8.6 PPG brine. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 W.O. A 1 P Complete passport test at OP18-08 and final ESP cable electrical integrity test. Clean mud pits. Prepare to move rig to OP09- S1. Hand well over to Production group. 12:00 17:00 5.00 17.00 W.O. A 1 P Prepare to move rig to OP09-S1. Secure BOPE stack, kill, and choke lines in BOPE enclosure. Orient walker feet to pull off OP18-08. Lay herculite and mats for OP09-S1. Rig down secondary containment around the rig. 17:00 23:00 6.00 23.00 W.O. A 2 P Walk rig to OP09-S1 and center over well. 23:00 00:00 1.00 24.00 W.O. A 1 P Berm containment around rig. Pick up rig mats from rig move. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jon Castle Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 5/22/2024 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) 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 Temperature (°F) 32.2 Wind NE @ 15 MPH Days LTI (days) 2,449.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Monitor well. Install BPV and nipple down X-mas tree. Nipple up BOPE. Test BOPE as per AOGCC requirements with 2-7/8” and 4” test joints. 24h Summary Berm containment around rig. Pick up rig mats from rig move. Spot cuttings tank and high line skid. Fill mud pits with 8.6 PPG brine. Perform crane lift to install empty Baker Centrilift capillary spool and empty ESP spool for de-complete on rig. Bullhead tubing and A-Annulus with 8.6 PPG 3% KCl/NaCl brine inhibited with biocide. Operation at 07.00 Nipple down tree, nipple up BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:30 5.50 5.50 W.O. A 1 P Continue to berm around rig. Ensure all landings and egress are clear of obstructions and secure. Continue picking up rig mats. Build containment and spot cuttings box. Spot high-line utility trailer and tie into rig. Change out suction rubbers in pill pits #1 and #2. 05:30 12:00 6.50 12.00 W.O. A 20 P Bring on 8.6 PPG 3 percent KCL brine to rig mud pits for bullhead operations. Rig up hoses to kill the well. Perform crane lift to remove partial Baker Centrilift flat pack capillary spool, and partial ESP spool for de-complete. 12:00 15:00 3.00 15.00 W.O. A 20 P Continue taking on brine to the rig mud pits. Pull high-line cable to high-line breaker module and terminate. Install shaker screens and prime #1 & #2 mud pumps. Pressure test lines for bullhead to 3,500 PSI. for 5 minutes (good test). 15:00 16:00 1.00 16.00 W.O. A 1 P Perform crane lift to install empty Baker Centrilift flat pack capillary spool, and empty ESP spool for de-complete. 16:00 00:00 8.00 24.00 W.O. L 9 P Bullhead 97 BBLS down the tubing @ 1.3 BBLS/minute tubing = 400 PSI, IA = 200 PSI, OA = 252 PSI. Shut in and tubing = 0 PSI, IA = 252 PSI, OA = 200 PSI. Line up and bullhead 1,130 BBLS down the IA @ 3 BBLS/minute IA = 270 PSI, tubing = -12 PSI, OA = 120 PSI. Shut in and tubing = 3 PSI, IA = 178 PSI, OA = 420 PSI. Note: 24 Hour Loss of 8.6 ppg Brine = 1,227 BBLs Total Loss of 8.6 ppg Brine = 1,227 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jon Castle Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 5/23/2024 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) 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 Temperature (°F) 30.9 Wind NE @ 14 MPH Days LTI (days) 2,450.00 Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast Continue testing BOPE as per AOGCC requirements with 2-7/8” and 4” test joints. Pull BPV from tubing hanger. Rig up GBR equipment and Baker Centrilift. Unseat tubing hanger. Pull out of hole laying down 2- 7/8” upper completion string. 24h Summary Bleed A Annulus down from 178 PSI to 0 PSI. Install BPV and nipple down X-mas tree. Nipple up BOPE. Start testing BOPE as per AOGCC requirements with 4” test joint. Operation at 07.00 Pull hanger to the rig floor. Disconnect ESP cable from penetrator and flat pack from hanger. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. L 1 P Bleed A Annulus down from 178 PSI to 2 PSI. Tubing -12 PSI. Loading 4” drill pipe in pipe shed and obtain measurements. 06:00 13:30 7.50 13.50 W.O. L 1 P Continue bleeding A Annulus down from 2 PSI to 0 PSI. Tubing -4 PSI. 13:30 15:00 1.50 15.00 W.O. C 5 P Install back pressure valve. Nipple down tree. Continue loading pits and upright tanks with brine. 15:00 19:30 4.50 19.50 W.O. C 20 P Install riser and Vault representative torqued riser Greylock to wellhead. Nipple up 13-5/8” 5M single and double ram BOP with 2-7/8” x 5” variable rams installed. Torque 13-5/8” 5M double ram and single ram BOP bolts. Install choke and HCR valves on BOPs and torque same. Grease valves and function test. Pressure up accumulator and function test control lines. Install turn buckles and center BOPs with rotary table. 19:30 23:00 3.50 23.00 W.O. C 5 P Install 4” test joint and blanking plug crossover with Vault representative. Rig up testing equipment. Fluid pack BOP and purge air from lines. 23:00 00:00 1.00 24.00 W.O. C 12 P Perform BOPE test #1 and #2 as per AOGCC requirements with 4” test joint, 250 PSI low and 3500 PSI high for 5 minutes each test and charted. Good test. Test Annular BOP with 4” test joint, 250 PSI low and 3000 PSI high for 5 minutes each test and charted. Good test. Witness Waived by AOGCC rep Kam StJohn. Note: 24 Hour Loss of 8.6 ppg Brine = 20 BBLs Total Loss of 8.6 ppg Brine = 1,247 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jon Castle Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 5/24/2024 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) 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 Temperature (°F) 28.9 Wind NE @ 7 MPH Days LTI (days) 2,451.00 Days RI (days) POB 54.0 Daily Summary Operations 24h Forecast Pull out of hole laying down 2-7/8” upper completion string. Prepare for VACS and casing scraper clean out run. 24h Summary Continue testing BOPE as per AOGCC requirements with 2-7/8” and 4” test joints. Pull BPV from tubing hanger. Rig up GBR equipment and Baker Centrilift. Unseat and pull tubing hanger to rig floor. Bullhead 790 BBLs down the A-Annulus. Pull out of hole laying down 2-7/8” upper completion string from 12,588’ to 9,338’. Operation at 07.00 Pulling out of hole with 2-7/8" upper completion string. 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. C 12 P Test BOPE as per AOGCC requirements with 2-7/8” and 4” test joints, 250 PSI low and 3500 PSI high for 5 minutes each test and charted. Good test. Test Annular BOP with 2-7/8” test joint, 250 PSI low and 3000 PSI high for 5 minutes each test and charted. Good test. Test gas alarms and PVT alarms. Good test. Perform accumulator drawdown test with starting pressure of 3000 PSI, 2150 PSI after function, 200 PSI recovery 26 seconds, with full recovery at 71 seconds. N2 bottle average 4 at 2656 PSI. Good test. Witness Waived by AOGCC rep Kam StJohn. 03:30 04:30 1.00 4.50 W.O. C 1 P Rig down test equipment. Lay down test joint with blanking plug. Pull BPV with Vault representative. 04:30 05:30 1.00 5.50 W.O. L 1 P Rig up GBR power tongs and Baker Centrilift. Makeup FOSV to crossover sub. 05:30 07:30 2.00 7.50 W.O. L 20 P Pick up the landing joint and make it up to the tubing hanger. Make a top drive connection. Verify tubing and A-annulus is 0 PSI. Back out upper lock down screws and pull tubing hanger to the rig floor. Unseat hanger = 105 K, UW = 95 K. Remove dual capillary lines and disconnect ESP from penetrator. 07:30 08:30 1.00 8.50 W.O. C 20 TR05 Attempt to obtain hot work permit to test ESP. Unacceptable level of LEL on handheld gas monitor at rotary table. Fill A- annulus with 100 BBLS of brine. Pipe spaced out, FOSV made up to tubing and closed, 2-7/8” x 5” variable upper pipe rams closed. 08:30 10:30 2.00 10.50 W.O. L 1 P Monitor pressures. Shut in tubing pressure 0 PSI. Shut in A-annulus 5 PSI. Bring on 8.6 PPG brine to the rig mud pits to perform bullhead operations. 10:30 16:00 5.50 16.00 W.O. L 9 P Bullhead down the A-annulus @ 5 BBL/minute 100 PSI. Caught pressure with 2,340 strokes pumped. Bullhead 790 total BBLS down the A-annulus @ 5 BBL/minute initial circulating pressure = 100 PSI. Final circulating pressure = 200 PSI 2,340 stroke pumped. Shut down pumps and monitor pressure. Tubing = 0 PSI, A-annulus = 0 PSI. Line up to poor boy degasser and open FOSV and upper pipe rams. 16:00 00:00 8.00 24.00 W.O. L 4 P Pull out of hole laying down 2-7/8” upper completion string from 12,588’ to 9,338’, 82K UW. Thread rep witnessed breaking down. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide plus pipe displacement. Note: 24 Hour Loss of 8.6 ppg Brine = 1,072 BBLs Total Loss of 8.6 ppg Brine = 2,319 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jon Castle Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 5/25/2024 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) 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 Temperature (°F) 28.0 Wind W @ 5 MPH Days LTI (days) 2,452.00 Days RI (days) POB 55.0 Daily Summary Operations 24h Forecast Pull out of hole laying down ESP assembly. Rig down and demobilize Baker Centrilift equipment. Remove ESP spool and dual flat pack capillary line spool from rig floor. Re-test 2-7/8” X 5” variable upper pipe rams with 2-7/8” and 4” test joint. Prepare for VACS and casing scraper clean out run. 24h Summary Pull out of hole laying down 2-7/8” upper completion string from 9,338’ to 7,481’. Clean rig floor in preparation of ESP reel swap. Change out ESP spools using Worley crane. Continue pulling out of hole laying down 2-7/8” upper completion string from 7,484’ to 81’. Operation at 07.00 Testing 2-7/8” X 5” variable upper pipe rams with 2-7/8” and 4” test joint. 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. L 4 P Pull out of hole laying down 2-7/8” upper completion string from 9,338’ to 7,484’, 75K UW. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide plus pipe displacement. Superior thread representative inspecting threads on box and pin ends on 2-7/8” tubing. 04:30 07:00 2.50 7.00 W.O. L 1 P Clean rig floor in preparation of ESP reel swap. Held lift meeting and pre job safety meeting with rig crew, Worley, Eni safety, and production. Obtain permit to work. Change out ESP spools using Worley crane. Secure new spool on rig floor. 07:00 00:00 17.00 24.00 W.O. L 4 P Continue pulling out of hole laying down 2-7/8” upper completion string from 7,484’ to 81’, 58K UW. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide plus pipe displacement. Superior thread representative inspecting threads on box and pin ends on 2-7/8” tubing. Seven joints total did not pass inspection on threads. Note: 24 Hour Loss of 8.6 ppg Brine = 261 BBLs Total Loss of 8.6 ppg Brine = 2,580 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jon Castle Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 5/26/2024 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) 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 Temperature (°F) 33.4 Wind NE @ 22 MPH Days LTI (days) 2,453.00 Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast Pick up Baker BHA #1, 7-3/8” polish mill, casing scraper, string magnets, and VACs tool assembly. Run in hole picking up 4” drill pipe from pipe shed to SLXP liner top at 12,674’ MD. 24h Summary Pull out of hole laying down ESP assembly. Remove ESP spool and dual flat pack capillary line spool from rig floor. Rig down and demobilize Baker Centrilift equipment. Re-test 2-7/8” X 5” variable upper pipe rams with 2-7/8” and 4” test joint. Load pipe shed with 4” drill pipe and heavy weight drill pipe. Pick up Baker BHA #1, 7-3/8” polish mill and VACs tool assembly. Operation at 07.00 Run in hole with BHA #1 picking up 4” drill pipe from pipe shed. 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. L 4 P Pull out of hole laying down ESP assembly from 81’ to surface. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide plus pipe displacement. Recovered 416 – 2 7/8" cross collar clamps, 1 – 2 7/8" MLE splice clamp, 1 – 2 7/8" cable to cable splice clamp, 1 – 4 1/2" cross collar clamp, and 1 – 4 1/2" half clamp. Test dual flat pack capillary line to 3000 PSI for 15 minutes each line, good test. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine. 04:30 06:00 1.50 6.00 W.O. L 1 P Clean and organize rig floor. Held pre job safety meeting with rig crew, Worley, and production. Obtain permit to work. Remove ESP spool and dual flat pack capillary line spool from rig floor. Rig down and demobilize Baker Centrilift equipment. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine. 06:00 07:30 1.50 7.50 W.O. L 1 P Clean and clear rig floor and pipe shed of 2-7/8” tubing and handing/inspection equipment. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine. 07:30 15:30 8.00 15.50 W.O. C 12 P Test upper pipe 2-7/8” X 5” variable upper pipe rams with 2-7/8” and 4” test joints to 250 PSI low and 3,500 PSI high for 5 charted minutes. Upper pipe rams fail due to upper pipe ram & lower pipe ram door seals leaking. Replace door seals and retest, good test. Monitor well on A-annulus. 15:30 17:00 1.50 17.00 W.O. C 20 P Rig down and blow down testing equipment. Pull test plug and lay down test joint. Install wear bushing with Vault representative. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine. 17:00 23:00 6.00 23.00 W.O. M 1 P Load pipe shed with 4” drill pipe and heavy weight drill pipe. Mobilize BHA #1 tools to rig floor. Change out handling tools and measure pipe elevators. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine. 23:00 00:00 1.00 24.00 W.O. M 1 P Pick up Baker BHA #1, 7-3/8” polish mill and VACs tool assembly. Note: 24 Hour Loss of 8.6 ppg Brine = 244 BBLs Total Loss of 8.6 ppg Brine = 2,824 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jon Castle Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 5/27/2024 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) 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 Temperature (°F) 34.5 Wind NE @ 12 MPH Days LTI (days) 2,454.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Pull out of hole laying down BHA #1, VACs tool assembly with polish mill. Load pipe shed with 32 joints of 2-7/8” PH-6 tubing and measure. Run in hole with Baker BHA #2; 1,000’ of 2-7/8” snorkel pipe, VACs tool, string magnets, LBS, and oil jars to clean out 5½” L1 lateral. Pull out of the hole laying down the 4” drill pipe. 24h Summary Pick up Baker BHA #1: 7-3/8” polish mill, 9-5/8” casing scraper, string magnets, VACs tool, LBS, and oil jars. Run in hole picking up 4” drill pipe from 140.74’ to 12,674’. Polish SLXP LH at 12,674’ MD. Pull out of hole with VACs tool assembly and polish mill from 12,674’ to 140’. Pull out of hole laying down BHA #1, VACs tool assembly with polish mill. Operation at 07.00 Make up Baker BHA #2; 1,000’ of 2-7/8” snorkel pipe, VACs tool. 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. M 20 P Pick up Baker BHA #1, 7-3/8” polish mill, casing scraper, string magnets, VACs tool, LBS, and oil jars to 140.74’. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine. 02:00 12:00 10.00 12.00 W.O. M 4 P Run in hole picking up 4” drill pipe from 140.74’ to 10,703’ drifting each joint. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine. 12:00 14:30 2.50 14.50 W.O. M 4 P Continue running in the hole picking up 4” drill pipe from 10,703’ to 12,611’ drifting each joint. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine. 14:30 16:30 2.00 16.50 W.O. M 9 P Obtain parameters with UW = 129K, DW = 87K, rotating weight = 103K, RPM = 20, Torque = 4-5k FT LBS. Engage rig pumps and pump a tubing volume at 5 BBL/minute, 65 PSI. Pump in the hole and locate liner top at 12,674’ set down 10K. Polish and scrape by reciprocating with pumps from 12,674’ to 12,624’ (12,586’ to 12,536’ scraper depths) 5 times. 16:30 22:30 6.00 22.50 W.O. M 4 P Pull out of the hole on elevators racking back drill pipe in the derrick from 12,624’ to 140’. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine plus pipe displacement. 22:30 00:00 1.50 24.00 W.O. M 4 P Pull out of hole laying down BHA #1, VACs tool assembly with polish mill. Recovered 15 LBS of fine metal shavings on string magnets. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine plus pipe displacement. Note: 24 Hour Loss of 8.6 ppg Brine = 433 BBLs Total Loss of 8.6 ppg Brine = 3,257 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jon Castle Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 5/28/2024 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) 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 Temperature (°F) 34.2 Wind W @ 5 MPH Days LTI (days) 2,455.00 Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast Pull out of hole laying down drill pipe with VACs tool assembly and 2-7/8” snorkel pipe from 7,978’ to surface. Load pipe shed with 2-7/8” upper completion string and process. 24h Summary Pull out of hole laying down BHA #1, VACs tool assembly with polish mill. Load pipe shed with 32 joints of 2-7/8” PH-6 tubing and measure. Run in hole with Baker BHA #2; 998’ of 2-7/8” snorkel pipe, VACs tool, string magnets, LBS, and oil jars to clean out 5-1/2” L1 lateral. Pull out of hole laying down drill pipe with VACs tool assembly and 2-7/8” snorkel pipe from 13,680’ to 7,978’. Operation at 07.00 Laying down drill pipe with VACs tool assembly and 2-7/8” snorkel pipe at 2731'. 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. L 4 P Pull out of hole laying down BHA #1, VACs tool assembly with polish mill. No recovery in VACs tool. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine plus pipe displacement. 01:00 04:00 3.00 4.00 W.O. L 1 P Clean and organize rig floor. Load pipe shed with 32 joints of 2-7/8” PH-6 tubing and measure. Rig up GBR power tongs. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine. 04:00 07:30 3.50 7.50 W.O. L 4 P Run in the hole with Baker BHA #2: 998’ of 2-7/8” snorkel pipe, VACs tool, string magnets, LBS, and oil jars to 1,120.07’. Rig down GBR power tongs. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine. 07:30 12:00 4.50 12.00 W.O. L 4 P Run in the hole with Baker BHA #2, from 1,120’ to 10,647’. UW = 113 K, SO = 75 K Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine. 12:00 12:30 0.50 12.50 W.O. L 25 P Service rig. Grease ST-80 and inspect handling tools on rig floor. 12:30 13:30 1.00 13.50 W.O. L 4 P Run in the hole with Baker BHA #2, from 10,647’ to 12,627’. UW = 115 K, SO = 76 K. 13:30 18:30 5.00 18.50 W.O. L 9 P Wash in the hole with Baker BHA #2, from 12,627’ to 13,680’ with 5 BBLS/minute, 1,130 PSI, UW = 115 K, SO = 76 K. Pumped 268 total BBLS. Pump 25 BBL deep clean pill due to crude on drill pipe @ 5 BBLS/minute. Prepare pipe shed to lay down drill pipe. 18:30 00:00 5.50 24.00 W.O. L 4 P Pull out of hole laying down drill pipe with VACs tool assembly and 2-7/8” snorkel pipe from 13,680’ to 7,978’. Offload pipe shed after filling bottom row of drill pipe. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine plus pipe displacement. Note: 24 Hour Loss of 8.6 ppg Brine = 467 BBLs Total Loss of 8.6 ppg Brine = 3,724 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE erik.bohlen@external.eni.com Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Nathan Woods Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Derek Sutherland Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 5/29/2024 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) 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 Temperature (°F) 34.5 Wind W @ 10 MPH Days LTI (days) 2,456.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Load pipe shed with 2-7/8” upper completion string and process. 24h Summary Pull out of hole laying down drill pipe with VACs tool assembly and 2-7/8” snorkel pipe from 7,978’ to surface. Palletize Baker tools and demobilize from pipe shed. Offload 2-7/8” PH6 tubing from pipe shed. Load pipe shed with 2-7/8” upper completion string and process. Operation at 07.00 Loading and processing 2-7/8" upper completion tubing. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 10:00 10.00 10.00 W.O. M 4 P Pull out of hole laying down drill pipe with VACs tool assembly and 2-7/8” snorkel pipe from 7,978’ to 1,120’. Offload pipe shed after filling bottom row of drill pipe. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine plus pipe displacement. 10:00 15:00 5.00 15.00 W.O. M 20 P Lay down Baker VACs tool assembly. Rig up GBR power tongs. Pull out of hole laying down 2-7/8” snorkel pipe. No sand recovery. Rig Down GBR power tongs. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine plus pipe displacement. 15:00 19:00 4.00 19.00 W.O. M 1 P Palletize Baker tools and demobilize from pipe shed. Offload 2-7/8” PH6 tubing from pipe shed. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine plus pipe displacement. 19:00 00:00 5.00 24.00 W.O. K 1 P Load pipe shed with 2-7/8” upper completion string and process. Drift each joint with 2.347” drift. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine plus pipe displacement. Note: 24 Hour Loss of 8.6 ppg Brine = 260 BBLs Total Loss of 8.6 ppg Brine = 3,984 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE erik.bohlen@external.eni.com Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Nathan Woods Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Derek Sutherland Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 5/30/2024 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) 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 Temperature (°F) 30.4 Wind WN @ 7 MPH Days LTI (days) 2,457.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Change out upper ram door seals on BOPs. Test BOPE with 2-7/8” test joint as per AOGCC requirements. Rig up handling equipment to pick up new ESP completion. Run in hole with 2-7/8” upper completion string. 24h Summary Load pipe shed with 2-7/8” upper completion string and process. Pull wear bushing and install 2-7/8” test joint and test plug with Vault representative. Attempt to shell test BOPE, observed door seals leaking on upper pipe rams. Change out upper pipe ram door seals. 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 21:00 21.00 21.00 W.O. K 1 P Load pipe shed with 2-7/8” upper completion string and process. 420 joints total. Drift each joint with 2.347” drift. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl. 21:00 23:00 2.00 23.00 W.O. C 20 P Pre job safety meeting. Pull wear bushing and install 2-7/8” test joint and test plug with Vault representative. Rig up to test BOPE. Flood BOP stack and manifold lines. Attempt to shell test BOPE, observed door seals leaking on upper pipe rams. 23:00 00:00 1.00 24.00 W.O. C 25 TR05 Pre job safety meeting. Blowdown BOPs and change out upper pipe ram door seals. Note: 24 Hour Loss of 8.6 ppg Brine = 249 BBLs Total Loss of 8.6 ppg Brine = 4,233 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE erik.bohlen@external.eni.com Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Nathan Woods Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Derek Sutherland Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 5/31/2024 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) 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 Temperature (°F) 32.0 Wind W @ 5 MPH Days LTI (days) 2,458.00 Days RI (days) POB 57.0 Daily Summary Operations 24h Forecast Rig up handling equipment to pick up new ESP completion. Run in hole with 2-7/8” upper completion string. 24h Summary Change out upper pipe ram door seals and 2-7/8” x 5” variable bore ram elements. Retorque bolts between lower pipe rams and riser spool. Achieve shell test to 3500 PSI. Perform BOPE as per AOGCC requirements with 2-7/8” test joint. Load Baker ESP equipment into pipe shed. Operation at 07.00 Picking up ESP assembly. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. C 25 TR05 Change out upper pipe ram door seals. Observed 2-7/8” x 5” variable bore ram elements were damaged. Changed out 2-7/8” x 5” variable bore ram elements. 04:00 06:30 2.50 6.50 W.O. C 25 TR05 Flood BOP stack and manifold lines. Attempt to shell test BOPE, observed kill line grey lock connection was leaking. Replaced Greylock rubber seal, hub, and bolts. 06:30 11:30 5.00 11.50 W.O. C 25 TR05 Attempt to shell test BOPE, observed door seals leaking on upper pipe rams. Blow down BOPs. Replace door seals on both sides of upper pipe rams. Flood BOP stack and manifold lines. 11:30 13:00 1.50 13.00 W.O. C 25 TR05 Attempt to shell test BOPE, observed flange between lower pipe rams and riser spool was leaking. Retorque bolts between lower pipe rams and riser spool. Achieve shell test to 3500 PSI. 13:00 17:00 4.00 17.00 W.O. C 12 P Perform weekly BOPE test as per AOGCC requirements with 2-7/8” test joint, 250 PSI low and 3500 PSI high for 5 minutes each test and charted, good test. Test Annular BOP with 2-7/8” test joint, 250 PSI low and 3000 PSI high for 5 minutes each test and charted, good test. Test gas alarms and PVT alarms, good test. Perform accumulator drawdown test with starting pressure of 3050 PSI, 2125 PSI after function, 200 PSI recovery in 27 seconds with full recovery in 79 seconds. N2 bottle average 4 at 2694 PSI. Witness Waived by AOGCC rep Guy Cook. 17:00 19:00 2.00 19.00 W.O. C 1 P Blow down lines and rig down test equipment. Lay down 2-7/8” test joint. Clean and organize rig floor. 19:00 00:00 5.00 24.00 W.O. K 1 P Held lift meeting and pre job safety meeting with rig crew, Worley, Eni safety, ENI lifting advisor, and production. Obtain permit to work. Place dual line flat pack capillary line spool and ESP spool on rig floor using Worley crane. Secure spools on rig floor. Load Baker ESP equipment into pipe shed. Note: 24 Hour Loss of 8.6 ppg Brine = 0 BBLs Total Loss of 8.6 ppg Brine = 4,233 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE erik.bohlen@external.eni.com Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jon Castle Nordic HSE 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 6/1/2024 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) 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 Temperature (°F) 34.0 Wind N @ 8 MPH Days LTI (days) 2,459.00 Days RI (days) POB 56.0 Daily Summary Operations 24h Forecast Run in hole with 2-7/8” upper completion ESP assembly. 24h Summary Rig up Baker Centrilift to run ESP completion string. Pick up ESP assembly and run in hole to 84’. Run in hole with 2-7/8” upper completion ESP string from 84’ to 3,504’. Perform electrical checks every 1,000’. Pump tubing capacity every 3,000’. Operation at 07.00 Run in hole with 2-7/8” upper completion ESP assembly at 6,000'. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 10:00 10.00 10.00 W.O. K 20 P Rig up Baker Centrilift to run ESP completion string. Pick up and run 7-5/8” motor shroud into the hole. Pick up ESP pump assembly, service ESP motor, seal assembly, and pump. Manually verified free shaft rotation after assembly was made up. Install dual line capillary tubing and test connections, good test. Fill A-Annulus with 10 BPH of 8.6 PPG KCL/NaCl brine. 10:00 12:30 2.50 12.50 W.O. K 20 P Splice motor lead to ESP cable, witnessed by ENI electrician. Test motor lead and ESP cable, good test. Install shroud bushing. Make up ESP assembly and run in hole to 84.25’. Rig up GBR power tongs. Fill A-Annulus with 10 BPH of 8.6 PPG KCL/NaCl brine. 12:30 00:00 11.50 24.00 W.O. K 4 P Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 upper completion ESP string from 84.25’ to 3,504’, 64K UW, 60K DW. Torque turn each connection to 1900 FT/LBS torque. Superior thread representative inspected threads. Drift each joint to 2.347”. Perform electrical checks every 1000’, maintain 1282 PSI on dual capillary tubing while run in hole. Pump tubing capacity every 3,000’. Fill A-Annulus with 10 BPH of 8.6 PPG KCL/NaCl brine. Note: 24 Hour Loss of 8.6 ppg Brine = 232 BBLs Total Loss of 8.6 ppg Brine = 4,524 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE erik.bohlen@external.eni.com Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jon Castle Nordic HSE 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 6/2/2024 Report #: 13 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) 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 Temperature (°F) 30.9 Wind N @ 10 MPH Days LTI (days) 2,460.00 Days RI (days) POB 56.0 Daily Summary Operations 24h Forecast Run in hole with 2-7/8” upper completion ESP assembly. Land tubing hanger in wellhead. Nipple down BOPE and install X-mas tree. Perform Passport test. Rig down and prepare to move rig. 24h Summary Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 upper completion ESP string from 3,504’ to 9,001’. Performed ESP splice at 7,543’. Perform electrical checks every 1,000’. Pump tubing capacity every 3,000’. Operation at 07.00 Preparing to land hanger. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 W.O. K 4 P Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 upper completion ESP string from 3,504’ to 7,482’, 74K UW, 58K DW. Torque turn each connection to 1900 FT/LBS torque. Superior thread representative inspected threads. Drift each joint to 2.347”. Perform electrical checks every 1000’, maintain 1256 PSI on dual capillary tubing while run in hole. Pump tubing capacity every 3,000’. Fill A-Annulus with 10 BPH of 8.6 PPG KCL/NaCl brine. 12:00 14:30 2.50 14.50 W.O. K 1 P Held lift meeting and pre job safety meeting with rig crew, Worley, Eni safety, ENI lifting advisor, and production. Obtain permit to work. Change out ESP spools using Worley crane. Secure new spool on rig floor. Feed ESP cable over sheave in derrick and prepare for a splice. Fill A-Annulus with 10 BPH of 8.6 PPG KCL/NaCl brine. 14:30 16:30 2.00 16.50 W.O. K 4 P Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 upper completion ESP string from 7,482’ to 7,573’. Perform ESP cable to cable splice. Perform electrical check, good test. Witnessed by ENI electrician. Fill A-Annulus with 10 BPH of 8.6 PPG KCL/NaCl brine. ESP splice at 7,543’. 16:30 17:30 1.00 17.50 W.O. K 4 P Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 upper completion ESP string from 7,573’ to 7,916’. Torque turn each connection to 1900 FT/LBS torque. Superior thread representative inspected threads. ESP cable armor coating was pinched from air pipe slips while running in hole. 17:30 21:00 3.50 21.00 W.O. K 20 P Remove armor coating on ESP cable to inspect for damage. The outer lead coating of ESP cable showed no damage. Insulate and tape ESP cable. Wrap armor around ESP cable and perform electrical test, good test. 21:00 00:00 3.00 24.00 W.O. K 4 P Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 upper completion ESP string from 7,916’ to 9,001’, 74K UW, 58K DW. Torque turn each connection to 1900 FT/LBS torque. Superior thread representative inspected threads. Drift each joint to 2.347”. Perform electrical checks every 1000’, maintain 1166 PSI on dual capillary tubing while run in hole. Pump tubing capacity every 3,000’. Fill A-Annulus with 10 BPH of 8.6 PPG KCL/NaCl brine. Note: 24 Hour Loss of 8.6 ppg Brine = 241 BBLs Total Loss of 8.6 ppg Brine = 4765 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE erik.bohlen@external.eni.com Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jon Castle Nordic HSE 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 6/3/2024 Report #: 14 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) 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 Temperature (°F) 31.6 Wind N @ 12 MPH Days LTI (days) 2,461.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Nipple down BOPE and install X-mas tree. Perform Passport test and final ESP cable electrical integrity test. Prepare to move rig to OP26-DSP02. Hand well over to Production group. 24h Summary Run in hole with 2-7/8” upper completion ESP string from 9,001’ to 9,942’. ESP cable on reel was not long enough to reach planned depth of 10,116’. Make up tubing hanger and land tubing with bottom of shroud at 9,993.41’. Attempt to test upper and lower seals on hanger. Lower seals tested and upper seals failed to test. Replace tubing hanger and land tubing with bottom of shroud at 9,993.41’. Test upper and lower seals on hanger to 5K, good test. Lay down landing joint with Vault representative. Rig down GBR power tongs. Operation at 07.00 Nippling up tree. 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 Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 upper completion ESP string from 9,001’ to 9,942’, 83K UW, 56K DW. Torque turn each connection to 1900 FT/LBS torque. Superior thread representative inspected threads. Drift each joint to 2.347”. Perform electrical checks every 1000’, maintain 1203 PSI on dual capillary tubing while run in hole. Fill A-Annulus with 10 BPH of 8.6 PPG KCL/NaCl brine. 04:30 08:00 3.50 8.00 W.O. K 20 TD99 ESP cable on reel was not long enough to reach planned depth of 10,116’. Decision made to make up tubing hanger with swivel joint. Fill A-Annulus with 10 BPH of 8.6 PPG KCL/NaCl brine. 08:00 15:00 7.00 15.00 W.O. K 20 P Pick up landing joint. Make up tubing hanger and Tenaris swivel to the tubing string. Torque swivel bushing to 4,780 FT-LBS torque. Orient tubing hanger. Feed dual capillary lines thru hanger and connect. Test dual capillary lines, good test. Make ESP penetrator splice, witnessed by the ENI electrician. Perform electrical test on ESP cable, good test. Install PFT pig tail to hanger. 15:00 18:30 3.50 18.50 W.O. K 12 TS99 Run in the hole and land tubing with bottom of shroud at 9,993.41’, 83K UW, 56K DW. Run in lock down screws and attempt to test upper and lower seals on hanger to 5,000 PSI. Lower seals tested and upper seals failed to test. Note: Alignment issues were encountered with tubing hanger alignment before landing the tubing hanger. 18:30 22:30 4.00 22.50 W.O. K 20 TS99 Back out lock down screws with Vault representative. Pull tubing hanger to rig floor. Observed several gouge marks in tubing hanger across upper seals. Replace tubing hanger. Torque swivel bushing to 4,780 FT-LBS torque. Orient tubing hanger. Feed dual capillary lines thru hanger and connect. Test dual capillary lines, good test. Perform electrical test on ESP cable, good test. Install PFT pig tail to hanger. 22:30 23:30 1.00 23.50 W.O. K 20 P Run in the hole and land tubing with bottom of shroud at 9,993.41’, 83K UW, 56K DW. Run in lock down screws and test upper and lower seals on hanger to 5,000 PSI for 15 minutes, good test. 23:30 00:00 0.50 24.00 W.O. K 1 P Lay down landing joint with Vault representative. Rig down GBR power tongs. Note: 24 Hour Loss of 8.6 ppg Brine = 196 BBLs Total Loss of 8.6 ppg Brine = 4,961 BBLs Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE erik.bohlen@external.eni.com Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jon Castle Nordic HSE 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 6/4/2024 Report #: 15 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) 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 Temperature (°F) 31.8 Wind W @ 5 MPH Days LTI (days) 2,462.00 Days RI (days) POB 51.0 Daily Summary Operations 24h Forecast No Further Operations, Final Report for OP09-S1. 24h Summary Nipple down BOP and install X-mas tree. Perform passport test and final ESP checks with Baker Centrilift. Prepare to move rig and hand well over to Production group. Rig released from OP09-S1 at 2400 HRS on 6/04/2024. Final report. Operation at 07.00 Prep Rig Move OP26-DSP02. 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. C 12 P Bleed down accumulator. Nipple down the BOP and secure in the tow position. 03:30 07:00 3.50 7.00 W.O. C 12 P Terminate capillary lines. Pick up and install tree. Tighten Gray lock connections. Test the hanger void to 5000 psi for 10 minutes. Company man witnessed the test. 07:00 13:30 6.50 13.50 W.O. C 12 P Perform passport test with Vault representative as procedure, good test. Remove TWC from tubing hanger profile. Simultaneously demobilizing all Baker equipment from the rig floor with the Worley crane. 13:30 00:00 10.50 24.00 W.O. K 12 P Perform final checks on the ESP cable/motor electrical integrity, good test. Clean mud pits. Prepare to move rig and hand well over to Production group. Rig released from OP09-S1 at 2400 HRS on 6/04/2024. Final report. Note: 24 Hour Loss of 8.6 ppg Brine = 0 BBLs Total Loss of 8.6 ppg Brine = 4,961 BBLs Note: Final Report for OP09-S1. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Erik Bohlen ASRC Energy Services HSE erik.bohlen@external.eni.com Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jon Castle Nordic HSE 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 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 Changeout_ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Schrader Bluff 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 22370 N/A Casing Collapse Structural Conductor Surface 2480 Intermediate 4790 Production slotted Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Giorgio Iannucci Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 907-865-3300 Well Operations Project Manager OP09-S1 Schrader Bluff 3784 21740 3868 1011 N/A Proposed Pools: Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY Tubing Grade: Tubing MD (ft): N/A Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0355024, 0373301, 0388583, 0390616, 0391283 211-058 3700 Centerpoint Dr. Ste. 500, Anchorage, AK, 99503 50-029-23448-00-00 Eni US Operating Co. Inc. L80 TVD Burst 12,532' slotted MD 6890 5210 154 2159 3929 154 2325 38685.5 20" 13.375 160 9.62513162 2290 21740 Perforation Depth MD (ft): 13195 13,195-22,370 8754 3,929-3,868 Nikaitchuq Amjad Chaudhry 5/1/2024 May 8th, 2024 2-7/8" N/A amjad.chaudhry@eni.com m n P s 2 6 5 6 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Iannucci By Grace Christianson at 10:46 am, May 01, 2024 X 10-404 X SFD 5/3/2024 BOP test to 3000 psig Annular preventer test to 3000 psig DSR-5/1/24VTL 5/7/2024JLC 5/7/2024 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Phone:907-865-3300 May 1, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP09-S1 Rig Workover Dear Commissioners, Eni US. Operating Co. Inc. hereby applies for a Workover Sundry for well OP09-S1. Well OP09-S1 was drilled and completed in 2011. A second lateral well (OP09-S1 L1) was last drilled in 2014 and the well was completed with a TTESP. On November 28th, 2023, OP09-S1 was shut down because of a suspected ESP failure. The workover was conducted in March 2024 and the well was completed with a conventional ESP. On April 30th, 2024, the well was shut down again because of a suspected ESP failure. The current plan is to pull the current ESP completion out and install a new conventional ESP system. The estimated date for beginning this work is May 8th, 2024. 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 907-865-3300. Sincerely, Giorgio Iannucci Well Operations Project Manager Sincerely, OP09-S1 Workover Summary Page OP09-S1 Rig Workover PTD#:211-058 Current Status Well, OP09-S1 is currently shut down. Scope of Work The scope of this workover is to pull the current failed ESP completion and run in with a new Conventional ESP system on 2-7/8 tubing. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1,400 psi during the time of workover. OP09-S1 MASP Shut-in BHP (Max) 1,400 psi, 6.9 ppge Depth 3,891 ft (TVD) Gradient 0.1 psi/ft MASP 1,011 psi Wellhead type/pressure rating: Vault PC, MB-247/5000 psi BOP configuration: Annular/Blind/2-7/8 x 5 VBR/4-1/2 Pipe Ram TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8 was tested 2000 psi for 30 minutes on February 29, 2024 Well type: Producer Estimated start date: May 8th, 2024. Drilling rig: Nordic 4. Sr. Drilling Engineer: Amjad Chaudhry: Amjad.chaudhry@eni.com Work: 907-865-3300 Well Operations Project Manager: Giorgio Iannucci: Giorgio.Iannucci@eni.com Work: 907-865-3300 Procedure: 1. MIRU Nordic 4. 2. Bullhead 8.6 ppg brine down tubing down tubing. 3. Bullheads brine down Annulus A. 4. ND tree, NU BOPE and test. 5. POOH with 2-7/8 tubing and ESP completion. 6. Contingent RIH with 5-1/2 L1 lateral cleanout assembly to L1 heal. 7. RIH with 2-7/8 completion ESP string. 8. Land hanger. 9. Install BPV, ND BOPE, NU Tree. 10. Passport test. 11. Contingency: bullhead LVT freeze protection. 12. RDMO. Below the current schematic of the well: Planned completion will be the same as current completion. Rig Nordic #4 Stack measurements Note: To be confirmed when rigged up Top Flange Upper Lock Down Screws Rotary Table 8 5 13 2 14 3 34 to GL (Nordic Rig 4 RKB 33.5 + 6 mats) 24 9 25 3 29.5 85 RISER 16 4 Projected KILL LINE CHOKE LINE TOP OF WELL HOUSE 13 10 to GL 4-1/2 pipe rams2-7/8 x 5 VBR rams Nordic Rig #4 RKB 7.41 11.00 12.48 15.20 25.28 6.35 Eni US Operating Co, Inc WELL LOG/DATA TRANSMITTAL To: ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽ 333 W. 7th Ave, Anchorage, AK 99501 April 16, 2024 Well:OP09-S1 LWD/MWD Logs PDF LAS DLIS Excel Mudlogs E-line logs 9.625" Multifinger Caliper Log x x PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Amjad Chaudhry Mail: amjad.chaudhry@eni.com Received By: ___________________________________Date:____________ Eni US Operating Co, Inc. 211-058 T38702 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.16 11:25:24 -08'00' 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Friday, March 15, 2024 11:13 AM To:Kyle Karsten Cc:Regg, James B (OGC) Subject:RE: Nordic Rig 4 Bop test Attachments:Nordic 4 02-11-24 Revised.xlsx Kyle, AƩached is a revised report changing the Annular Preventer & Choke Ln. Valves test result to “FP” and the Number of Failures to 5 (3 H2S failures, Annular Preventer, & Choke Ln. Valves) based on the remarks. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas ConservaƟon Commission Phone: 907‐793‐1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Tuesday, February 13, 2024 1:31 PM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: FW: Nordic Rig 4 Bop test Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: Kyle Karsten <Kyle.Karsten@nordic‐calista.com> Sent: Tuesday, February 13, 2024 10:43 AM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Enipetroleum OPPDrilling <OPPdrilling@eni.com> Subject: Nordic Rig 4 Bop test Some people who received this message don't often get email from kyle.karsten@nordic-calista.com. Learn why this is important Nikaitchuq OP09-S01PTD 2110580 2 Nordic Calista Rig Manager (907)201‐1244 (cell) (907)670‐1407 (Office) This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:4 DATE:2/11/24 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2110580 Sundry #323-677 Operation:Drilling:Workover:X Explor.: Test:Initial:Weekly:X Bi-Weekly:Other: Rams:250/5,000 Annular:250/3,500 Valves:250/5,000 MASP:711 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 ⅝" Hydril FP Pit Level Indicators P P #1 Rams 1 BSR P Flow Indicator P P #2 Rams 1 2 ⅞" x 5 ½" VBR P Meth Gas Detector P P #3 Rams 1 4 ½" Pipe Rams P H2S Gas Detector FP FP #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 ⅛"FP Time/Pressure Test Result HCR Valves 2 3 ⅛"P System Pressure (psi)3050 P Kill Line Valves 1 3 ⅛"P Pressure After Closure (psi)2150 P Check Valve 0 NA 200 psi Attained (sec)24 P BOP Misc 0 NA Full Pressure Attained (sec)70 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4@2,894 P No. Valves 14 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 11 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 5 P #4 Rams 0 P Test Results #5 Rams 0 P #6 Rams 0 NA Number of Failures:5 Test Time:7.5 HCR Choke 1 P Repair or replacement of equipment will be made within 0 days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2-08-24 12:52 Waived By Test Start Date/Time:2/11/2024 2:30 (date)(time)Witness Test Finish Date/Time:2/11/2024 14:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Nordic Tested with 2 7/8" & 4 1/2" test joints. Annular failed/raised closing pressure/passed with 2 7/8" test joint. Rig floor H2S failed audible and visual (2 failures). Recalibrated and passed. Cellar H2S failed only on high alarm. Sensor head changed out and passed. Inside choke line valve on BOP's failed/replaced valve/passed. Kelly/Woods ENI Ashley/Cornel Nikaitchuq OP09-S01 Test Pressure (psi): igmanager.rig4@nordic-calista.co OPPdilling@eni.com Form 10-424 (Revised 08/2022)2024-0211_BOP_Nordic4_Nikaitchuq_OP09-S01            J. Regg; 4/5/2024 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. From:Kyle Karsten To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC) Subject:Nordic 4 BOP test OP09-S1 3/4/24 Date:Wednesday, March 6, 2024 2:51:59 PM Attachments:BOP test form 3-4-24.xlsx Some people who received this message don't often get email from kyle.karsten@nordic-calista.com. Learn why this is important Here you are folks. Let me know if I missed anything! Kyle Karsten Nordic Calista Rig Manager (509)217-1478 (cell) (907)670-1407 (Office) This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. 1LNDLWFKXT236 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:4 DATE: 3/4/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2110580 Sundry #323-677 Operation: Drilling: Workover: x Explor.: Test: Initial: Weekly: x Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:711 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" Hydrill P Pit Level Indicators PP #1 Rams 1 BSR P Flow Indicator PP #2 Rams 1 2-7/8x5-1/2 VBR P Meth Gas Detector PP #3 Rams 1 2-7/8x5-1/2 VBR P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3-1/8"P Time/Pressure Test Result HCR Valves 2 3-1/8"P System Pressure (psi)2980 P Kill Line Valves 1 3-1/8"P Pressure After Closure (psi)2025 P Check Valve 0NA200 psi Attained (sec)29 P BOP Misc 0NAFull Pressure Attained (sec)87 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4@2887 P No. Valves 14 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 14 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.0 HCR Choke 1 P Repair or replacement of equipment will be made within 0 days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3-3-24 12:22 Waived By Test Start Date/Time:3/4/2024 6:00 (date) (time)Witness Test Finish Date/Time:3/4/2024 11:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Nordic Tested with 2-7/8" test joint. Tested gas alarms from all stations. Tested PVT's and flow paddle Karsten / Woods ENI Ashley/Dillion Nikaitchuq OP09-S1 Test Pressure (psi): ggmaniger.rig4@nordic-calista.co OPPDrilling@eni.com Form 10-424 (Revised 08/2022) 2024-0304_BOP_Nordic4_Nikaitchuq_OP09-S1 9 9999 9 9 9 9 9 9 -5HJJ 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. From:Kyle Karsten To:DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Regg, James B (OGC) Subject:Nordic Rig4 BOP test 2-27-24 OP09-S1 Date:Wednesday, February 28, 2024 9:26:00 AM Attachments:BOP test form 2-27-24.xlsx Here you are folks. If I missed anything, please let me know. Thanks and have a great day! Kyle Karsten Nordic Calista Rig Manager (509)217-1478 (cell) (907)670-1407 (Office) This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. 1LNDLWFKXT236 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m itt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:4 DATE: 2/27/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #22110580 Sundry #323-677 Operation: Drilling: Workover: x Explor.: Test: Initial: Weekly: x Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:711 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1FP Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" Hydrill P Pit Level Indicators PP #1 Rams 1 BSR P Flow Indicator PP #2 Rams 1 2-7/8x5-1/2 VBR P Meth Gas Detector PP #3 Rams 1 2-7/8x5-1/2 VBR P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3-1/8"P Time/Pressure Test Result HCR Valves 2 3-1/8"P System Pressure (psi)3050 P Kill Line Valves 1 3-1/8"P Pressure After Closure (psi)2125 P Check Valve 0NA200 psi Attained (sec)28 P BOP Misc 0NAFull Pressure Attained (sec)75 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4@2869 P No. Valves 14 FP ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 11 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:3 Test Time:10.5 HCR Choke 1 P Repair or replacement of equipment will be made within 0 days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2-24-24 18:16 Waived By Test Start Date/Time:2/26/2024 18:40 (date) (time)Witness Test Finish Date/Time:2/27/2024 5:43 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Nordic Tested with 2-7/8" & 4" test joints. CM #1 fail/greased/passed. CM#7 fail/greased/passed. 4" TIW (Ball Type) failed/changed out with spare/passed. Karsten/Stuckart ENI Hays/Dillion Nikaitchuq OP09-S1 Test Pressure (psi): ggmaniger.rig4@nordic-calista.co OPPDrilling@eni.com Form 10-424 (Revised 08/2022) 2024-0227_BOP_Nordic4_Nikaitchuq_OP09-S1 9 9 9 9 999 9 9 9 9 9 9 9 9 -5HJJ FP FP CM #1 fail CM#7 fail 4" TIW (Ball Type) failed/ 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. From:Kyle Karsten To:Regg, James B (OGC); Enipetroleum OPPDrilling Subject:Rig 4 BOP Test Date:Wednesday, February 21, 2024 6:33:35 AM Attachments:BOP test form 2-19-2024.xlsx You don't often get email from kyle.karsten@nordic-calista.com. Learn why this is important Hello Jim I sent this to the address you said but I got a undelivered back this morning in my email, so im sending it to you. John Kelly Nordic Calista Rig Manager (907)201-1244 (cell) (907)670-1407 (Office) This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. 1LNDLWFKXT236 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:4 DATE: 2/19/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #22110580 Sundry #323-677 Operation: Drilling: Workover: x Explor.: Test: Initial: Weekly: x Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:711 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 2P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" Hydrill P Pit Level Indicators PP #1 Rams 1 BSR P Flow Indicator PP #2 Rams 1 2-7/8x5-1/2 VBR P Meth Gas Detector PP #3 Rams 1 2-7/8x5-1/2 VBR P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3-1/8"P Time/Pressure Test Result HCR Valves 2 3-1/8"P System Pressure (psi)3000 P Kill Line Valves 1 3-1/8"P Pressure After Closure (psi)1950 P Check Valve 0NA200 psi Attained (sec)38 P BOP Misc 0NAFull Pressure Attained (sec)101 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4@2950 P No. Valves 14 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 12 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:7.0 HCR Choke 1 P Repair or replacement of equipment will be made within 0 days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2-17-24 07:14 Waived By Test Start Date/Time:2/18/2024 23:38 (date) (time)Witness Test Finish Date/Time:2/19/2024 11:24 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Sully Sullivan Nordic Tested with 2-7/8" & 4" test joints. Tested with 2-7/8" & 4" Dart valve and Ball Type floor safety valves. Kelly/Stuckart ENI Hays/Cornell Nikaitchuq OP09-S1 Test Pressure (psi): ggmaniger.rig4@nordic-calista.co OPPDrilling@eni.com Form 10-424 (Revised 08/2022) 2024-0219_BOP_Nordic4_Nikaitchuq_OP09-S1 9 9 9 9 9 9 9 9 9 9 9 -5HJJ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________NIKAITCHUQ OP09-S01 JBR 03/07/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:6 2-7/8" & 4-1/2" joints. Rig floor H2S visual & audible FP. Cellar H2S audible FP. Annular FP. CH misc FP is bypass/panic line terminating inside section of the rig. Extend to exterior for a pass. Manual choke on mud cross Fail. R/T not witnessed. Chart of same sent to J. Regg. Test Results TEST DATA Rig Rep:Karsten/WoodsOperator:Eni US Operating Co. Inc.Operator Rep:Ashley/Dillon Rig Owner/Rig No.:Nordic 4 PTD#:2110580 DATE:2/2/2024 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopSAM240203130328 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 9.5 MASP: 711 Sundry No: 323-677 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 14 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 1 FPCH Misc Stripper 0 NA Annular Preventer 1 13-5/8"FP #1 Rams 1 B/S P #2 Rams 1 2-7/8"x5-1/2"P #3 Rams 1 4-1/2"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"F HCR Valves 2 3-1/8"P Kill Line Valves 2 3-1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P2125 200 PSI Attained P24 Full Pressure Attained P70 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2840 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector FP FPH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P11 #1 Rams P6 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1          Manual Choke retest chart attached -- J. Regg; 3/7/2024 Nordic 4 – Nikaitchuq OP09-S1 (PTD 2110580) Manual Choke Retest Chart AOGCC Inspection # bopSAM240203130328 2/4/2024 P.I. Supv Comm: Rig Coil Tubing Unit?No Rig Contractor Rig Representative Operator Operator Representative Well Permit to Drill #2110580 Sundry Approval #323-677 Operation Inspection Location Working Pressure, W/H Flange P Pit Fluid Measurement P Working Pressure P P Flow Rate Sensor P Operating Pressure P FP Mud Gas Separator P Fluid Level/Condition P P Degasser P Pressure Gauges P P Separator Bypass P Sufficient Valves P P Gas Detectors FP Regulator Bypass P P Alarms Separate/Distinct P Actuators (4-way valves)P P Choke/Kill Line Connections P Blind Ram Handle Cover P P Reserve Pits NA Control Panel, Driller P P Trip Tank P Control Panel, Remote P P Firewall P FP 2 or More Pumps P P Kelly or TD Valves P Independent Power Supply P P Floor Safety Valves P N2 Backup P P Driller's Console P Condition of Equipment P P Flow Monitor P Flow Rate Indicator P Pit Level Indicators P Valves P PPE P Gauges P Remote Hydraulic Choke P Well Control Trained P Gas Detection Monitor P FOV Upstream of Chokes P Housekeeping P Hydraulic Control Panel P Targeted Turns P Well Control Plan P Kill Sheet Current P Bypass Line FP FAILURES:6 CORRECT BY: COMMENTS Inspection prior to and during initial BOPE test (5000psi) while over the well. During actual testing of well control components, manual choke on the BOP's mudcross, annular, cellar and rig floor H2S sensors fail/pass. Choke manifold bypass ("panic") line terminated inside part of the rig. Asked it be extended by means of hose or hardline to just outside the rig module. Picture rec'd 2/4/24 showing extensionn and end of the bypass line outside the rig. No other issues with this inspection. CHOKE MANIFOLD Nikaitchuq OP09-S1 MUD SYSTEM OP09-S1 Workover CLOSING UNIT ALASKA OIL AND GAS CONSERVATION COMMISSION RIG INSPECTION REPORT HCR Valve(s) Manual Valves Annular Preventer Working Pressure, BOP Stack Stack Anchored Choke Line Kill Line Targeted Turns Pipe Rams Blind Rams Karsten/Woods Ashley/Dillon Locking Devices, Rams BOP STACK Austin McLeod 2/2/2024INSPECT DATE AOGCC INSPECTOR 2/4/2024 Nordic 4 Nordic Calista ENI US Operating Co. Inc. MISCELLANEOUS Flange/Hub Connections Drilling Spool Outlets Flow Nipple Control Lines RIG FLOOR 2024-0202_Rig_Nordic4_Nikaitchuq_OP09-S1_am rev. 4-19-2023 J. Regg; 3/7/2024          1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: __ESP Changeout_ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 22,370 feet N/A feet true vertical 3,784 feet N/A feet Effective Depth measured 21,740 feet N/A feet true vertical 3,868 feet N/A feet Perforation depth Measured depth 13,195-22,370 feet True Vertical depth 3,929-3,868 feet Tubing (size, grade, measured and true vertical depth)2-7/8"L-80 12,532' 3,859' 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: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Schrader Bluff 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: Authorized Name and Giorgio Iannucci Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Well Operations Project Manager Contact Phone: 323-677 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 22 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 9.625 5.5 3700 Centerpoint Dr. Ste. 500, Anchorage, AK, 99503 3. Address: OP09-S1 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 160 Gas-Mcf MD 186 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 2132 00 316 2931112 193 13.375 MFC will be uploaded on FTP site 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 0355024, 0373301, 0388583, 0390616, 0391283 Nikaitchuq Schrader Bluff Eni US Operating Co. Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 211-058 50-029-23448-00-00 Size 154 measured TVD Production Liner 10440 11127 Casing Structural 10440 21325 9.625 5.5 Plugs Junk measured Length 160 2324 20" Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3300 13.375 2324 Burst Collapse 0 5210 6890 slotted 154 2163 3847 3671 N/A Conductor Surface Intermediate 20" p k ft t Fra O s 211 6.A G L PG , _ Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Giorgio Iannucci By Grace Christianson at 4:29 pm, Mar 28, 2024 RBDMS JSB 040424 DSR-4/12/24 2-7/8" 6.4# L80 Hydril 563 Production TubingHAL 5-½” Oil Swell Packer2-7/8” x-cplg cable clamps, for ESP Power Cable, (2) 3/8" Chem Inj LineOP09-S1Dual Lateral Producer with ESP LiftNikaitchuq Field- Oliktok Point5-½” Silver Bullet Ecc. Nose Guide ShoeAs RunMarch 2024 Interm. Casing 9-5/8", 40#13,195' MD, 3,929' TVD86º Inc.Slotted Liner,5-½” 15.5 - 17 ppf21,740' MD, 3,868' TVD93º Inc.12,986' MD, 3,908 TVDBaker SLXP Liner Hanger/PackerSurf. Casing13-3/8", 68 # 2,325' MD, 2,159' TVD42º Inc.Top ESP: 12,572' MD, 84º Inc. Bottom of shroud 12,654' MDϴϮƐƚŐ&ůĞǆϮϳ͕ϮϬƐƚŐ'ŝŶƉƐŚ͕ϮϱϬ,WŵŽƚŽƌDischarge Head: 12,580'MDXN-Nipple: 12,532' MD, 84º Inc12,674' MD, 3,873' TVDL1 - Baker SLXP LH/PKRAs tagged during last WO5-½” Silver Bullet Ecc. Nose Guide Shoe with Bent JointHAL 5-½” Oil Swell Packer12,827-12,843 MD, Casing Exit WindowSlotted Liner,5-½” 15.5 ppf21,460' MD, 3,860' TVD91º Inc.WĂĐŬĞƌ D;ĨƚͿ^ǁĞůůWĂĐŬĞƌηϭ ϮϬ͕Ϭϳϱ^ǁĞůůWĂĐŬĞƌηϮ ϭϵ͕ϲϴϱ^ǁĞůůWĂĐŬĞƌηϯ ϭϴ͕ϭϭϬ^ǁĞůůWĂĐŬĞƌηϰ ϭϳ͕ϮϴϬ^ǁĞůůWĂĐŬĞƌηϱ ϭϱ͕ϱϰϱ^ǁĞůůWĂĐŬĞƌηϲ ϭϰ͕ϰϯϱϱϭͬϮΗ^ǁĞůůWŬƌͲDĂŝŶŽƌĞ Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 1/27/2024 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) 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 Temperature (°F) -30.3 Wind SW @ 9 MPH Days LTI (days) 2,333.00 Days RI (days) POB 29.0 Daily Summary Operations 24h Forecast Continue to walk rig to OP09-S1 and center over well. Berm containment around rig. Spot cuttings tank and highline skid. Swap rig over to highline power. Fill mud pits with 8.6 PPG brine. Bullhead tubing and A- Annulus with 8.6 PPG 3% KCl/NaCl brine inhibited with biocide. 24h Summary Clean out cuttings box and rig mud pits. Retract and secure cuttings chute. Move highline tie breaker and cuttings box. Lay rig mats for rig move to OP09-S1. Walk rig to OP09-S1, total of 114’. Operation at 07.00 Rig startup. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 PREP A 2 P Continue walking rig to OP09-S1, total 99’ moved. Retainer plate bolts sheared for wellbay off driller side stomper pin. 02:30 05:30 3.00 5.50 PREP A 25 P Replace sheared retainer plate bolts for wellbay off driller side stomper pin. 05:30 07:00 1.50 7.00 PREP A 2 P Continue walking rig to OP09-S1, total 104’ moved. Boss fitting on flow block for wellbay off driller side walker ram o-ring leaking. 07:00 08:30 1.50 8.50 PREP A 25 P Replace Boss fitting on flow block for wellbay off driller side walker ram. 08:30 10:30 2.00 10.50 PREP A 2 P Continue walking rig to OP09-S1, total 114’ moved. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 1/28/2024 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) 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 Temperature (°F) -36.8 Wind SW @ 8 MPH Days LTI (days) 2,334.00 Days RI (days) POB 29.0 Daily Summary Operations 24h Forecast Rotate rig 90°. Walk rig to OP09-S1 and center over well. Berm containment around rig. Spot cuttings tank and highline skid. Swap rig over to highline power. Fill mud pits with 8.6 PPG brine. Bullhead tubing and A -Annulus with 8.6 PPG 3% KCl/NaCl brine inhibited with biocide. 24h Summary Walk rig to OP09-S1. Unable to obtain loader permit due to temperature below -35°F to lay additional matting boards. Operation at 07.00 Walk rig to OP09-S1. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 PREP A 2 P Continue walking rig to OP09-S1 well center to rotate 90°, total 178’ moved. 03:00 12:00 9.00 12.00 PREP A 22 TW01 Unable to obtain loader permit due to temperature below -35°F to lay additional matting boards as per eni Alaska Cold Weather Requirements operating procedure. 12:00 00:00 12.00 24.00 PREP A 22 TW01 Unable to obtain loader permit due to temperature below -35°F to lay additional matting boards as per eni Alaska Cold Weather Requirements operating procedure. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 1/29/2024 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) 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 Temperature (°F) -9.0 Wind NE @ 25 MPH Days LTI (days) 2,335.00 Days RI (days) POB 34.0 Daily Summary Operations 24h Forecast Spot cuttings tank and highline skid. Swap rig over to highline power. Fill mud pits with 8.6 PPG brine. Bullhead tubing and A Annulus with 8.6 PPG 3% KCl/NaCl brine inhibited with biocide. Install BPV and nipple down Xmas tree. Nipple up BOPE. 24h Summary Rotate rig 90° and square up with well. Walk rig to OP09-S1 and center over well. Berm containment around rig. Operation at 07.00 Rigging up to fill mud pits with 8.6 PPG brine. 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 PREP A 1 P Pressure test air boots on low pressure mud system. Locate and stage 2” high pressure hoses, chicksans, and valves for well kill. Locate and stage tools and gaskets for nipple up of BOPE. Install dies in 6” and 8” collar slips. Locate and stage valves and chicksans for testing BOPE. Note: Unable to obtain loader permit due to temperature below -35°F to lay additional matting boards as per eni Alaska Cold Weather Requirements operating procedure. 08:00 18:00 10.00 18.00 PREP A 1 P Obtain loader permit and lay additional matting boards. Rotate rig 90° and square up with well. Remove choke line to raise BOP enclosure before moving over wellbay. Walk rig to OP09-S1 and center over well. 18:00 00:00 6.00 24.00 PREP A 1 P Lay rig mats for cuttings box and containment. Berm containment around rig. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 1/30/2024 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) 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 Temperature (°F) -9.2 Wind SE @ 9 MPH Days LTI (days) 2,336.00 Days RI (days) POB 38.0 Daily Summary Operations 24h Forecast Continue bullhead A-Annulus with 8.6 PPG 3% KCl/NaCl brine inhibited with biocide. Monitor well. Install BPV and nipple down Xmas tree. Nipple up BOPE. 24h Summary Berm containment around rig. Spot cuttings tank and high line skid. Fill mud pits with 8.6 PPG brine. Bullhead tubing and A-Annulus with 8.6 PPG 3% KCl/NaCl brine inhibited with biocide. Operation at 07.00 Monitor well. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 PREP A 1 P Continue to berm around rig. Spot clam shells for high line cable. Contact drill site operator and un-spool high line cable. Spot cuttings tank with Worley bed truck and install secondary containment. 04:00 08:00 4.00 8.00 PREP M 1 P Onload 600 BBLS of 8.6 ppg 3% KCL bine to mud pits. Obtain permit through operations group with Vault wellhead representative. Install flange block valve to wellhead. Rig up 2” high pressure lines to rig mud manifold and OP09-S1 wellhead. 08:00 12:00 4.00 12.00 PREP M 12 P Fluid pack lines and attempt to pressure test to 3,500 psi. No test due to discrepancy in manual and electronic gauges. Troubleshoot discrepancy with rig electrician and PECO remote services. 12:00 16:00 4.00 16.00 PREP M 12 P Obtain production permit for operating in well bay. Test lines for bull head to 3,500 PSI. Good test. Manual and electronic pressure gauges align. 16:00 18:00 2.00 18.00 PREP M 9 P Bull head tubing with 8.6 PPG 3% KCL brine. Initial circulating pressure 20 PSI at 3 BPM. 304 total BBLs pumped (tubing volume + 30%). Final shut-in pressures, 0 PSI Tubing, 300 PSI A-Annulus, 160 PSI B-Annulus. 18:00 00:00 6.00 24.00 PREP M 9 P Top off mud pits with 8.6 ppg 3% KCL brine. Initial pressures, 0 PSI Tubing, 250 PSI A-Annulus, 140 PSI B-Annulus. Bull head A-Annulus with 8.6 PPG 3% KCL brine. Initial circulating pressure 250 PSI at 3 BPM. 689 total BBLs pumped. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Drilling Engineer Amjad Chaudhry Eni Sr. Drilling Engineer amjad.chaudhry@eni.com 907-865-3379 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 1/31/2024 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) 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 Temperature (°F) -10.1 Wind W @ 20 MPH Days LTI (days) 2,337.00 Days RI (days) POB 36.0 Daily Summary Operations 24h Forecast Install BPV and nipple down X-mas tree. Nipple up BOPE. Test BOPE as per AOGCC requirements with 2-7/8” and 4-1/2” test joints. 24h Summary Continue bullhead A-Annulus with 8.6 PPG 3% KCl/NaCl brine inhibited with biocide. Monitor well. Bleed off tubing and A-Annulus. Install BPV and nipple down X-mas tree. Nipple up BOPE. Operation at 07.00 Nipple up BOPE 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 PREP M 9 P Continue bullhead A-Annulus with 8.6 PPG 3% KCl/NaCl brine inhibited with biocide. Total of 834 BBLs pumped. Final shut-in pressures: 440 PSI Tubing, 0 PSI A-Annulus, 240 PSI B-Annulus. 01:00 02:00 1.00 2.00 PREP M 1 P Monitor well for one hour while rig-up bleed trailer. Shut-in pressures after one hour: 420 PSI Tubing, 0 PSI A-Annulus, 180 PSI B-Annulus. 02:00 09:30 7.50 9.50 PREP M 20 P Bleed tubing down thru production heeder from 420 PSI to 185 PSI. Swap over to bleed trailer and continue bleed tubing down. SITP stabilized at 2.6 PSI. A-Annulus pressure increased from 0 PSI to 100 PSI during bleed down of tubing. Bleed A- Annulus down from 100 PSI to 2.5 PSI to bleed trailer. SITP stabilized at 2.6 PSI. Shut in well to monitor pressure build up. No build up. 09:30 13:30 4.00 13.50 PREP M 20 P Bleed tubing and Annulus pressure to zero. Shut in well and monitor pressure build up. No build up. 13:30 17:30 4.00 17.50 PREP C 20 P Rig up and install BPV with Vault.Nipple down X-mas tree. Terminate control line. Clean and inspect tubing hanger. Install riser and Vault representative torqued riser Greylock to wellhead. 17:30 20:30 3.00 20.50 PREP C 5 P Nipple up 13-5/8” 5M single ram BOP with 4-1/2” rams installed. 20:30 23:00 2.50 23.00 PREP C 1 P Lift rig with hydraulic walking feet to allow clearance to install 13-5/8” 5M double ram BOP and annular with bridge crane. 23:00 00:00 1.00 24.00 PREP C 1 P Torque 13-5/8” 5M double ram and single ram BOP bolts. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Safety Representative Joe Hladick ASRC Energy Services HSE Joe.Hladick@external.eni.com 907-685-1434 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Drilling Engineer Amjad Chaudhry Eni Sr. Drilling Engineer amjad.chaudhry@eni.com 907-865-3379 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/1/2024 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) 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 Temperature (°F) -9.6 Wind SW @ 14 MPH Days LTI (days) 2,338.00 Days RI (days) POB 37.0 Daily Summary Operations 24h Forecast Test BOPE as per AOGCC requirements with 2-7/8” and 4-1/2” test joints. Slip and cut drilling line. Hold lift plan meeting. Mobilize GBR tools and equipment and empty ESP spools to the rig floor. Rig up to pull 4- 1/2” upper completion string. 24h Summary Finish nipple up BOPE. Attempt shell test on BOPE to 5000 PSI. 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 09:00 9.00 9.00 PREP C 5 P Torque 13-5/8” 5M double ram and single ram BOP bolts. Install rams and change door seals. Install wing valves on BOPs and torque same. Grease valves and function test. Pressure up accumulator and function test control lines. Install turn buckles and center BOPs with rotary table. 09:00 10:00 1.00 10.00 PREP C 5 P Install test plug with Vault representative. 10:00 12:00 2.00 12.00 PREP C 5 P Install 4-1/2” test joint with TIW and pump in sub. Rig up test pump. Fluid pack all lines and fill BOP. 12:00 14:00 2.00 14.00 PREP C 12 P Attempt shell test on BOPE to 5000 PSI. Lower pipe ram door seal is leaking. 14:00 00:00 10.00 24.00 PREP C 12 U Replaced lower pipe ram door seal. Tighten flange between kill line and upper pipe rams. Change hydraulic hose on choke HCR valve. Tighten choke and kill line gray lock connections. Replace auto clave fitting on BOP test pump. Re-attempt shell test on BOPE to 5000 PSI. Gray lock connections leaking on choke line. Blow down BOPs and change gaskets and clamps for gray lock connections. Note: AOGCC Petroleum Inspector Austin McLeod will witness BOPE test. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Safety Representative Joe Hladick ASRC Energy Services HSE Joe.Hladick@external.eni.com 907-685-1434 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Drilling Engineer Alex Vaughan Eni Sr. Drilling Engineer Alex.Vaughan@external.eni.com 907-865-3323 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/2/2024 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) 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 Temperature (°F) -16.6 Wind SW @ 16 MPH Days LTI (days) 2,339.00 Days RI (days) POB 37.0 Daily Summary Operations 24h Forecast Test inside manual choke valve. Cut and slip drilling line. Perform derrick inspection. Hold Lift plan meeting. Mobilize GBR and Baker Centrilift equipment to the rig floor via crane. Rig up GBR equipment and Baker Centrilift equipment. Prepare to pull 4-1/2” upper completion string. 24h Summary Achieve shell test on BOPE to 5000 PSI. Test BOPE as per AOGCC requirements with 2-7/8” and 4-1/2” test joints. AOGCC Inspector Austin McLeod witnessed BOPE test. Inside manual choke valve failed initial test. Change out inside manual choke valve on BOP. Operation at 07.00 Prepare to pull ESP. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:00 5.00 5.00 PREP C 12 U Change gasket and clamp on choke hard line gray lock connection. Tighten gland nut on wellhead lock down pin with Vault representative. Inspect seal ring on #2 mud pump check valve and retighten. 05:00 08:00 3.00 8.00 PREP C 12 P Achieve shell test on BOPE to 5000 PSI. Notify AOGCC Petroleum Inspector Austin McLeod ready for BOPE test at 0500 HRS. AOGCC Inspector arrived on location at 0800 HRS. 08:00 17:00 9.00 17.00 PREP C 12 P Test BOPE as per AOGCC requirements with 2-7/8” and 4-1/2” test joints, 250 PSI low and 5000 PSI high for 5 minutes each test and charted. Good test. Test Annular BOP with 2-7/8” test joint, 250 PSI low and 3500 PSI high for 5 minutes each test and charted. Good test. Test gas alarms and PVT alarms. Good test. Perform accumulator drawdown test with starting pressure of 3050 PSI, 2125 PSI after function, 200 PSI recovery 24 seconds, with full recovery at 70 seconds. N2 bottle average 4 at 2937 PSI. Good test. Inside manual choke valve failed initial test. AOGCC Inspector Austin McLeod witnessed BOPE test. 17:00 00:00 7.00 24.00 PREP C 25 U Blow down BOPs. Change out inside manual choke valve on BOP. Fill BOP with water and purge lines. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Safety Representative Joe Hladick ASRC Energy Services HSE Joe.Hladick@external.eni.com 907-685-1434 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Drilling Engineer Alex Vaughan Eni Sr. Drilling Engineer Alex.Vaughan@external.eni.com 907-865-3323 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/3/2024 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) 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 Temperature (°F) -10.1 Wind SW @ 16MPH Days LTI (days) 2,340.00 Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Finish bullhead tubing. Pull BPV from tubing hanger. Unseat tubing hanger. Pull out of hole laying down 4-1/2” upper completion string. 24h Summary Test inside manual choke valve. Slip and cut drill line. Perform derrick inspection. Hold Lift plan meeting. Mobilize GBR and Baker Centralift equipment to the rig floor via crane. Rig up GBR equipment and Baker Centralift equipment. Attempt to pull BPV from tubing hanger. Bullhead 295 BBLs of 8.6 PPG 3% KCl/NaCl brine inhibited with biocide at 2 BPM with 0 PSI down tubing. Operation at 07.00 Laying down 4 1/2" completion string. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 PREP C 12 P Install test joint with Vault representative. Test inside manual choke valve and HCR valve to 250 PSI low and 5000 PSI high for 5 minutes each test and charted. Good test. Rig down testing equipment and blow down lines. Pull test dart from hanger and lay out test joint. 02:30 05:30 3.00 5.50 PREP M 20 P Slip and cut 60’ drill line. Perform derrick inspection. 05:30 09:30 4.00 9.50 PREP L 1 P Staging GBR and Baker tools to the crane access area. Mobilize ESP and capillary sheaves to rig floor. Mobilize handling equipment for de-completion to rig floor. 09:30 12:00 2.50 12.00 PREP L 1 P Lift plan meeting with Worley crane crew, ENI lifting advisor, ENI safety, Baker, GBR, and Production lead. Pre job safety meeting with crane crew and rig crew. Mobilize GBR and Baker Centralift equipment to the rig floor. 12:00 16:00 4.00 16.00 PREP L 1 P Hang ESP sheaves and capillary sheaves in derrick. Rig up GBR and Baker Centralift for de-completion. 16:00 21:00 5.00 21.00 PREP L 25 U Troubleshoot Baker ESP hydraulic spooler. Place heat on hydraulic hoses and reverse polarity on unit. 21:00 00:00 3.00 24.00 PREP L 9 P Attempt to pull BPV from tubing hanger. Observed gas underneath BPV. Bullhead 295 BBLs of 8.6 PPG 3% KCl/NaCl brine inhibited with biocide at 2 BPM with 0 PSI down tubing. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Safety Representative Joe Hladick ASRC Energy Services HSE Joe.Hladick@external.eni.com 907-685-1434 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Drilling Engineer Alex Vaughan Eni Sr. Drilling Engineer Alex.Vaughan@external.eni.com 907-865-3323 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/4/2024 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) 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 Temperature (°F) -3.8 Wind W @ 3 MPH Days LTI (days) 2,341.00 Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Continue pull out of hole laying down 4.5” upper completion string to 197’ MD. Rig up wireline and pull retrievable section of thru tubing ESP from the 4.5” tubing. Continue pull out of the hole and lay down ESP assembly. Prepare for VACS and casing scraper clean out run. 24h Summary Continue bullhead 4.5” tubing with 8.6 PPG 3% KCl/NaCl brine inhibited with biocide. Remove BPV from tubing hanger and back out lock down pins. Unseat tubing hanger and monitor well. Pull tubing hanger to the rig floor and lay down. Connect capillary line and ESP cable to spooler. Pull out of hole laying down 4.5” upper completion string to 496’. Operation at 07.00 Rigging up Halliburton wireline. 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 PREP L 9 P Continue bullhead 308 BBLs total of 8.6 PPG 3% KCl/NaCl brine inhibited with biocide at 2 BPM with 0 PSI down tubing. 00:30 03:00 2.50 3.00 PREP C 5 P Remove BPV from tubing hanger and back out lock down pins with Vault representative. Unseat tubing hanger with 184K without block and topdrive, 239K total hookload. Pick up tubing hanger 4’, 143K UW. Monitor well for 1 hour. 03:00 04:30 1.50 4.50 PREP L 20 P Pull tubing hanger to 4’ above rig floor to expose ESP cable and capillary line under hanger. Terminate capillary line and disconnect from tubing hanger. Cut ESP cable and remove penetrator from tubing hanger. Lay down tubing hanger and landing joint. Connect capillary line and ESP cable to spooler. 04:30 14:30 10.00 14.50 PREP L 4 P Pull out of hole laying down 4.5” upper completion string to 4694’, 80K UW. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide plus pipe displacement. 14:30 15:30 1.00 15.50 PREP L 1 P Perform kick drill while tripping. Safety meeting with crew, discussed offloading tubing from pipeshed. 15:30 18:30 3.00 18.50 PREP L 4 P Pull out of hole laying down 4.5” upper completion string from 4694’ to 2963’, 70K UW. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide plus pipe displacement. 18:30 20:30 2.00 20.50 PREP L 20 P Pre job safety meeting with Baker, Worley crane crew, and Nordic. Terminate ESP cable and remove ESP cable spool from rig floor. 7206’ of ESP cable on spool. Install empty ESP cable spool on hydraulic spooler. 20:30 00:00 3.50 24.00 PREP L 4 P Pull out of hole laying down 4.5” upper completion string from 2693’ to 496’, 50K UW. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide plus pipe displacement. Note: 24 Hour Loss of 8.6 ppg Brine = 337 bbls Total Loss of 8.6 ppg Brine = 1826 bbls Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Safety Representative Joe Hladick ASRC Energy Services HSE Joe.Hladick@external.eni.com 907-685-1434 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Drilling Engineer Alex Vaughan Eni Sr. Drilling Engineer Alex.Vaughan@external.eni.com 907-865-3323 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/5/2024 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) 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 Temperature (°F) -1.7 Wind NE @ 18 MPH Days LTI (days) 2,341.00 Days RI (days) POB 42.0 Daily Summary Operations 24h Forecast Install wearbushing with Vault representative. Remove upper completion equipment from pipe shed. Load 4” drill pipe and HWDP in pipe shed. Mobilize VACS and casing scraper clean out run BHA to pipe shed and rig floor. Run in hole with VACS and casing scraper picking up 4” drill pipe. 24h Summary Pull out of hole laying down 4.5” upper completion string from 496’ to 197’. Terminate capillary line and ESP cable. De-mobilize ESP spool, capillary line spool, and hydraulic ESP cable spooler from rig floor. Spot Halliburton slickline unit and rig up equipment to pull retrievable portion of TTC-ESP assembly from tubing. Attempt to pull retrievable portion of TTC-ESP assembly from tubing with slickline without success. Pull out of hole laying down retrievable portion of TTC-ESP assembly from tubing. Pull out of hole laying down 4.5” upper completion string from 197’ to 60.75’. Pull out of hole laying down ESP BHA. Rig down GBR tubing tongs. Clean and organize rig floor. Operation at 07.00 Preparing drill pipe and BHA for cleanout. 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. L 4 P Pull out of hole laying down 4.5” upper completion string from 496’ to 197’, 48K UW. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide plus pipe displacement. 01:00 04:00 3.00 4.00 W.O. L 5 P Pre job safety meeting. Terminate capillary line and ESP cable. De-mobilize ESP spool, capillary line spool, and hydraulic ESP cable spooler from rig floor. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide. 04:00 09:00 5.00 9.00 W.O. R 5 P Spot Halliburton slickline unit and rig up equipment to pull retrievable portion of TTC-ESP assembly from tubing. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide. 09:00 16:00 7.00 16.00 W.O. R 5 P Slickline Run #1, run in hole with 4 ½” GS pulling tool and attempt to latch Tubing Stop. Tagged 8’ high. Pull out of hole and had debris on pulling tool. Slickline Run #2, run in hole with 2.5” stroke bailer to 97’ SLM. Pull out of hole. Bailer was 25% full of hard debris. Slickline Run #3, run in hole with 2.5” stroke bailer to 97’ SLM. Pull out of hole and recovered a rag plugging the mule shoe. Slickline Run #4, run in hole with 2.5” stroke bailer to 97’ SLM. Pull out of hole and recovered a small piece of a rag in bailer. Slickline Run #5, run in hole with 2.5” stroke bailer to 97’ SLM. Pull out of hole with no recovery. Slickline Run #6, run in hole with 4 ½” GR pulling tool and retrieved Tubing Stop. Slickline Run #7, run in hole with 4 ½” GR pulling tool and attempt to retrieve Pack-off with Check Valve assembly. Unable to jar free after two hours of hand jarring or release from tool. Cut wire and rig down slickline. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide. 16:00 20:30 4.50 20.50 W.O. L 5 P Pre job safety meeting. Pull out of hole laying down retrievable portion of TTC-ESP assembly from tubing. Full recovery of slickline tools. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide. 20:30 23:00 2.50 23.00 W.O. L 5 P Pre job safety meeting. Pull out of hole laying down 4.5” upper completion string from 197’ to 60.75’. Pull out of hole laying down ESP BHA. Note: 2 half clamps, 2 splice clamps, and 215 full clamps recovered. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide. 23:00 00:00 1.00 24.00 W.O. M 5 P Rig down GBR tubing tongs. Change elevators to 4”. Clean and organize rig floor. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide. Note: 24 Hour Loss of 8.6 ppg Brine = 323 bbls Total Loss of 8.6 ppg Brine = 2149 bbls Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Safety Representative Joe Hladick ASRC Energy Services HSE Joe.Hladick@external.eni.com 907-685-1434 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Drilling Engineer Alex Vaughan Eni Sr. Drilling Engineer Alex.Vaughan@external.eni.com 907-865-3323 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/6/2024 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) 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 Temperature (°F) -6.0 Wind E @ 05 MPH Days LTI (days) 2,342.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Run in hole with VACS tool and casing scraper picking up 4” drill pipe to top of SLXP liner top packer at 12,642’ MD. 24h Summary Install wear bushing with Vault representative. Remove upper completion equipment from pipe shed. Mobilize VACS Tool and casing scraper clean out run BHA to pipe shed and rig floor. Load 280 joints of 4” XT- 39 drill pipe and 30 joints of 4” XT-39 HWDP in pipe shed. Measure drill pipe and prepare to run in hole. Operation at 07.00 Picking up cleanout BHA. 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 1 P Install wear bushing with Vault representative. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide. 00:30 05:00 4.50 5.00 W.O. M 1 P Remove upper completion equipment from pipe shed. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide. 05:00 06:30 1.50 6.50 W.O. M 1 P Mobilize VACS tool and casing scraper clean out run BHA to pipe shed and rig floor. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide. 06:30 00:00 17.50 24.00 W.O. M 1 P Load 280 joints of 4” XT-39 drill pipe and 30 joints of 4” XT-39 HWDP in pipe shed. Measure and caliper HWDP. Measure drill pipe and prepare to run in hole. Fill casing with 10 BPH of 8.6 PPG KCL/NaCl brine inhibited with biocide. Note: 24 Hour Loss of 8.6 ppg Brine = 276 bbls Total Loss of 8.6 ppg Brine = 1857 bbls Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Safety Representative Joe Hladick ASRC Energy Services HSE Joe.Hladick@external.eni.com 907-685-1434 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Eni representative Marco Mazzocchi Eni WOP Compliance Coordinator marco.mazzocchi@eni.com (907) 223-9811 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/7/2024 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) 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 Temperature (°F) -8.5 Wind NE @ 7 MPH Days LTI (days) 2,343.00 Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Run in hole with VACS tool and casing scraper picking up 4” drill pipe for 280 joints. Load pipe shed with 115 more joints of 4” drill pipe. Prepare pipe and continue to RIH to top of SLXP liner top packer at 12,642’ MD. 24h Summary Pick up clean out BHA. Run in the hole picking up HWDP. Continue run in the hole picking up 4” drill pipe. Safety stand down. Continue run in the hole picking up 4” drill pipe. Operation at 07.00 Loading pipe shed with 4" drill pipe. 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. M 1 P PJSM – Pick up 2 stands of drill pipe and stand them in the derrick.Pick up clean out BHA. 08:00 11:30 3.50 11.50 W.O. M 4 P Run in the hole with the clean out assembly picking up HWDP and 4" drill pipe. 11:30 12:30 1.00 12.50 W.O. M 1 P Safety stand down meeting with all crews. 12:30 22:30 10.00 22.50 W.O. M 4 P Service Rig, TDS, draw works, and crown.Continue to run in the hole with clean out assembly & picking up 4” drill pipe (181 jts total / 6770’). 22:30 23:00 0.50 23.00 W.O. M 25 U Shut down to replace pinched hydraulic hose on the Iron Roughneck. 23:00 00:00 1.00 24.00 W.O. M 4 P Continue to run in the hole with clean out assembly & picking up 4” drill pipe (205 jts total) Note: 24 Hour Loss of 8.6 ppg Brine = 337 bbls Total Loss of 8.6 ppg Brine = 1826 bbls Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Safety Representative Joe Hladick ASRC Energy Services HSE Joe.Hladick@external.eni.com 907-685-1434 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Eni representative Marco Mazzocchi Eni WOP Compliance Coordinator marco.mazzocchi@eni.com (907) 223-9811 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/8/2024 Report #: 13 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) 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 Temperature (°F) -1.8 Wind NE @ 14 MPH Days LTI (days) 2,344.00 Days RI (days) POB 41.0 Daily Summary Operations 24h Forecast Repair top drive issues. Continue to ream down from 9945’ – 12642’ (Liner Top). 24h Summary Continue to run in the hole with clean out assembly & picking up 4” drill pipe to 9697’. Load pipe shed with remaining joints of drill pipe and prepare to pick up. Continue to run in the hole to 10,307’. Pipe is floating, slack off weight 42K. Pull out of the hole standing pipe in the derrick. Work on TDS. Continue to pull out of the hole standing pipe in the derrick. Pick up singles from pipe shed. RU & begin reaming in the hole with top drive. Shut down @ 22:00 HRS for top drive repairs. Operation at 07.00 Troubleshooting programming issues with top drive. 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. M 4 P Continue to run in the hole with clean out assembly & picking up 4” drill pipe to 9697’. (274 joints) 03:30 09:30 6.00 9.50 W.O. M 1 P Load pipe shed with 120 jts 4” drill pipe. Measure and prepare for picking up. Obtain permits for the loader with the lift advisor and production supervisor. 09:30 11:00 1.50 11.00 W.O. M 4 P Run in the hole picking up 4” drill pipe from the pipe shed to 10,307’. The drill string would not free fall any deeper. Slack off weight 42K. Pick up weight. 11:00 12:30 1.50 12.50 W.O. M 1 P PJSM - Pull out of the hole racking back stands of drill pipe. Encountered Problem with the Proximity sensor malfunction on the TDS 12:30 15:00 2.50 15.00 W.O. M 1 U Trouble shoot link tilt on the TDS and issue was corrected ready to continue. 15:00 17:30 2.50 17.50 W.O. M 4 P Continue to pull out of the hole racking back stands of drill pipe. 17:30 21:00 3.50 21.00 W.O. M 4 P Run in the hole picking up 4” drill pipe from the pipe shed to 9936’ total of 273’ jts (12’ sticking up). 21:00 21:30 0.50 21.50 W.O. M 6 P Change handling equipment to begin reaming in the hole w/ top drive. 21:30 22:00 0.50 22.00 W.O. M 6 P Reamed down 9’ to 9945’ w/ 15 RPM @ 6800 torque. Attempted to release torque to break connection & top drive fully released to the left with no control from the driller. Picked up to ensure 130k string weight was still present & no trapped torque. Set pipe in slips & shut down for top drive repairs. 22:00 00:00 2.00 24.00 W.O. M 25 TR04 Troubleshoot top drive system. Contacting PECO & Canrig for guidance. Note: 24 Hour Loss of 8.6 ppg Brine = 283 bbls Total Loss of 8.6 ppg Brine = 2140 bbls Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Safety Representative Jonah Lloyd ASRC Energy Services HSE jonah.lloyd@external.eni.com 907-685-1434 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/9/2024 Report #: 14 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) 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 Temperature (°F) -0.8 Wind NE @ 26MPH Days LTI (days) 2,345.00 Days RI (days) POB 41.0 Daily Summary Operations 24h Forecast Troubleshooting the Top Drive torque release issues. Pull out of the hole with 4’ DP to 7150’. Prepare to run storm packer for upcoming BOP test. 24h Summary Trouble shooting the Top Drive torque release issues. Changed out TDS joystick with no change in issues. Installed original joystick. PECO & Can Rig remote into computer system to ensure parameters were correct. Tesla electrician verified all drives were correctly operating. Continue to troubleshoot TDS. Operation at 07.00 Continue troubleshooting top drive torque release issues. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 14:00 14.00 14.00 W.O. M 25 TR04 Trouble shoot top drive torque release issue w/ PECO & Can rig support. 14:00 19:00 5.00 19.00 W.O. M 25 TR04 Changed out joystick that controls top drive functions. Unable to program new controller. Changed back to original controller. 19:00 00:00 5.00 24.00 W.O. M 25 TR04 Tesla electrician arrived and started trouble shooting top drive components. PECO specialist remoted into computer system and inspected parameters for all drive programs with no issues found. Numerous function tests performed by electrician. Note: 24 Hour Loss of 8.6 ppg Brine = 263 bbls Total Loss of 8.6 ppg Brine = 2403 bbls Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Safety Representative Jonah Lloyd ASRC Energy Services HSE jonah.lloyd@external.eni.com 907-685-1434 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/10/2024 Report #: 15 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) 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 Temperature (°F) -2.4 Wind NE @ 16 MPH Days LTI (days) 2,346.00 Days RI (days) POB 41.0 Daily Summary Operations 24h Forecast Set Storm packer & prepare for weekly BOPE Test. Make up test assembly and Test BOPE. Rig down test assembly and Install wear bushing. Run in hole 4” drill pipe. Continue troubleshooting the Top Drive torque release issues. 24h Summary Pull out of the hole 4 1/2" drill pipe to 7024’. Perform rig maintenance while electrician was resting. Troubleshooting the Top Drive torque release issues. Set 9-5/8” Storm Packer. Prepare for upcoming BOP test. 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 01:30 1.50 1.50 W.O. M 25 TR04 Trouble shoot top drive torque release issue w/ PECO, Can-Rig & Tesla electrician. 01:30 04:00 2.50 4.00 W.O. M 4 P PJSM. Changed over handling tools to pull pipe. Pull out of the hole to 7024’. 04:00 12:00 8.00 12.00 W.O. M 25 TR04 Continue with Peco and Can-Rig techs working on torque release issues. Maintenance & cleaning. 12:00 19:00 7.00 19.00 W.O. M 25 TR04 Continue troubleshooting TDS issues. Prepare for the upcoming BOP test. Grease valves. 19:00 00:00 5.00 24.00 W.O. C 12 P Make up 9-5/8” Storm Packer assembly. Run in the hole and set @ 85’ from surface. Unable to get off of packer. Released and pull out of hole. Cleaned back off sub. Run in the hole & set @ 85’ from surface. Back off sub & pull out of hole. Contacted Kam St John with AOGCC and gained a verbal approval to begin BOPE test after midnight. Note: 24 Hour Loss of 8.6 ppg Brine = 268 bbls Total Loss of 8.6 ppg Brine = 2671 bbls Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Safety Representative Jonah Lloyd ASRC Energy Services HSE jonah.lloyd@external.eni.com 907-685-1434 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/11/2024 Report #: 16 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) 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 Temperature (°F) -4.4 Wind NE @ 24 MPH Days LTI (days) 2,347.00 Days RI (days) POB 41.0 Daily Summary Operations 24h Forecast Troubleshooting the Top Drive torque release issues. Following Top Drive repairs, continue with workover program. 24h Summary Test BOPE as per AOGCC requirements with 2-7/8” test joint. (Good Test) Change the rams in the BOP from 4.5” fixed to 2 7/8” x 5” variables. Test the rams. (Good Test) Rig down test assembly. Install wear bushing. Retrieve the storm packer. Troubleshooting the Top Drive torque release issues. Operation at 07.00 Troubleshooting the Top Drive torque release issues. 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. C 12 P Remove wear ring & install test plug with Vault Rep. 01:30 02:30 1.00 2.50 W.O. C 12 P Install 2 7/8” test joint with TIW and pump in sub. Rig up test pump. Fluid pack all lines and fill BOP. 02:30 16:00 13.50 16.00 W.O. C 12 P Test BOPE with 2 7/8” test joint to 250 psi low/ 3500 psi high. Annular 250/2500 psi. Test choke and blinds 250 psi low/3500 psi high. (Good Test) Blow down lines and empty BOP stack. Change lower rams to 2 7/8” x 5 ½” variables. Continue testing BOP, (Good Test) Perform accumulator draw down test, and test all gas, pvt, alarms. (Good Test) Note: Witness waived by AOGCC rep Kam St. John 2/10/2024 16:00 17:00 1.00 17.00 W.O. C 5 P Rig down test equipment. Blow down choke & kill lines. 17:00 18:30 1.50 18.50 W.O. M 5 P PJSM. Pull test plug and set wear bushing with Vault Rep. 18:30 20:30 2.00 20.50 W.O. M 1 P Load long bales on catwalk. Pull 1 stand of 4” drill pipe & lay down due to height restrictions crowning out. Remove short bales and install long bales onto top drive. 20:30 23:00 2.50 23.00 W.O. M 1 P Make up packer release sub and TIW valve. PU & run in the hole to 85’. Latch 9-5/8” packer & release. Pull out of hole and laydown packer. 23:00 00:00 1.00 24.00 W.O. M 1 P Change out long bales back to short bales on top drive. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Safety Representative Jonah Lloyd ASRC Energy Services HSE jonah.lloyd@external.eni.com 907-685-1434 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/12/2024 Report #: 17 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) 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 Temperature (°F) 0.1 Wind E @ 12 MPH Days LTI (days) 2,348.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Troubleshooting the Top Drive torque release issues. Following Top Drive repairs, continue with workover program. 24h Summary Troubleshooting the Top Drive torque release issues. Normal rig maintenance along with housekeeping and inventory of rig materials. Operation at 07.00 Troubleshooting the Top Drive torque release issues. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 00:00 24.00 24.00 W.O. M 25 TR04 Troubleshooting the Top Drive torque release issues with Can-Rig and Tesco. Remote logged into TDS and attempting to load different software without success. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Safety Representative Jonah Lloyd ASRC Energy Services HSE jonah.lloyd@external.eni.com 907-685-1434 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Eni representative Giorgio Ianucci Eni Drilling Manager Giorgio.Iannucci@eni.com Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/13/2024 Report #: 18 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) 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 Temperature (°F) 5.7 Wind E @ 16 MPH Days LTI (days) 2,349.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Troubleshooting the Top Drive torque release issues with both PECO and Can-Rig technicians on location. Following Top Drive repairs, continue to ream in the hole to 12,642’ (Liner Top). 24h Summary Troubleshooting the Top Drive torque release issues remotely. Normal rig maintenance along with housekeeping and inventory of rig materials. PECO Technician arrived on location at 19:00 hrs and began hands on trouble shooting. Operation at 07.00 Troubleshooting the Top Drive torque release issues. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 19:00 19.00 19.00 W.O. M 25 TR04 Troubleshooting the Top Drive torque release issues with Can-Rig and PECO remotely logged into TDS. 19:00 00:00 5.00 24.00 W.O. M 25 TR04 PECO technician arrived on the location. Start hands on trouble shooting with heavy concentration on the joystick which operates the majority of the controls for the TDS. No exact cause of the issues was found at this time. Technicians daily working hours expired and will resume hands on trouble shooting in the morning along with Can-Rig technician arriving at 10:00 AM. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Eni representative Giorgio Ianucci Eni Drilling Manager Giorgio.Iannucci@eni.com Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/14/2024 Report #: 19 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) 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 Temperature (°F) 33.1 Wind SW @ 24 MPH Days LTI (days) 2,350.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Ream in the hole with the clean out assembly to 12,642’ (Liner Top). Pull out of hole and lay down BHA #1. Make up BHA #2. Run in the hole to 12,642’ and cleanout 1600’ below Liner Top. 24h Summary Rig maintenance along with housekeeping and inventory of rig materials. Made repairs on the Top Drive torque release issues with PECO and Can-Rig Technicians on location. The joystick controller was repaired, and drive parameters were set up. Run in the hole with the clean out assembly to 9650’. Ream into the hole with the clean out assembly from 9650’ to 11,300’. Operation at 07.00 Pull 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 09:30 9.50 9.50 W.O. M 1 TR04 Rig crew performed rig maintenance and housekeeping around the rig 09:30 13:00 3.50 13.00 W.O. M 25 TR04 Can-Rig and PECO working on the TDS functions with the software and programming checks and verified that the torque release is functioning as designed. Found Rheostat had failed with the joystick. Set up drive parameters. 13:00 16:30 3.50 16.50 W.O. M 4 P Run in the hole with the 9-5/8” clean out assembly to 9650’. Unable to slide pipe in the hole. Change over tools and prepare to start reaming down hole with Top Drive. 16:30 00:00 7.50 24.00 W.O. M 6 P Set torque at 10K with 20 RPM. Start rotating and ream down hole from 9650’ – 11300'. Note: 24 Hour Loss of 8.6 ppg Brine = 293 bbls. Total Loss of 8.6 ppg Brine = 3545 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Eni representative Giorgio Ianucci Eni Drilling Manager Giorgio.Iannucci@eni.com Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/15/2024 Report #: 20 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) 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 Temperature (°F) 1.9 Wind NW @ 6 MPH Days LTI (days) 2,351.00 Days RI (days) POB 43.0 Daily Summary Operations 24h Forecast Run in the hole with BHA #2 - 9-5/8” clean out assembly (Re-run same BHA) and cleanout to the liner top at 12,677’. 24h Summary Ream in the hole with the clean out assembly to the liner top at 12,677’ drill pipe depth. Fill pipe and work string 50’ x 5 times circulating at 3 BPM. Pull out of the hole. Lay down BHA #1. Clean up BHA #1 and rig floor. Make up BHA #2. Inspect and change saver sub on top drive. Operation at 07.00 Run in hole with BHA #2. 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. M 6 P Continue to ream in the hole from 11,300’ – 11,744’. TDS flashed an overheating code and stopped rotating while making up pipe. 01:30 02:30 1.00 2.50 W.O. M 25 TR04 Can-Rig on location made repairs by adjusting a proximity switch that was out of adjustment for makeup rotation & turned the TD fan on manually to keep hydraulic fluid cooled down instead of waiting for the system to turn it on. 02:30 05:00 2.50 5.00 W.O. M 6 P Reaming in the hole with the clean out assembly from 11,744’ to top of liner at 12,677’ drill pipe depth. 05:00 07:00 2.00 7.00 W.O. M 9 P Fill pipe. Work string 50’ x 5 times pumping 3 BPM, 227 psi. 07:00 12:00 5.00 12.00 W.O. M 4 P Lay down work string. Blow down TDS. Pull out of the hole from 12,670’ to 6268’. Steel line measurement. 12:00 21:00 9.00 21.00 W.O. M 4 P Pull out of the hole from 6268’ to surface. PJSM. Recovered 60 lbs of metal shavings from magnets and both joints of wash pipe packed with fine mesh sand, estimated 250 lbs of sand recovered. 21:00 00:00 3.00 24.00 W.O. M 20 P Clean out BHA #1 and rig floor. Make up BHA #2 - 9-5/8” clean out assembly (Re-run same BHA). Inspect and change saver sub on top drive. Note: 24 Hour Loss of 8.6 ppg Brine = 507 bbls. Total Loss of 8.6 ppg Brine = 4052 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/16/2024 Report #: 21 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) 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 Temperature (°F) -3.6 Wind NW @ 8 MPH Days LTI (days) 2,352.00 Days RI (days) POB 42.0 Daily Summary Operations 24h Forecast Run in hole with 5-1/2” L1 lateral cleanout assembly to L1 heal. 24h Summary Run in the hole with 8 1/8” wash pipe, Vacs tool, 8.250” dress off mill, 7.3” polish mill, 9 5/8” scraper, and 2 each string magnets. Cleanout to liner top at 12,674’. Set down 10k weight on liner top. Scrape packer setting area 5 X’s. Start pulling out of the hole with cleanout assembly. Operation at 07.00 Rig up to run BHA #3. 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. M 20 TR04 Inspect and change saver sub on top drive. Pipe management moving stands of 4” XT-39 drill pipe in derrick. 02:00 03:00 1.00 3.00 W.O. M 5 P Make up BHA #2 with 8 1/8” wash pipe, Vacs tool, 8.250” dress off mill, 7.3” polish mill, 9 5/8” scraper, and 2 each string magnets. 03:00 10:00 7.00 10.00 W.O. M 4 P Run in the hole on elevators with BHA #2 from 249’ MD to 9,209’ MD pick up weight = 140 K, unable to slack off due to hole geometry. Decision made to wash and ream in hole. 10:00 12:00 2.00 12.00 W.O. M 6 P Wash and ream in the hole from 9,209’ MD to 11,552’ MD with 20 RPM, 7-10K FT/LBS torque, 2 BBL per minute, 49 PSI. Rotating weight with light slack off 130 K, free rotating torque 8 K FT/LBS. 12:00 16:30 4.50 16.50 W.O. M 6 P Continue to Wash and ream in the hole from 11,552’ MD, pick up single and tag liner top at 12,674’ MD. Pick up 30’ and repeat setting down 10 K. Rotate on down stroke and reciprocate from, 12,673’ MD to 12,623’ 5 times with 20 RPM, 7-10K FT/LBS torque, 3 BBL per minute, 50 PSI. Rotating with light slack off 70 K, free rotating torque 8 K FT/LBS, pick up weight 150 K. 16:30 17:30 1.00 17.50 W.O. M 1 P Monitor well (no returns to surface). Blow down top drive and prepare to pull out of the hole on elevators. 17:30 18:00 0.50 18.00 W.O. M 4 P POOH and lay down single. Continue pulling out of hole from 12,673’ MD to 12,212’ MD while adding 10 bbls/hour and metal displacement over the top of the hole. 18:00 19:00 1.00 19.00 W.O. M 25 U Repair hydraulic leak on Iron Roughneck. 19:00 00:00 5.00 24.00 W.O. M 4 P Continue pulling out of hole from 12,212’ MD to 2,850’ MD while adding 10 bbls/hour and metal displacement over the top of the hole. Note: 24 Hour Loss of 8.6 ppg Brine = 447 bbls. Total Loss of 8.6 ppg Brine = 4499 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/17/2024 Report #: 22 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) 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 Temperature (°F) -1.7 Wind NE @ 9 MPH Days LTI (days) 2,353.00 Days RI (days) POB 39.0 Daily Summary Operations 24h Forecast Run in the hole with BHA #3 5-1/2” L1 lateral cleanout assembly to L1 heal. Pull out of the hole with BHA #3 and prepare for weekly BOP test. 24h Summary Continue to pull out of the hole with BHA #2. Cleanout and recover solids from magnets and Vacs tool. Clean up rig floor. Rig up GBR and 2-7/8” handling equipment. Make up BHA #3. Run in the hole with BHA #3 on 2-7/8” PH6 tubing with elevators to 11,802’ MD. Operation at 07.00 Back reaming. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. M 4 P Continue to pull out of the hole with 9-5/8” cleanout string from 2,850’ MD to surface. Recovered approximately 70 lbs of metal from magnets and 100 lbs of sand from the wash pipe. 04:00 06:00 2.00 6.00 W.O. M 1 P Clean out sand and metal from BHA #2. Lay down BHA #2. Clean up rig floor and rig up to make up BHA #3. Fill hole with 10 BBLS/hour of 8.6 ppg brine. 06:00 08:00 2.00 8.00 W.O. M 1 P Rig up GBR 2 7/8” handing equipment and power tongs to make up BHA #3. Fill hole with 10 BBLS/hour of 8.6 ppg brine. 08:00 12:00 4.00 12.00 W.O. M 5 P Make up BHA #3 5-1/2” L1 lateral cleanout assembly and run in the hole with BHA #3 on 2 7/8” PH6 to 1,463’ MD. Fill hole with 10 BBLS/hour of 8.6 ppg brine. 12:00 16:00 4.00 16.00 W.O. M 4 P Run in the hole with BHA #3 on 2 7/8” PH6 to 1,700’ MD. Fill hole with 10 BBLS/hour of 8.6 ppg brine. 16:00 00:00 8.00 24.00 W.O. M 4 P Continue to run in the hole on elevators with BHA #3 on 2-7/8” PH6 to 11,802’ MD. Tagged up and unable to slide down hole. Prepare to wash and ream down hole. Fill hole with 10 BBLS/hour of 8.6 ppg brine. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/18/2024 Report #: 23 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) 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 Temperature (°F) -3.5 Wind NE @ 12 MPH Days LTI (days) 2,354.00 Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Finish weekly BOP test per AOGCC. Make up BHA #4. RIH with 5-1/2” L1 lateral cleanout assembly to L1 heal (Cleanout Run #2). 24h Summary Fill 4” DP with 110 bbls 8.6 ppg brine. Wash and ream in the hole from 11,802’ MD to 13,909’ MD. Pull out of the hole recovering 630 lbs of sand packed in the bottom 7 jts of 2-7/8” PH6 tubing. Clean up equipment and rig floor. Flush BOP and lines. Remove wear ring and install test plug. Flush sand from BOP and lines. Install 4” test joint with TIW and pump in sub. Rig up test pump. Fluid pack all lines and fill BOP. Perform successful 250 psi low / 3500 psi high shell test. Operation at 07.00 Continue with weekly BOP test as per AOGCC. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 W.O. M 6 P Fill 4” DP capacity with 110 bbls 8.6ppg brine. Wash and ream in the hole with BHA #3 from 11,802’ MD to 12,776’ MD with 20 RPM, 8-10K FT/LBS torque, 2 BBL per minute, 52 PSI. Pick up weight 130K and 70K slack off weight, free rotating weight 8.8K FT/LBS. Tag sand bridge (102’ below liner top). Work pipe up and down 5 X’s to clean out bridge. 03:00 07:30 4.50 7.50 W.O. M 6 P Continue to wash and ream in the hole from 12,776’ MD to 13,909’ MD with 20 RPM, 10K FT/LBS torque, increase to 3 BBL per minute, 65 PSI. Pick up weight 135K and 70K slack off weight with rotary, free rotating weight 9.3K FT/LBS. Wash through several bridges from liner top 12,674’ MD to 13,909 MD. 07:30 12:00 4.50 12.00 W.O. M 4 P Blow down top drive and pull out of the hole on elevators from 13,909’ MD to 3,834’ MD. Fill hole with 10 bbls/hour plus metal displacement of 8.6 ppg brine. Up weight 180K. 12:00 20:00 8.00 20.00 W.O. M 4 P PJSM. Continue to pull out of the hole with BHA #3 on elevators from 3834’ MD to 1600’. Rig up GBR and pull 2-7/8” PH6 from 1600’ – surface. Fill hole with 10 bbls/hour plus metal displacement of 8.6 ppg brine. Recovered a total of 7 jts 2-7/8” PH6 tubing packed full of sand. Estimated weigh of recovered sand is 630 lbs. 20:00 21:00 1.00 21.00 W.O. M 1 P RDMO GBR equipment. Clean up equipment and rig floor. 21:00 23:30 2.50 23.50 W.O. C 5 P Remove wear ring and install test plug with Vault Rep. Flush sand BOP and lines. Install 4” test joint with TIW and pump in sub. Rig up test pump. Fluid pack all lines and fill BOP. 23:30 00:00 0.50 24.00 W.O. C 12 P Pressure up and obtained a successful shell test of 250 psi low and 3500 psi high. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/19/2024 Report #: 24 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) 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 Temperature (°F) -12.5 Wind NE @ 9 MPH Days LTI (days) 2,355.00 Days RI (days) POB 37.0 Daily Summary Operations 24h Forecast Continue run in hole with 5-1/2” L1 lateral cleanout assembly. 24h Summary Test BOPE as per AOGCC requirements with 2-7/8” and 4” test joints. Make up and run in the hole with 5-1/2” L1 lateral cleanout BHA #4. Operation at 07.00 Continue running in hole. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 11:30 11.50 11.50 W.O. C 12 P Test BOPE as per AOGCC requirements. Test annular with 2-7/8” and 4” test joints to 250 PSI low and 2,500 PSI high. Good test. Test all other components to 250 PSI low and 3,500 PSI high for 5 charted minutes. Good test. Test upper and lower 2- 7/8” variable pipe rams, blind shear rams, primary and secondary kill and choke manuals and HCR’s. Good test. Kill line valve. Upper and lower IBOP. 2-7/8” TIW and dart valve. Choke manifold valves 1-15 and A and B chokes. Test gas alarms and PVT alarms. Perform accumulator drawdown test with starting pressure of 3,000 PSI, 1,950 PSI after function, 200 PSI recovery 38 seconds, with full recovery at 101 seconds. N2 bottle average 4 at 2,950 PSI. Good test. BOPE test witness waived by AOGCC Sean Sullivan. 11:30 12:00 0.50 12.00 W.O. C 1 P Lay down test joint, rig down and blow down BOPs and lines. 12:00 19:30 7.50 19.50 W.O. M 4 P Make up BHA #4 vac’s tool, scraper and magnets for 5.5” liner clean out run. Run in the hole on 2 7/8” PH6 to 1620’ MD. Fill hole with 8.6 ppg brine at 10 BBLS / hour. Rig down GBR equipment. 19:30 00:00 4.50 24.00 W.O. M 4 P Change out tools from 2-7/8” to 4 “drill pipe. Continue to run in the hole on elevators from 1620’ MD to 7700’ MD at 24:00 HRS. Fill hole with 10 BBLS/hour of 8.6 ppg brine. Note: 24 Hour Loss of 8.6 ppg Brine = 9 bbls. Total Loss of 8.6 ppg Brine = 5570 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Levi Karns ASRC Energy Services HSE Levi.Karns@external.eni.com 907-685-0721 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/20/2024 Report #: 25 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) 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 Temperature (°F) -5.2 Wind NE @ 32 MPH Days LTI (days) 2,356.00 Days RI (days) POB 39.0 Daily Summary Operations 24h Forecast Waiting on weather. Depending on weather conditions, proceed with contingency trip in hole with 5-1/2” L1 lateral cleanout assembly. Gyrodata logging run on Halliburton E-line. 24h Summary Run in the hole with BHA #4 on elevators to 11,896’ MD. Fill 4” drill pipe capacity with 110 bbls 8.6 ppg brine. Begin washing and reaming in the hole from 11,896’ MD to 14,286’ MD. Pull out of the hole on elevators from 14,286’ MD to 1854’ MD. Perform slip and cut of the drill line. Phase 3 weather conditions initiated. Install TIW valve and secure well. Continue to Fill hole at 10 BBL/hour with 8.6 PPG brine. Operation at 07.00 Waiting on weather. Phase 3 conditions, shut down all life critical work. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. M 4 P Continue to run in the hole with BHA #4 on elevators from 7,700’ MD to 11,896’ MD. Decision made to begin washing and reaming in hole due to insufficient slack off weight. 04:00 10:30 6.50 10.50 W.O. M 6 P Fill 4” DP capacity with 110 bbls 8.6 ppg brine. Wash and ream in the hole from 11,896’ MD to 14,286’ MD with 20 RPM, 7-10K FT/LBS torque, ICP 3 BBL per minute, 103 PSI. FCP 3 BBL per minute, 345 PSI. Pick up weight 174 K, free rotating weight 50 -70 K, 9-11 FT/LBS torque. 10:30 11:30 1.00 11.50 W.O. M 4 P Pull out of hole on elevators from 14,286’ MD to 12,494’ MD. Pick up weight 145 K. Fill hole at 10 BBL/hour plus metal displacement with 8.6 PPG brine. 11:30 12:00 0.50 12.00 W.O. M 25 P Service rig draw works, ST-80 iron roughneck, hydraulic slips, and handling equipment. Fill hole at 10 BBL/hour plus metal displacement with 8.6 PPG brine. 12:00 19:00 7.00 19.00 W.O. M 4 P Continue pulling out of hole on elevators from 12,494’ MD to 1854’ MD. Fill hole at 10 bbls/hour plus metal displacement with 8.6 PPG brine. 19:00 23:00 4.00 23.00 W.O. M 25 TR99 Nordic crew performed slip and cut on drill line. Extra time needed due to repairs made on hydraulic cutter. 23:00 00:00 1.00 24.00 W.O. M 22 TW01 Phase 3 conditions initiated. Install TIW valve on 4” drill pipe. Secure well. Fill hole at 10 bbl/hour with 8.6 PPG brine. Note: 24 Hour Loss of 8.6 ppg Brine = 770 bbls. Total Loss of 8.6 ppg Brine = 6340 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/21/2024 Report #: 26 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) 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 Temperature (°F) 3.0 Wind NE @ 17 MPH Days LTI (days) 2,357.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Run in hole with 5-1/2” L1 lateral cleanout assembly and perform cleanout as per program. 24h Summary Phase 3 weather conditions. TIW valve installed on 4” drill pipe. Fill hole at 10 BBL/hour with 8.6 PPG brine. Phase 3 conditions lifted at 16:00 hrs. Pull out of the hole with vacs tool BHA recovering 15 lbs of metal from magnets. Rig up GBR. Pull out of the hole from 1760’ MD to 750’ MD. Operation at 07.00 Run in hole with 5-1/2” L1 lateral cleanout assembly. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 16:00 16.00 16.00 W.O. M 22 TW01 Phase 3 weather conditions. Waiting on weather. TIW valve installed on 4” drill pipe. Fill hole at 10 BBL/hour with 8.6 PPG brine. 16:00 00:00 8.00 24.00 W.O. M 4 P PJSM. Pull out of the hole with 3 joints of 4” drill pipe and vac’s tool BHA. Recovered 15 lbs of metal from magnets. Rig up GBR. Pull out of the hole from 1760’ MD to 750’ MD. Note: 24 Hour Loss of 8.6 ppg Brine = 229 bbls. Total Loss of 8.6 ppg Brine = 6549 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Jody Cornell ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/22/2024 Report #: 27 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) 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 Temperature (°F) -5.8 Wind NE @ 24 MPH Days LTI (days) 2,358.00 Days RI (days) POB 54.0 Daily Summary Operations 24h Forecast Pull out of hole with 5-1/2” L1 lateral cleanout assembly. Perform logging run on Halliburton E-line with Welltec Tractor as per program. 24h Summary Pull out of the hole from 750’ MD to surface. 6.5 joints of 2-7/8” PH6 tubing packed with sand (estimated recovery weight of 600 lbs). Make up BHA # 5. Run in the hole on elevators with 2-7/8” PH6 to 12,116’ MD. Washing and reaming in the hole from 12,116’ MD to 14,286’ MD. Pull out of the hole on elevators from 14,286’ MD to 14,086’ MD. Operation at 07.00 Pull out of hole. Lay down 5-1/2” L1 lateral cleanout assembly. 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. M 4 P Pull out of the hole from 750’ MD to surface. 6.5 joints of 2-7/8” PH6 tubing packed with sand (estimated 600 lbs of sand recovered). 01:30 12:00 10.50 12.00 W.O. M 4 P Clean the rig floor and equipment. Make up BHA #5 vac’s tool, scraper, and magnets for 5.5” liner clean out run. Run in the hole on 2-7/8” PH6 to 11,553’ MD. Fill hole with 8.6 ppg brine at 10 BBLS / hour. Rig down GBR equipment. 12:00 13:30 1.50 13.50 W.O. M 4 P Run in the hole on 2-7/8” PH6 from 11,553’ MD to 12,116’ MD. Pick up weight 105K, slack off weight 48K. Fill hole with 8.6 ppg brine at 10 BBLS / hour. 13:30 23:00 9.50 23.00 W.O. M 6 P Wash and ream in the hole from 12,116’ MD to 14,286‘ MD, 20 RPM, 7-10K FT/LBS torque, pumping at 3 BPM with 0 PSI to 100 PSI. Add 1% lube to 8.6 ppg brine. Stopped rotary at 14,286’, increased pump rate to 4 BPM for 50 BBLs total pumped. ICP 4 BBL per minute, 470 PSI. FCP 4 BBL per minute, 600 PSI. Pick up weight 160 K, free rotating weight 50-70 K, 9-11 FT/LBS torque. 23:00 00:00 1.00 24.00 W.O. M 4 P Pre job safety meeting. Pull out of hole on elevators from 14,286’ MD to 14,086’ MD. Pick up weight 160 K. Fill hole at 10 BBL/hour plus metal displacement with 8.6 PPG brine. Note: 24 Hour Loss of 8.6 ppg Brine = 350 bbls. Total Loss of 8.6 ppg Brine = 6899 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/23/2024 Report #: 28 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) 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 Temperature (°F) -14.4 Wind NE @ 14 MPH Days LTI (days) 2,359.00 Days RI (days) POB 54.0 Daily Summary Operations 24h Forecast Mobilize fishing tools. Make up fishing BHA and run in hole. 24h Summary Pull out of hole on elevators from 14,086’ MD to 1,759’ MD. Lay down vac’s tool, scraper, and magnets. Pull out of hole laying down 2-7/8” PH6 tubing. Rig up Halliburton E-line. Make up E-line BHA#1, Gyrodata MicroDLS and 60 MFC logging tool with Welltec 318 tractor. Operation at 07.00 Mobilizing fishing tools. 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 P Service ST-80 iron roughneck, hydraulic slips, and handling equipment. 00:30 06:00 5.50 6.00 W.O. M 4 P Pull out of hole on elevators from 14,086’ MD to 1,759’ MD. Fill hole at 10 BPH plus metal displacement with 8.6 PPG brine. 06:00 08:00 2.00 8.00 W.O. M 20 P Pre job safety meeting. Lay down vac’s tool, scraper, and magnets. Recovered 30 LBS of metal shavings on magnets and 30 LBS of sand in wash pipe. Fill hole at 10 BPH with 8.6 PPG brine. 08:00 15:30 7.50 15.50 W.O. M 4 P Rig up GBR equipment and change elevators. Pull out of hole laying down 2-7/8” PH6 tubing. 5.5 joints of 2-7/8” PH6 tubing packed with sand (estimated recovery weight of 500 lbs). Fill hole at 10 BPH plus metal displacement with 8.6 PPG brine. 15:30 17:00 1.50 17.00 W.O. M 20 P Rig down GBR equipment. Clean and organize rig floor. Demobilize vac’s tool and wash pipe from pipe shed. Fill hole at 10 BPH with 8.6 PPG brine. 17:00 19:30 2.50 19.50 W.O. R 20 TD99 Pre job safety meeting with Halliburton, Welltec, and Gyrodata. While in the process of loading wireline tools in pipe shed one end of the tool dropped approx. 12’ to the ground level and the other end remained suspended on the pipe elevator platform. Stop the job and investigate what caused the incident. Recover the wireline tool. Held safety standdown with Nordic, Halliburton, Welltec, and Gyrodata. Fill hole at 10 BPH with 8.6 PPG brine. 19:30 00:00 4.50 24.00 W.O. R 20 P Rig up Halliburton E-line. Make up E-line Run #1 BHA, Gyrodata MicroDLS and 60 MFC logging tool with Welltec 318 tractor. Function test tools, good test. Fill hole at 10 BPH with 8.6 PPG brine. Note: 24 Hour Loss of 8.6 ppg Brine = 763 bbls. Total Loss of 8.6 ppg Brine = 7662 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/24/2024 Report #: 29 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) 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 Temperature (°F) -13.9 Wind NE @ 5 MPH Days LTI (days) 2,360.00 Days RI (days) POB 61.0 Daily Summary Operations 24h Forecast Fish for Welltec 318 tractor and logging tools. 24h Summary Run in hole with Gyrodata MicroDLS and 60 MFC logging tool with Welltec 318 tractor and rope socket backed off from Welltec SW 218 swivel at 3276’ WLM. Mobilize fishing tools to location. Run in hole with fishing BHA #1 and attempt to latch fish multiple times without success from 3284’ WLM to 3608’ WLM. Pull out of hole and inspect grapple. Run in hole with fishing BHA #1 and attempt to latch fish at 3608’ WLM. Operation at 07.00 Making up fishing BHA #2. 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. R 4 P E-line Run #1 with Gyrodata MicroDLS and 60 MFC logging tool with Welltec 318 tractor, 80.56’, 596 LBS, Max OD 4.0”. Run in hole and deviate out at 3148’ WLM. Engage Welltec 318 tractor at 45 FPM from 3148’ WLM to 3276’ WLM. 02:00 03:30 1.50 3.50 W.O. R 4 TD04 Lost communication with tool. Troubleshoot communication loss and pull out of hole. Rope socket had backed off from Welltec SW 218 swivel. 79.32’ fish left in hole. Fill hole at 10 BPH with 8.6 PPG brine. 03:30 12:00 8.50 12.00 W.O. R 1 TD04 Lay down tools and transport Welltec tractor to Deadhorse shop for inspection. Expedite Halliburton fishing assembly to location. Perform derrick inspection. Service catwalk, blocks, crown and top drive assembly. Stage 100 JTS of 2-7/8” Hydril Wedge 563 tubing on drillers side of pipe shed for middle completion. Fill hole at 10 BPH with 8.6 PPG brine. 12:00 15:00 3.00 15.00 W.O. R 2 TD04 Continue inspecting Welltec tractor (good). Transport Welltec tractor from Deadhorse to location. Fill hole at 10 BPH with 8.6 PPG brine. 15:00 19:00 4.00 19.00 W.O. R 20 TD04 Perform post transport electrical checks on Welltec tractor. Make up fishing BHA #1, 3.60” bell guide with short catch overshot dressed with 1.5” basket grapple, 1.785” long stroke spang jars, 1.75” oil jars, knuckle joint, and Welltec 318 tractor, 43.63’, Max OD 3.60”. Fill hole at 10 BPH with 8.6 PPG brine. 19:00 23:00 4.00 23.00 W.O. R 13 TD04 E-line Run #2. Run in hole with fishing BHA #1, 3.60” bell guide with short catch overshot dressed with 1.5” basket grapple to 3284’ WLM. 733 LBS UW line tension at 3200’ WLM. Engage Welltec 318 tractor and attempt to latch fish multiple times without success from 3284’ WLM to 3608’ WLM. Twice line tension was between 900 LBS and 947 LBS UW before dropping back down to ~700 LBS UW line tension. Pull out of hole and inspect grapple. Grapple showed no indication of pulled threads. Fill hole at 10 BPH with 8.6 PPG brine. 23:00 00:00 1.00 24.00 W.O. R 13 TD04 E-line Run #3. Run in hole with fishing BHA #1, 3.60” bell guide with short catch overshot dressed with 1.5” basket grapple to 3608’ WLM. 730 LBS UW line tension at 3500’ WLM. Engage Welltec 318 tractor and attempt to latch fish. Fill hole at 10 BPH with 8.6 PPG brine. Note: 24 Hour Loss of 8.6 ppg Brine = 161 bbls. Total Loss of 8.6 ppg Brine = 7823 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/25/2024 Report #: 30 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) 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 Temperature (°F) -18.6 Wind NE @ 7 MPH Days LTI (days) 2,361.00 Days RI (days) POB 64.0 Daily Summary Operations 24h Forecast Perform logging run on Halliburton E-line with Welltec Tractor as per program. Test BOPE as per AOGCC requirements. 24h Summary Run in hole with fishing BHA #1, 3.60” bell guide with short catch overshot dressed with 1.5” basket grapple and latch fish at 3,828’ WLM. Pull out of hole and recover Welltec WRD section. Run in hole with fishing BHA #2, 3.60” bell guide, 2.60” bell guide, 2” RB pulling tool and latch fish at 4,070’ WLM. Pull out of hole and recover Welltec 318 tractor with remaining logging tool string. Run in hole with E-line Run #5, Gyrodata MicroDLS and 60 MFC logging tool with Welltec 318 tractor to 10,010’ WLM. Operation at 07.00 Logging with MicroDLS. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:00 5.00 5.00 W.O. R 13 TD04 Attempt to latch fish multiple times without success from 3,608’ WLM to 3,828’ WLM before latching fish at 3,828’ WLM with 990 LBS UW line tension. Worked spang jars down twice and pickup to 3,806’ WLM. Wait 75 minutes before attempting to pull out of hole allowing timer to release Welltec WRD with ~800 LBS static line tension. Pick up from 3,806’ WLM to 3,795’ WLM before line tension decreased from 980 LBS UW to 730 LBS UW. Pull out of hole at 35 FPM. Fill hole at 10 BPH with 8.6 PPG brine. 05:00 11:00 6.00 11.00 W.O. R 20 TD04 Fish at surface. Lay down fishing BHA #1. Inspect and fill Welltec tractor with oil. Assemble fishing BHA #2 with Welltec tractor, knuckle, long spang jars, 3.60 OD x 32.0”L bell guide over 2.60 OD x 21”L bell guide, over 2” RB pulling tool pinned with 5/16 steel. Fill hole at 10 BPH with 8.6 PPG brine. 11:00 14:00 3.00 14.00 W.O. R 13 TD04 RIH with fishing BHA #2 from surface to 3,829’ WLM and locate top of fish. Work over fish from 3,829’ WLM to 4,070’ WLM. Observe 4.5 AMP draw on Welltec tractor. Pick up and verify latch with 400 LBS overpull. Up wt = 1,100 LBS. POOH to surface with fish. Fill hole at 10 BPH with 8.6 PPG brine. 14:00 17:30 3.50 17.50 W.O. R 20 TD04 Lay down fish. Inspect and fill Welltec tractors with oil. Change batteries in GiroData MicroDLS logging tool. Fill hole at 10 BPH with 8.6 PPG brine. 17:30 20:00 2.50 20.00 W.O. R 5 P Make up E-line Run #5 BHA, Gyrodata MicroDLS and 60 MFC logging tool with Welltec 318 tractor. Function test tools, good test. Fill hole at 10 BPH with 8.6 PPG brine. 20:00 00:00 4.00 24.00 W.O. R 4 P E-line Run #5, Gyrodata MicroDLS and 60 MFC logging tool with Welltec 318 tractor, 79.57’, 747 LBS, Max OD 4.0”. Run in hole and deviate out at 3,433’ WLM. Engage Welltec 318 tractor at 37 FPM from 3,433’ WLM to 10,010’ WLM. Fill hole at 10 BPH with 8.6 PPG brine. Note: 24 Hour Loss of 8.6 ppg Brine = 269 bbls. Total Loss of 8.6 ppg Brine = 8062 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/26/2024 Report #: 31 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) 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 Temperature (°F) -18.4 Wind SW @ 14 MPH Days LTI (days) 2,362.00 Days RI (days) POB 57.0 Daily Summary Operations 24h Forecast Continue to test BOPE as per AOGCC requirements. Run in hole with 5-1/2” L1 lateral cleanout assembly. 24h Summary Run in hole with E-line Run #5, Gyrodata MicroDLS and 60 MFC logging tool with Welltec 318 tractor from 10,010’ WLM to 12,698’ MD. Pull out of hole with caliper log at 50 FPM to surface. Lay down Halliburton, Welltec, and Gyrodata wireline tools. Pull wear bushing and set test plug in wellhead with Vault representative. Rig up to test BOPE. Test BOPE as per AOGCC requirements with 4” test joint. Operation at 07.00 Rig down test equipment. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 11:00 11.00 11.00 W.O. R 11 P Run in hole with E-line Run #5, Gyrodata MicroDLS and 60 MFC logging tool with Welltec 318 tractor at 37 FPM from 10,010’ WLM to 12,698’ MD after correlation to pipe tally, -20’ correction. Pull up to 12,670.3’ MD (CCL) with Gyro sensor at 12,691.4’ MD. Pull out of hole with caliper log at 50 FPM to surface. Fill hole at 10 BPH with 8.6 PPG brine. 11:00 12:00 1.00 12.00 W.O. R 1 P Lay down Halliburton, Welltec, and Gyrodata wireline tools. Fill hole at 10 BPH with 8.6 PPG brine. 12:00 14:30 2.50 14.50 W.O. R 20 P Download logging data from GyroData MicroDLS logging tool and Halliburton multifinger caliper logging tool. Unload wireline tools from rig. Inspect Welltec tractor, fill with oil, and function test (good). Fill hole at 10 BPH with 8.6 PPG brine. 14:30 17:00 2.50 17.00 W.O. C 1 P Pick up stack washer, wash wellhead and BOP stack. Pull wearbushing and set test plug in wellhead with Vault representative. Rig up to test BOPE. Fill hole at 10 BPH with 8.6 PPG brine. 17:00 00:00 7.00 24.00 W.O. C 12 P Test BOPE as per AOGCC requirements with 4” test joint, 250 PSI low and 3500 PSI high for 5 minutes each test and charted. Choke valve #7 had a fail / pass test. AOGCC Inspector Kam StJohn waived witness for BOPE test. Fill hole at 10 BPH with 8.6 PPG brine. Note: 24 Hour Loss of 8.6 ppg Brine = 234 bbls. Total Loss of 8.6 ppg Brine = 8256 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/27/2024 Report #: 32 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) 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 Temperature (°F) -15.2 Wind SW @ 20 MPH Days LTI (days) 2,363.00 Days RI (days) POB 55.0 Daily Summary Operations 24h Forecast Troubleshoot spin function on top drive. Run in hole with 5-1/2” L1 lateral cleanout assembly. 24h Summary Test BOPE as per AOGCC requirements with 2-7/8” and 4” test joints. (Good Test) Make up BHA #6, 5-1/2” L1 lateral cleanout assembly. Run in the hole on elevators with 2-7/8” PH6 tubing to 12,629’ MD. Troubleshoot spin function on top drive. Operation at 07.00 Pull out of Hole with cleanout assembly. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:30 5.50 5.50 W.O. C 12 P Continue testing BOPE as per AOGCC requirements. Test annular with 2-7/8” and 4” test joints to 250 PSI low and 2,500 PSI high. (Good Test) Test all other components to 250 PSI low and 3,500 PSI high for 5 charted minutes. (Good Test) Test upper and lower 2-7/8” variable pipe rams, blind shear rams, primary and secondary kill and choke manuals and HCR’s. (Good Test) Kill line valve. Upper and lower IBOP. 2-7/8” TIW and dart valve. (Good Test) Choke manifold valves 1-15 and A and B chokes. (Good Test) Test gas alarms and PVT alarms. Fail pass on Choke valves #1 and #7. Fail 4” TIW, replace and test new one. (Good Test) Perform accumulator drawdown test with starting pressure of 3050 PSI, 2125 PSI after function, 200 PSI recovery 28 seconds, with full recovery at 75 seconds. Good Test) N2 bottle average 4 at 2,869 PSI. Fill hole with 8.6 ppg brine at 10 BBLS / hour. Note: Witness waived by AOGCC rep Kam StJohn. 05:30 06:00 0.50 6.00 W.O. C 12 P Lay down test joint and rig down test pump. Blow down BOPs and lines. 06:00 08:00 2.00 8.00 W.O. C 12 P Pull test plug and install wear bushing as per Vault representative. Fill hole with 8.6 ppg brine at 10 BBLS / hour. 08:00 13:00 5.00 13.00 W.O. M 4 P Make up BHA #6, VAC’s tool, scraper and magnets for 5.5” liner clean out run. Rig up GBR casing equipment. Run in the hole on 2-7/8” PH6 to 955’ MD. Change out tools from 2-7/8” to 4” drill pipe. Rig down GBR equipment. Fill hole with 8.6 ppg brine at 10 BBLS / hour. 13:00 23:00 10.00 23.00 W.O. K 4 P Run in the hole on 2-7/8” PH6 from 955’ MD to 12,629’ MD. Pick up weight 101K, slack off weight 75K. Fill hole with 8.6 ppg brine at 10 BBLS / hour. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Justin Hays ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/28/2024 Report #: 33 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) 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 Temperature (°F) -23.4 Wind SW @ 21 MPH Days LTI (days) 2,364.00 Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast Run in hole with 7” tie back bullet seal assembly with Spargauge BHP gauges to SLXP liner top at 12,642’ MD. Test 9-5/8” casing as procedure. Pull out of hole laying down 4” drill pipe. 24h Summary Troubleshoot spin function on top drive, with success. Wash in the hole from 12,629’ MD to 13,482’ MD. Pull out of the hole on elevators from 13,482’ MD to 955’ MD. Lay down VAC’s, scraper, and magnet BHA. Rig up GBR power tongs. Pull out of hole laying down 2-7/8” PH6 tubing. Finish breaking down VAC’s tool and wash pipe. Organize rig floor and pipe shed. Operation at 07.00 Run in hole 7" tieback bullet seal assembly to test casing. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. M 25 TR04 Troubleshoot spin function on top drive. Contacted PECO support and log into computer software and check communication on top drive system. Powered down VFD and regained TDS communications. 02:30 05:00 2.50 5.00 W.O. M 9 P Wash in the hole from 12,629’ MD to 13,482’ MD pumping at 3 BPM with 0 PSI to 100 PSI. Add 2.5% Lotorq lube to 8.6 ppg brine. Once at 13,482’ increased pump rate to 4 BPM for 50 BBLs total pumped. ICP 4 BBL per minute, 390 PSI. FCP 4 BBL per minute, 480 PSI. Pick up weight 105K, down weight 70K. 05:00 14:30 9.50 14.50 W.O. M 4 P Pull out of the hole on elevators from 13,482’ MD to 955’ MD. Lay down VAC’s, scraper, and magnets. Recovered 8 LBS of metal shavings from magnets. No sand in VAC’s tool. Fill hole at 10 BPH plus metal displacement with 8.6 PPG brine. 14:30 15:00 0.50 15.00 W.O. M 1 TS03 Rig up GBR power tongs. Power pack unit not running correctly. 15:00 19:00 4.00 19.00 W.O. M 1 TS03 15:00 – 19:00 4.0 HRS Swap out power pack unit. Unable to get backup power pack unit started, install heater to warmup. 19:00 20:30 1.50 20.50 W.O. M 4 P Pull out of hole laying down 2-7/8” PH6 tubing. Recovered 0.22 GLS (1’ inside tubing) of sand above bottom flapper. Fill hole at 10 BPH plus metal displacement with 8.6 PPG brine. 20:30 00:00 3.50 24.00 W.O. M 1 P Rig down GBR equipment. Change pipe elevators to 4”. Clean and organize rig floor. Finish breaking down VAC’s tool and wash pipe. Organize pipe shed. Fill hole at 10 BPH with 8.6 PPG brine. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 2/29/2024 Report #: 34 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) 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 Temperature (°F) -23.3 Wind SW @ 17 MPH Days LTI (days) 2,365.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Pull out of hole laying down 4” drill pipe and 7” tie back bullet seal assembly with Spargauge BHP gauges. Load pipe shed with 2-7/8” upper completion tubing and process. 24h Summary Organize pipe shed and bring in 7” tie back bullet seal assembly. Run in hole with 7” tie back bullet seal assembly with Spargauge BHP gauges to SLXP liner top at 12,642’ MD. Sting into SLXP liner top at 12,676’ MD. Perform MIT on A-Annulus to 2000 PSI. Good test. Pull out of hole laying down 4” drill pipe to 9,621’ MD. Operation at 07.00 Pull out of hole laying down 4" 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 1 P Organize pipe shed and bring in 7” tie back bullet seal assembly. Fill hole at 10 BPH with 8.6 PPG brine. 01:00 03:00 2.00 3.00 W.O. M 1 P Make up BHA #7, 7” tie back bullet seal assembly with Spargauge BHP gauges, 49.75’ length of BHA. Fill hole at 10 BPH with 8.6 PPG brine. 03:00 12:00 9.00 12.00 W.O. K 5 P Run in hole with 7” tie back bullet seal assembly with Spargauge BHP gauges at 90 FPM from 49.75’ to 12,676’ MD. Fill hole at 10 BPH with 8.6 PPG brine. 12:00 17:00 5.00 17.00 W.O. K 12 P Sting into SLXP liner top at 12,676’ MD. Slack off to NoGo at 12,686’ MD. Fill A-Annulus with 71 BBLs of 8.6 PPG brine. Perform MIT on A-Annulus to 2000 PSI. Initial 2120 PSI, 2100 PSI after first 15 minutes, 2100 PSI after second 15 minutes. 20 PSI total loss after 30 minutes. Pumped 8 BBLs with 7.9 BBLs returned. Good test. 17:00 20:30 3.50 20.50 W.O. M 1 P Prepare pipe shed and horseshoe to lay down 4” drill pipe. Fill hole at 10 BPH with 8.6 PPG brine. 20:30 00:00 3.50 24.00 W.O. K 4 P Pull out of hole laying down 4” drill pipe to 9,621’ MD. Fill hole at 10 BPH plus pipe displacement with 8.6 PPG brine. Note: 24 Hour Loss of 8.6 ppg Brine = 144 bbls. Total Loss of 8.6 ppg Brine = 9,164 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Eni representative Giorgio Ianucci Eni Drilling Manager Giorgio.Iannucci@eni.com Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/1/2024 Report #: 35 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) 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 Temperature (°F) -25.8 Wind S @ 16 MPH Days LTI (days) 2,366.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Load off driller side pipe shed with 2 7/8” W563, 6.4 PPF, L-80 upper completion tubing and process. Run 2 7/8” W563, 6.4 PPF, L-80 completion tubing as procedure. 24h Summary Pull out of hole laying down 4” drill pipe to BHA. Rig up GBR casing tongs. Continue pull out of hole laying down fishing jars. Break down seal assembly and retrieve Spargauge memory gauge. Remove wear bushing with Vault representative. Unload pipe shed of 4” drill pipe, 2 7/8” PH6 tubing, and Baker fishing tools. Load off driller side pipe shed with 2 7/8” W563 6.4 PPF L-80 upper completion tubing and process. Operation at 07.00 Loading pipe shed with 2-7/8" completion 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. M 1 P Service rig. Grease traveling block, crown, and top drive. Inspect handling equipment and ST-80 dies. 01:00 11:00 10.00 11.00 W.O. K 4 P Pull out of the hole with the bullet seal assembly laying down 4” drill pipe from 9,621’ to 49’. Fill hole at 10 BPH plus pipe displacement with 8.6 PPG brine. 11:00 13:30 2.50 13.50 W.O. K 4 P Rig up GBR casing tongs. Continue pull out of hole laying down fishing jars. Break down seal assembly and retrieve Spargauge memory gauge. Fill hole at 10 BPH plus pipe displacement with 8.6 PPG brine. 13:30 14:00 0.50 14.00 W.O. K 5 P Remove wear bushing with Vault representative. 14:00 17:30 3.50 17.50 W.O. K 1 P Permitting, lift plan for loader operator. Unload pipe shed of 4” drill pipe, 2 7/8” PH6 tubing, and Baker fishing tools. Fill hole at 10 BPH with 8.6 PPG brine. 17:30 00:00 6.50 24.00 W.O. K 1 P Load off driller side pipe shed with 2 7/8” W563, 6.4 PPF, L-80 upper completion tubing and process. Load Baker Centrilift ESP Assembly in pipe shed on driller side. Fill hole at 10 BPH with 8.6 PPG brine. 24 Hour Loss of 8.6 ppg Brine = 281 bbls. Total Loss of 8.6 ppg Brine = 9,445 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Eni representative Giorgio Ianucci Eni Drilling Manager Giorgio.Iannucci@eni.com Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/2/2024 Report #: 36 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) 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 Temperature (°F) -11.7 Wind SW @ 17 MPH Days LTI (days) 2,367.00 Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Make test run to liner top at 12,642’ MD with 2-7/8” mule shoe. 24h Summary Load off driller side pipe shed with 2-7/8” W563, 6.4 PPF, L-80 upper completion tubing and process. Install wear bushing with Vault representative. Rig up GBR tubing tongs. Make up 2-7/8” mule shoe. Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 tubing from pipe shed to 4,141’. Operation at 07.00 Running in hole picking up 2-7/8" tubing. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 17:00 17.00 17.00 W.O. M 1 P Load off driller side pipe shed with 2-7/8” W563, 6.4 PPF, L-80 upper completion tubing and process. Total 410 joints. Fill hole at 10 BPH with 8.6 PPG brine. 17:00 17:30 0.50 17.50 W.O. K 5 P Install wear bushing with Vault representative. 17:30 18:00 0.50 18.00 W.O. K 1 P Rig up GBR tubing tongs. 18:00 00:00 6.00 24.00 W.O. K 4 P Make up 2-7/8” mule shoe. Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 tubing from pipe shed to 4,141’, 58K UW, 57K DW. Fill hole at 10 BPH with 8.6 PPG brine. 24 Hour Loss of 8.6 ppg Brine = 243 bbls. Total Loss of 8.6 ppg Brine = 9,577 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Safety Representative David Fleming Nordic HSE David.Fleming@nordic-calista.com 907-685-8603 Safety Representative Jon Castle Nordic HSE 907-685-8603 Tool Push Sean Stuckart Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Eni representative Giorgio Ianucci Eni Drilling Manager Giorgio.Iannucci@eni.com Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/3/2024 Report #: 37 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) 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 Temperature (°F) -4.7 Wind NE @ 13 MPH Days LTI (days) 2,368.00 Days RI (days) POB 57.0 Daily Summary Operations 24h Forecast Pull out of hole laying down 2-7/8” tubing from 2,380’ to surface. Test BOPE as per AOGCC requirements with 2-7/8” test joint. Rig up Baker Centrilift to run ESP completion string. Run in hole with 2-7/8” upper completion ESP string. 24h Summary Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 tubing from pipe shed to top of liner at 12,674’ MD. Service rig. Pull out of the hole laying down 2-7/8” tubing from 12,674’ to 2,380’. 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 09:00 9.00 9.00 W.O. K 4 P Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 tubing from pipe shed to top of liner at 12,674’, 70K UW, 61K DW. Fill hole at 10 BPH with 8.6 PPG brine. 09:00 09:30 0.50 9.50 W.O. K 1 P Service rig. Grease traveling block, crown, and top drive. Inspect handling equipment and ST-80 dies. 09:30 00:00 14.50 24.00 W.O. K 4 P Pull out of hole laying down 2-7/8” tubing from 12,674’ to 2,380’ into pipe shed, 56K UW, 55K DW. Fill hole at 10 BPH plus pipe displacement with 8.6 PPG brine. Note: 24 Hour Loss of 8.6 ppg Brine = 255 bbls. Total Loss of 8.6 ppg Brine = 9,985 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/4/2024 Report #: 38 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) 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 Temperature (°F) -16.8 Wind NE @ 17 MPH Days LTI (days) 2,369.00 Days RI (days) POB 57.0 Daily Summary Operations 24h Forecast Rig up Baker Centrilift to run ESP completion string. Run in hole with 2-7/8” upper completion ESP string. 24h Summary Pull out of hole laying down 2-7/8” tubing from 2,380’ to surface. Test BOPE as per AOGCC requirements with 2-7/8” test joint. Rig up Baker Centrilift to run ESP completion string. Operation at 07.00 Rigging up to run ESP completion. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. K 4 P Pull out of hole laying down 2-7/8” tubing from 2,380’ to surface into pipe shed. Fill hole at 10 BPH plus pipe displacement with 8.6 PPG brine. 04:00 04:30 0.50 4.50 W.O. K 20 P Rig down GBR tubing tongs. 04:30 06:00 1.50 6.00 W.O. C 1 P Remove wear bushing with Vault representative and install test plug. Make up test assembly. Fill hole at 10 BPH with 8.6 PPG brine. 06:00 10:30 4.50 10.50 W.O. C 12 P Test BOPE as per AOGCC requirements with 2-7/8” test joint Test annular with 2-7/8” test joint to 250 PSI low and 2,500 PSI high. Test all other components to 250 PSI low and 3,500 PSI high for 5 charted minutes. Test upper and lower 2-7/8” variable pipe rams, blind shear rams, primary and secondary kill and choke manuals and HCR’s. Kill line valve. Upper and lower IBOP. 2-7/8” TIW and dart valve. Choke manifold valves 1-15 and A and B chokes. Test gas alarms and PVT alarms. Perform accumulator drawdown test with starting pressure of 2980 PSI, 2025 PSI after function, 200 PSI recovery 29 seconds, with full recovery at 87 seconds. N2 bottle average 4 at 2,887 PSI. AOGCC Inspector Brian Bixby waived witness for BOPE test. Fill hole at 10 BPH with 8.6 PPG brine. (Good Tests) 10:30 12:00 1.50 12.00 W.O. C 20 P Lay down test joint and rig down test pump. Blow down BOPs and lines. Pull test plug with Vault representative. 12:00 13:00 1.00 13.00 W.O. K 1 P Clean and organize rig floor for running 2-7/8” upper completion. Fill hole at 10 BPH with 8.6 PPG brine. 13:00 13:30 0.50 13.50 W.O. K 1 P Reviewed the lift plan and held pre-job safety meeting prior to mobilizing ESP spools and equipment to the rig floor. 13:30 22:30 9.00 22.50 W.O. K 1 P Begin mobilizing all ESP equipment to the rig floor. Unable to install two capillary spools on rig floor for trip in the hole. Spool 1,000’ of capillary line on a 12,000’ spool in order to have just one capillary spool on the rig totaling 13,000’. Fill hole at 10 BPH with 8.6 PPG brine. 22:30 00:00 1.50 24.00 W.O. K 1 P Pre job safety meeting with Worley crane crew, Baker Centrilift, and rig crew. Load capillary line spool, ESP hydraulic spooling unit, and power pack on the rig. Fill hole at 10 BPH with 8.6 PPG brine. Note: 24 Hour Loss of 8.6 ppg Brine = 226 bbls. Total Loss of 8.6 ppg Brine = 1,021 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/5/2024 Report #: 39 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) 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 Temperature (°F) -20.7 Wind NE @ 14 MPH Days LTI (days) 2,370.00 Days RI (days) POB 59.0 Daily Summary Operations 24h Forecast Run in hole with 2-7/8” upper completion ESP string. 24h Summary While in the process of unloading middle completion packer assembly from the pipe shed the tool dropped 25 ft. Stop work and Job safety analysis performed with all crews, packer removed and normal operation resumed. Mobilize ESP equipment to the rig floor. Rig up Baker Centrilift to run ESP completion string. Make up ESP assembly and run in hole to 81’. Operation at 07.00 Running in hole completion string. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:00 5.00 5.00 W.O. K 1 TR99 While in the process of unloading middle completion packer assembly from the pipe shed the tool dropped ~25’ to the ground level and the other end remained suspended behind the pipe elevator platform railing above a hydraulic cylinder. Held safety standdown with Nordic, Baker, Worley, and ENI Safety. Obtain permit to work and lift plan. Fill hole at 10 BPH with 8.6 PPG brine. 05:00 06:00 1.00 6.00 W.O. K 1 U Pre job safety meeting and lift meeting for removing Halliburton packer from pipe shed and stairwell. Remove the Halliburton packer from behind stairwell and pipe elevator platform railing. Fill hole at 10 BPH with 8.6 PPG brine. 06:00 11:00 5.00 11.00 W.O. K 1 P Continue to mobilize the ESP equipment to the rig floor and rig up to run ESP completion string. Load ESP cable onto hydraulic spooler. Pick up ESP pump and load pipe shed with the shroud. Fill hole at 10 BPH with 8.6 PPG brine. 11:00 12:30 1.50 12.50 W.O. K 1 U Safety stand down with both crews and Anchorage team. Discussed preventing dropped objects and recent drops incidents. 12:30 00:00 11.50 24.00 W.O. K 4 P Pick up and run 7-5/8” motor shroud into the hole. Pick up ESP pump assembly, service motor and seal assemblies. Verify free rotation on connections. Test dual capillary lines and ESP continuity. Install shroud bushing. Make up ESP assembly and run in hole to 81’. Fill hole at 10 BPH with 8.6 PPG brine. 24 Hour Loss of 8.6 ppg Brine = 328 bbls. Total Loss of 8.6 ppg Brine = 1,539 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/6/2024 Report #: 40 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) 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 Temperature (°F) -16.4 Wind N @ 3 MPH Days LTI (days) 2,371.00 Days RI (days) POB 58.0 Daily Summary Operations 24h Forecast Run in hole with 2-7/8” upper completion ESP string. 24h Summary Run in the hole with 2-7/8” upper completion ESP string from 81’ to 5,782’. Perform electrical checks every 1,000’. Pump tubing capacity every 3,000’. Operation at 07.00 Run in hole completion string. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 W.O. K 4 P Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 upper completion ESP string from 81’ to 2,068’, 60K UW, 60K DW. Torque turn each connection to 2000 FT/LBS torque. Superior thread representative inspected threads and witnessed make up. Drift each joint to 2.347”. Perform electrical checks every 1000’, maintain ~1000 PSI on dual capillary tubing while run in hole. Repair capillary line splice at 1,200’. Fill hole at 10 BPH with 8.6 PPG brine. 12:00 00:00 12.00 24.00 W.O. K 4 P Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 upper completion ESP string from 2,068’ to 5,782’, 70K UW, 60K DW. Torque turn each connection to 2000 FT/LBS torque. Superior thread representative inspected threads and witnessed make up. Drift each joint to 2.347”. Perform electrical checks every 1000’, maintain ~1000 PSI on dual capillary tubing while run in hole. Pump tubing capacity every 3,000’. Fill hole at 10 BPH with 8.6 PPG brine. Note: 24 Hour Loss of 8.6 ppg Brine = 207 bbls. Total Loss of 8.6 ppg Brine = 10,746 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 907-685-8603 Area Manager Stefano Pierfelici Eni SEQ Director stefano.pierfelici@eni.com Drilling Engineer Amjad Chaudhry Eni Sr. Drilling Engineer amjad.chaudhry@eni.com 907-865-3379 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/7/2024 Report #: 41 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) 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 Temperature (°F) -26.1 Wind SW @ 9 MPH Days LTI (days) 2,372.00 Days RI (days) POB 57.0 Daily Summary Operations 24h Forecast Run in hole with 2-7/8” upper completion ESP string and land in wellhead with tubing hanger. Nipple down BOPE and install X-mas tree. 24h Summary Run in the hole with 2-7/8” ESP upper completion from 5,782’ to 10,302’. Perform electrical checks every 1,000’. Pump tubing capacity every 3,000’. Baker Centrilift spliced ESP cable together at 7,588’, witnessed by ENI electrician. Operation at 07.00 Making up Hangar. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 07:30 7.50 7.50 W.O. K 4 P Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 upper completion ESP string from 5,782’ to 7,486’, 70K UW, 60K DW. Torque turn each connection to 2000 FT/LBS torque. Superior thread representative inspected threads and witnessed make up. Drift each joint to 2.347”. Perform electrical checks every 1000’, maintain ~1000 PSI on dual capillary tubing while run in hole. Pump tubing capacity every 3,000’. Fill hole at 10 BPH with 8.6 PPG brine. 07:30 13:30 6.00 13.50 W.O. K 20 P Hold pre-job safety meeting and review lift plan. Remove empty ESP spool from rig floor and install new spool with Worley crane. Baker Centrilift spliced ESP cable together, witnessed by ENI electrician. Fill hole at 10 BPH with 8.6 PPG brine. 13:30 16:30 3.00 16.50 W.O. K 20 P Redo ESP splice due to splice positioned across tubing collar, unable to install cross collar clamp. ESP splice witnessed by ENI electrician. ESP splice depth at 7,588’. Fill hole at 10 BPH with 8.6 PPG brine. 16:30 00:00 7.50 24.00 W.O. K 4 P Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 upper completion ESP string from 7,486’ to 10,302’, 77K UW, 65K DW. Torque turn each connection to 2000 FT/LBS torque. Superior thread representative inspected threads and witnessed make up. Drift each joint to 2.347”. Perform electrical checks every 1000’, maintain ~1000 PSI on dual capillary tubing while run in hole. Pump tubing capacity every 3,000’. Fill hole at 10 BPH with 8.6 PPG brine. Note: 24 Hour Loss of 8.6 ppg Brine = 288 bbls. Total Loss of 8.6 ppg Brine = 11,034 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 907-685-8603 Drilling Engineer Amjad Chaudhry Eni Sr. Drilling Engineer amjad.chaudhry@eni.com 907-865-3379 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/8/2024 Report #: 42 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) 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 Temperature (°F) -25.2 Wind SW @ 9 MPH Days LTI (days) 2,373.00 Days RI (days) POB 58.0 Daily Summary Operations 24h Forecast Nipple down BOPE and install X-mas tree. Perform Passport test. Rig down and prepare to move rig. 24h Summary Run in the hole with 2-7/8” ESP upper completion from 10,302’ to 12,628’. Perform electrical checks every 1,000’. Pump tubing capacity every 3,000’. Pick up landing joint and orient tubing hanger to well bay wing valve. Make final splice with ESP cable with Baker Centrilift to penetrator pigtail assembly, witnessed by ENI electrician. Perform dual Capillary string integrity and function test. Install PFT Pig Tail and test conductivity. Land tubing hanger in wellhead with bottom of 7-5/8” shroud at 12,654.05’. Flow check well for 30 minutes. Pull landing joint and install TWC. Nipple down bell nipple and BOPE. Operation at 07.00 Nipple up tree. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 07:30 7.50 7.50 W.O. K 4 P Run in hole picking up 2-7/8” W563, 6.4 PPF, L-80 upper completion ESP string from 10,302’ to 12,588’, 87K UW, 59K DW. Torque turn each connection to 2000 FT/LBS torque. Superior thread representative inspected threads and witnessed make up. Drift each joint to 2.347”. Perform electrical checks every 1000’, maintain ~1000 PSI on dual capillary tubing while run in hole. Pump tubing capacity every 3,000’. Fill hole at 10 BPH with 8.6 PPG brine. 07:30 13:30 6.00 13.50 W.O. K 4 P Run in hole picking up 2-7/8” x 4-1/2” W563 crossover with pup joints, three 4-1/2” W563, 12.6 PPF, L-80 pup joints, 4-1/2” swivel joint, one 4-1/2” W563, 12.6 PPF, L-80 pup joint, and MB-247 13-1/2” X 4-1/2” one piece tubing hanger from 12,588’ to 12,628’. Pick up landing joint and orient tubing hanger to well bay wing valve. 13:30 18:00 4.50 18.00 W.O. K 20 P Make final splice with ESP cable with Baker Centrilift to penetrator pigtail assembly, witnessed by ENI electrician. Perform dual Capillary string integrity and function test. Install PFT Pig Tail and test conductivity. (Good Test) 18:00 20:30 2.50 20.50 W.O. K 5 P Land tubing hanger in wellhead with bottom of 7-5/8” shroud at 12,654.05’. 45K Hanging Block Weight, 87K Up Weight, 59K Down Weight. Install hold down pins. Test upper and lower tubing hanger body seal to 5000 PSI for 10 minutes, good test. Flow check well for 30 minutes. Pull landing joint and install TWC with Vault representative. Total 416 - 2-7/8" cross collar clamps, 1 - 2-7/8" MLE splice clamp, 1 - 2-7/8" cable to cable splice clamp, 1 - 4-1/2" cross collar clamp, 1 - 4-1/2" half clamp. 20:30 00:00 3.50 24.00 W.O. K 5 P Nipple down bell nipple and BOPE. Note: 24 Hour Loss of 8.6 ppg Brine = 466 bbls. Total Loss of 8.6 ppg Brine = 11,755 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 Well Name: OP09-S1 OR Wellbore Name: OP09-S1 Well Code: 25601 Job: WORKOVER WCEI Level: N/A Daily Report Date: 3/9/2024 Report #: 43 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) 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 Temperature (°F) -30.5 Wind SW @ 8 MPH Days LTI (days) 2,374.00 Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Prepare to move rig to OP03-P05 when ambient temperature is above -35°F cold weather restriction. Loader operations to scrap / level location and lay rig mats on containment for rig move. 24h Summary Nipple down BOPE. Terminate capillary lines. Nipple up X-mas tree. Test tubing hanger bonnet seals to 5000 PSI for 10 minutes. Perform passport test and final ESP cable electrical integrity test. Prepare to move rig to OP03-P05. Hand well over to Production group. Rig released at 2400 HRS on 3/9/2024. No further reports. Operation at 07.00 Cold weather stand down. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. C 5 P Nipple down BOPE. 04:00 10:00 6.00 10.00 W.O. K 12 P Terminate capillary lines. Nipple up X-mas tree. Test tubing hanger bonnet seals to 5000 PSI for 10 minutes, good test. 10:00 17:00 7.00 17.00 W.O. K 12 P Perform passport test with Vault representative as procedure, good test. Remove TWC from tubing hanger profile. 17:00 20:00 3.00 20.00 W.O. K 12 P Perform final ESP cable electrical integrity test with Baker Centrilift, good test. 20:00 00:00 4.00 24.00 W.O. K 12 P Prepare to move rig to OP03-P05. Unable to perform loader operations due to ambient temperature below -35°F cold weather restriction. Hand well over to Production group. Rig released at 2400 HRS on 3/9/2024. No further reports. Daily Contacts Position Contact Name Company Title Email Office Mobile Company Representative Tim Ashley ASRC Energy Services Company Man OPPdiilling@eni.com 907-685-0710 Company Representative Paul Dillon ASRC Energy Services Company Man paul.dillon@external.eni.com 907-685-0710 Company Representative Adam Groendyke ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Lonnie Kalar ASRC Energy Services HSE lonnie.karlar@external.eni.com 812-968-4595 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push John Kelly Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative George Orloff Nordic HSE 907-685-8603 Safety Representative Derek Sutherland Nordic HSE 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 L80 12,988.4 21,740.0 3,868.0 7/14/2011 This document was created with the Win2PDF “print to PDF” printer available at http://www.win2pdf.com This version of Win2PDF 10 is for evaluation and non-commercial use only. This page will not be added after purchasing Win2PDF. http://www.win2pdf.com/purchase/ http://www.win2pdf.com http://www.win2pdf.com/purchase/ 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 Changeout_ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Nikaitchuq Schrader Bluff 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 22370 N/A Casing Collapse Structural Conductor Surface 2480 Intermediate 4790 Production slotted Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Giorgio Iannucci Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Amjad Chaudhry 12/1/2023 January th, 2024 4.5 N/A 13162 2290 21740 Perforation Depth MD (ft): 13195 13,195-22,370 8754 3,929-3,868 154 2325 38685.5 20" 13.375 160 9.625 6890 5210 154 2159 3929 Proposed Pools: L80 TVD Burst 10054 slotted MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 211-058 3700 Centerpoint Dr. Ste. 500, Anchorage, AK, 99503 50-029-23448-00-00 Eni US Operating Co. Inc. AOGCC USE ONLY Tubing Grade:Tubing MD (ft): N/A Perforation Depth TVD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writte n approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size amjad.chaudhry@eni.com 907-865-3300 Well Operations Project Manager OP09-S1 Schrader Bluff 3784 211740 3868 711 N/A m n P s 2 6 5 6 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov ucci 323-677 By Grace Christianson at 2:30 pm, Dec 19, 2023 ADL0355024, ADL0373301, ADL0388583, ADL0390616, ADL0391283 SFD SFD 12/20/2023 DSR-12/19/23 X 10-404 X VTL 01/03 2024 BOP test to 2500 psig Annular preventer test to 2500 psig *&:JLC 1/3/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.03 15:23:28 -09'00'01/03/24 RBDMS JSB 010424 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Phone:907-865-3300 December 1th, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP09-S1 Rig Workover Dear Commissioners, Eni US. Operating Co. Inc. hereby applies for a Workover Sundry for well OP09-S1. OP09-S1 well was drilled and completed in 2011. A second lateral (OP09-S1 L1) was last drilled in 2014 and the well was completed with a TTESP. OP09-S1 well is shut down since November 28 th, 2023, because of a suspected ESP failure, plan is to pull out current TTCESP completion and install a new conventional ESP system. The estimated date for beginning this work is January 5 th, 2024. 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 907-865-3300. Sincerely, Giorgio Iannucci Well Operations Project Manager Sincerely, OP09-S1 Workover – Summary Page OP09-S1 Rig Workover PTD#:211-058 Current Status Well, OP09-S1 is currently shut down. Scope of Work The scope of this workover is to pull the current TTCESP tubing completion and run in with a new upsized Conventional ESP system on 2-7/8” tubing. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1,100 psi during the time of workover. OP09-S1 MASP Shut-in BHP (Max) 1,100 psi, 5.4 ppge Depth 3,891 ft (TVD) Gradient 0.1 psi/ft MASP 711 psi Wellhead type/pressure rating: Vault PC, MB-247/5000 psi BOP configuration: Annular/Blind/2-7/8” x 5” VBR/4-1/2” Pipe Ram TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8” was tested 1500 psi for 10 minutes on February 3rd, 2014. Well type: Producer Estimated start date: January 5th 2024. Drilling rig: Nordic 4. Sr. Drilling Engineer: Amjad Chaudhry: Amjad.chaudhry@eni.com Work: 907-865-3300 Well Operations Project Manager: Giorgio Iannucci: Giorgio.Iannucci@eni.com Work: 907-865-3300 Procedure: Pre-Rig E-line Program o RU E-line above tree o EL Run #1 Drift to top of TTC-ESP o EL Run #2 Punch 6 holes in first full joint above TTC-ESP o RD E-Line. 1. MIRU Nordic 4. 2. Bullhead 8.6 ppg brine down tubing down tubing. 3. Bullheads brine down Annulus A. 4. ND tree, NU BOPE and test. 5. POOH with 4-1/2” tubing to through-tubing ESP to just below rig floor. 6. RU slickline and attempt to pull retrievable section of through-tubing ESP from 4-1/2” tubing. 7. RD slickline. 8. POOH with remaining 4-1/2” tubing and permanent section of through tubing ESP. 9. RIH with 9-5/8” Casing Scraper and clean / scrape the packer setting zone. 10. RIH with 5-1/2” L1 lateral cleanout assembly to L1 heal. 11. RIH with 9-5/8” Retrieve-O-Matic Test Packer assembly and pressure test the casing. o Contingency: Baker seal assembly w/ triple connection and memory gauge. 12. E-Line Program (Contingent). o RU E-line above BOPE o Run #1: Perform MicroDLS log above 9-5/8” LHP o RD E-Line 13. RIH with 2-7/8” middle completion velocity string. 14. Set middle completion packer and pressure test annulus ‘A’. 15. RIH with 2-7/8” upper completion ESP string. 16. Land hanger. 17. Install BPV, ND BOPE, NU Tree. 18. Passport test. 19. Contingency: bullhead LVT freeze protection. 20. RDMO. 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(QL862SHUDWLQJ&R,QF 1$ 236 1LNDLWFKXT 6FKUDGHU%OXII2LO3RRO 6L]H / 79'%XUVW VORWWHG 0' 1$ 3HUIRUDWLRQ'HSWK0'IW 1$ 6WHIDQR3LHUIHOLFL :HOO2SHUDWLRQV3URMHFW0DQDJHU $PMDG&KDXGKU\ DPMDGFKDXGKU\#HQLFRP 0DU 3 W XWBBBB )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Meredith Guhl at 4:08 pm, Mar 04, 2022 'LJLWDOO\VLJQHGE\6WHIDQR3LHUIHOLFL '1&1 6WHIDQR3LHUIHOLFL& $' 'DWH 6WHIDQR 3LHUIHOLF L '65%-0 6)' %23 WHVW WR SVL 6)' ; GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.10 14:58:13 -09'00' RBDMS SJC 031122 &HQWHUSRLQW'ULYH6XLWH $QFKRUDJH$ODVND 6WHIDQR3LHUIHOLFL 3KRQH (PDLOVWHIDQRSLHUIHOLFL#HQLFRP 0DUFK $ODVND2LODQG*DV&RQVHUYDWLRQ&RPPLVVLRQ :HVWWK $YHQXH6XLWH $QFKRUDJH$ODVND 5( $SSOLFDWLRQIRU6XQGU\$SSURYDOIRU236 5LJ:RUNRYHU 'HDU&RPPLVVLRQHUV (QL 86 2SHUDWLQJ&R ,QF KHUHE\DSSOLHVIRU D:RUNRYHU6XQGU\IRUZHOO 236 236ZHOOZDVGULOOHG DQGFRPSOHWHGLQ$VHFRQGODWHUDO236/ ZDVODVWGULOOHG LQDQGWKHZHOOZDVFRPSOHWHGZLWKD77(63 &XUUHQWO\WKHZHOOLVSURGXFLQJ SODQLVWRSXOORXWFXUUHQW77&(63FRPSOHWLRQDQGLQVWDOODQHZ FRQYHQWLRQDO(63V\VWHP 7KHHVWLPDWHGGDWHIRUEHJLQQLQJWKLVZRUN LV 0DUFK WK 3OHDVH ILQG DWWDFKHG IRU WKH UHYLHZ RI WKH &RPPLVVLRQ IRUPV DQG VXSSRUWLQJ GRFXPHQWDWLRQ ,I\RXKDYHDQ\TXHVWLRQVRUUHTXLUHIXUWKHULQIRUPDWLRQSOHDVHFRQWDFW $PMDG &KDXGKU\ DW 6LQFHUHO\ 6WHIDQR3LHUIHOLFL :HOO2SHUDWLRQV3URMHFW0DQDJHU 'LJLWDOO\VLJQHGE\6WHIDQR 3LHUIHOLFL '1&1 6WHIDQR3LHUIHOLFL& $' 'DWH 6WHIDQR 3LHUIHOLF L 236:RUNRYHU±6XPPDU\3DJH 2365LJ:RUNRYHU 37' &XUUHQW6WDWXV :HOO236LVFXUUHQWO\SURGXFLQJ 6FRSHRI:RUN 6FRSHRIWKLVZRUNRYHULVWRSXOOWKHFXUUHQW77&(63WXELQJFRPSOHWLRQDQGUXQLQZLWKDQHZ XSVL]HG&RQYHQWLRQDO(63V\VWHP *HQHUDO:HOOLQIR 5HVHUYRLU3UHVVXUH79'7KLVZHOOLVH[SHFWHGWRKDYHDVWDWLFPD[ERWWRPKROH SUHVVXUHRIDSSUR[LPDWHO\SVLGXULQJWKHWLPHRI ZRUNRYHU 230$636DIHW\)DFWRU 6KXWLQ%+3 0D[SVLSSJH 'HSWKIW79' *UDGLHQWSVLIW 0$63SVL :HOOKHDGW\SHSUHVVXUHUDWLQJ 9HWFR*UD\0%SVL %23FRQILJXUDWLRQ $QQXODU%OLQG´[´9%5´3LSH5DP 7,)/0,7,$0,72$ ,QWHUPHGLDWHFVJ´ZDVWHVWHGSULRUWRGULOORXWLQ-XO\ :HOOW\SH3URGXFHU (VWLPDWHGVWDUWGDWH 0DUFK WK 'ULOOLQJULJ 1RUGLF 6U'ULOOLQJ(QJLQHHU $PMDG&KDXGKU\DPMDGFKDXGKU\#HQLFRP :RUN :HOO2SHUDWLRQV3URMHFW0DQDJHU 6WHIDQR3LHUIHOLFL6WHIDQRSLHUIHOLFL#HQLFRP :RUN ,QWHUPHGLDWHFVJ´ZDVWHVWHGSULRUWRGULOORXWLQ-XO\ 3URFHGXUH 0,581RUGLF 6KHDUORZHU*/0YDOYHDQGFLUFXODWHSSJ.&OEULQHNLOOIOXLGWKURXJKWUHH 6HW%391'WUHHDQG18%23DQGWHVWDVSHU$2*&&¶VDSSURYHG6XQGU\ 3XOOWXELQJWRORZHU*/05LJXSZLUHOLQHDQGSXOOWXELQJVWRSFKHFNYDOYH &LUFXODWHRXWUHPDLQLQJSURGXFWLRQIOXLG &RQWLQXH322+DQGOD\GRZQ77&(63DVVHPEO\ 08QHZ&RQYHQWLRQDO(63DVVHPEO\DQG5,+WRVHWWLQJGHSWK /DQGKDQJHUDQGWHVWLW ,QVWDOO%39DQGQLSSOHGRZQ%23 18WXELQJDGDSWHUDQGWUHH 3XOO%39LQVWDOOWHVWSOXJDQGWHVWWUHHSVLWHVW &LUFXODWH)UHH]HSURWHFWWKURXJKWUHHGRZQ,$ 6KXWLQZHOO 5'02 %HORZWKHFXUUHQWVFKHPDWLFRIWKHZHOO 3ODQQHGFRPSOHWLRQZLOOEHVDPHZLWKRXW*/0VDQGQHZ(63ZLOOEH&RQYHQWLRQDO(63GHSWK FDQEHIURPFXUUHQWVHWWLQJGHSWK 8SGDWHG 5HYLVLRQ 8SGDWHG%\ %:5LJ)ORZSDWK'LDJUDP3,3(5$06%/,1'6+($55$069%55$06%8))(57$1.0000000000000008'*$66(3(5$7256+$.(56+$.(5$118/$5000000003/8*9$/9(&877,1*6%2;000063$5(&,5&/,1(00),//83/,1(FV -1 2" STAND PIPE 2" BLEEDER TO PITS TOP DRIVE GAUGE TREE CAPPED AT END 3" 5,000 PSI WP KILL LINE CM1 CM2 CM3 CM4 CM5 CM6 CM7 CM8 CM9 CM10 CM11 CM12 CM13 CM14 CM15 MANUAL CHOKE CM16 REMOTE ACTUATED MP 2 MM 15 MANUAL CHOKE MM GA 1 MM GA 2 MM SN 1 MM SN 2 SN 1 SN 2 CM GA 1 FLOW BACK TANK 8.&$&78$7('/.&0$18$/TO MGS TO SHAKER MP 1 OPEN PORT CAPPED 3-1/8" 5,000 PSI WP CHOKE MANIFOLD Drilling Riser: 13-5M Flange x Hub .,//+&5,16,'(.,//&+2.(+&50$18$/&+2.(3" 5,000 PSI WP CHOKE LINE DV -1 SP -1 CV -1 FB -1 12" Flow line 8" vent line 20' long 3593LW3593LWSpacer Spool: 13-5M Flange x Flange Rig Nordic #4 Stack measurements Note: To be confirmed when rigged up Top Flange Upper Lock Down Screws Rotary Table 8’ 5” 13’ 2” 14’ 3” 34’ to GL (Nordic Rig 4 RKB 33.5’ + 6” mats) 24’ 9” 25’ 3” 29.5” 85” RISER 16’ 4” Projected KILL LINE CHOKE LINE TOP OF WELL HOUSE 13’ 10” to GL Draft 09-28-18 4-1/2” pipe rams 2-7/8” x 5” VBR rams From: Schwartz, Guy L (DOA) Sent: Tuesday, March 5, 2019 4:24 PM To: 'Richard Gentges' Cc: John Lau; Matthew Federle Subject: RE: Wellhead Schematic for CLUS-5 Velocity String �_ O Richard, The AOGCC doesn't have any concerns with this wellhead arrangement. It will meet all our SVS requirements as shown. This is assuming the ScSSV in the tubing string is installed also. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDEN17AL17Y 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 Guy Schwartz at (907-793-1226 1 or (Guvschwortze alaska.aov). From: Richard Gentges <Richard.Gentges@cingsa.com> Sent: Tuesday, March 5, 2019 2:22 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Richard Gentges <Richard.Gentges@cingsa.com>; John Lau <John <Matthew. Federle@ensta rnatu ra Igas.com> Subject: Wellhead Schematic for CLUS-5 Velocity String Guy, Lau@enstarnaturalgas.com>; Matthew Federle Per our phone conversation today, CINGSA is planning to run a 3 1/2 inch velocity string in the CLUS-5 storage well later this year to address an ongoing water loading issue during storage withdrawals. The 3 1/2 inch will be set on a packer above the completion interval. We'll be modifying the existing wellhead to accommodate the smaller diameter string inside of the existing 7 inch tubing string. We plan to run a 3 1/2 inch wireline retrievable subsurface safety valve and the existing surface safety valve will remain in the wellhead above the new tubing string. At the appropriate time we will of course include more specifics in a Sundry Notice. In the interim, attached, is a schematic of the revised wellhead plan. We would appreciate it if you would look this over and advise as to whether this configuration would be acceptable from the AOGCC's perspective. Please give me a call or email me with any questions. Cell phone is 989-464-3849. Thanks much. ,PEI W. FII-,A I ..MIN- In.S."Imro ,Y 1-5ro n551ro, .F�PaPEu ae 6.615 Opi3P Yai11 E16T / IEP ,." ; ,� �j IL NAMw.u, ryE, x.xa en vier. LE ,3, "`=37 FI Roo ' S I L M E#-oEi ,A. M. 3}65 9 YC- A SBTu11 IED PSK II Ina-y Sl� l 0 WnEl1 0.1 ro W \ ro QP.W Bra ,I/2 ANI I IIIMAMANA 1. IIN MAN mi IAWIM GROUND LEVEL - - GROUND LEVEL a.. 11"Br.F 19� 11505001 Vi505% PIMWPmm v 1121 B.OL MAI lY LVE "R0.0-31 MINA IAIXT SL x A.IMA MIN AD ALASKA 9, 13 3/8 X 9 5/6 % r x 3/z- EpmOSCTOM. OF CELLAR 0v. _... 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N N V n W N fV f0 N M N N N N 'O N N N N N m N QO o Y rn 2 co OC co n co 0) 0 0 co CD n m N O n NV' O CO CI) N '- a CO N N N O N o v O 10 l0 !O 0 IN m N N n t7 N N M N S7 N N N N N N N N N N N M C 5 oI- a m N C E'CI O vi r r r cu N N CU r r r f7 r N r V ^' `� r N m r r N 9 L O 0 o co, U E y 0 a2 N 5 U) U) U) U) U) U) U) U) UUN co O UYU) 0 UUUt0 U) N N 0 N UN 0 u ' g• *2 g `m LL z C 'a d N md 'V CO CO CO CO U) CO CD CD 0 CO CO CDCOD COtD CO U) co O cotD (D co co co co co co co E S C C::;\) `oo o66 6 nd r, d d m o hd b d m z 0)g � � o � ; i ; ig ; A0AtAt8t0000ooo Ci .2 8 o 0 0 0 0 qq g 0 0o 0 0 g 0 o 0 g 0 g 40 0 0 aOb 0 0 0 o $ 00 s, t c. .0.z o a8c dc o0 0 490 0 Q - o 0 0 0 moNOgON0m..COZQ b r N ON r _ 0V <nMNn NONA" V N aN N 0 INU) NNNNmNjNNNNNNNNNNNNNNNNNNNNN O$ NN aN N N N N N N N N N N N ON N N N N N N N N N N N N N N N N 1 e000O O d d d d OOOU) tqfj UCO m m 0 O IDd d d o co d 2 d d d c d d d 2 O 2 m CO oto N co 00 o U0o iuddddEy N 1,..,' c v L m Fs n E N O r m co N Z n co n U) co N o ° Z a a a a a s co a a o h w w Z n z w Z u) 3 z co w °� v .0 0 1... z 4j i LL .z LL 4, LL z z LL z co z z ,>e, E E N �. a? E o g 0 0 o o N d td n to m d co d r to to N :3 .} n d 0 6 g t c z w 3 a a a Cl- a a a a a a O. a s a a a a a a N a N a a N a a a a = 0- 0 0 0 0 0 0 0 0 0 0 0 0 to w co co w to U W (D 0 0 W co 4) 0 0 0 to Q _ • w atk -o58 RECEIVED OCT 2 6 2015 CANI4IG AOGCC Uau.i.wc Tecnvni.,x:r Ln>. 301 EAST 92"°AVENUE,SUITE 2•ANCHORAGE,ALASKA 99515•(907)561-2465•FAX(907)561-2474 l 1-1 BIA Co October 26, 2015 A1015001 10.u� -0L� ✓`G�J Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 Re: Final Digital Data and Well Reports: Eni Petroleum, OP09-S1, North Slope Borough, Alaska Dear Meredith; Enclosed with this letter is the Final Well Data on CD from the Eni OP09-S1 well. The following data and is included as per your instructions. OP09-S1: Description Copies LAS and Final Log TIFF Files on CD ROM 1 If I can be of any future assistance, please do not hesitate to call me at your convenience at (907) 561-2465. Most sincerely, ilovix 62 C.,. James R. Carson SCANNED AUG 1 1 2016 Alaska Division Manager Canrig Drilling Technology Ltd. ReceiveOF u kptk -CTS0- 11 � -e .2.1 ELS- Signature Title Date Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aj L - O�7 g Well History File Identifier Organizing(done) ❑ Two-sided III IIIIII IIII ❑ Rescan Needed III IIIIIIIIII 111111 RESC N DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No. ❑ Ma s: V reyscale Items: ❑ Other, No/Type: Other Items Scannable by a Large Scanner rokm ATM �j G S ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: (Maria Date: 1/171/ /s/ • Project Proofing 111011111M Dill BY: _ Date: / /s/ IMP Scanning Preparation 7 x 30 =ala + 1 = TOTAL PAGES F q (Count does not include cover sheet) IA a BY: Maria Date: /s/ Production Scanning I 11111 Stage 1 Page Count from Scanned File: q aO(Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES NO BY: Maria ) Date: it//7/19- /s/ P Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III 111111 11111 I I III ReScanned HIM 11111 I BY: Maria Date: Js/ Comments about this file: Quality Checked III 1111111111111 12/22/2011 Well History File Cover Page.doc O u) 9 f0 a)w- O CD N J O a3 a) co N O) J Q V d N Z �� v 2 v Z O J m co J m rn U °' '4 ,,_ 8 a) in aa)) in c c p o > O O lit 3a`� aCi (/)"0--° c a� o a� c a� c ° OU p co N E m o o • o 0 0 .--c) o aai € o p o m o 2 c j ,LL >fn cn >cn cn tL J O O Z ' c V Ooa 2a i-a 2a i-a w 2 1- 2 1- 2 2 w FE � c Q �a O V C E > ,- ,-O O .- `- a d o 0 0 0 0 0 0 0 0 0 0 0 0 J ` y O N N N N N N N N N N N N N C) a) V Zi v- V a V a • V - V V pi Q J ce N N N N N N N N N N N N N E a) Co CO co CO co CO co CO CO CO Co CO C O 7 2 — C c c c c c c c c c c c c a) N a) a) a) a) M a) N Cl) a) N a) Cl) E ? �a c = = a a a a a 0. a a a 0. a a a ~// 0 Y O V 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Li V .2 V 0 0 0 0 0 0 0 0 0 0 0 0 0 O C7 f0 a r` n r` r-- r` r- n r` Z j N �O, M M M M M M M M CO CO CO M M d a) 0 N N N N N N N N N N N N N a- .0 3 0- (a N N N N N N N N N N N N N E E W w a) a) N Z 0 Lo to W U) ! 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J O _._i Z m f0 ni U LL U E U 66 CL W a 1 CC 0 W > > U Z u W ) a Z 9 Q I- ii 7 N O J o _ ay CD 0 • N � a • M ■ J Q r T- o N 5 G o N CO v m n I p = a) CO ~ o Q I— za Q C a 0 Z A E U m OOP d co N- co Z o O op 0 aQ m o 3 N 0 m Z c,' a>i re 0 O ^ Q �. .0 Z y U v O N '0 C C N O 0 C y CO E a iil n 2....,a E E a 0 j d 2 Q 0 < 0 U CANRIG U¢u i.rne:Tisri rvni.x:r Lro. 301 EAST 92"°AVENUE,SUITE 2•ANCHORAGE,ALASKA 99515•(907)561-2465•FAx(907)561-2474 August 23, 2011 E0811004 Ms. Christine Mahnken AOGCC 333 West 7th Avenue Anchorage AK 99501 Re: Final DML Color Log Prints, Well Reports and Digital Data: Eni Petroleum, OP09-S1, Nikaitchuq, North Slope Borough, Alaska Dear Christine: Enclosed with this letter are the Final DML Color Formation logs for the recently drilled OP09-S1 well. The following data and corresponding number of copies is included as per Eni Petroleum instructions. OP09-S1 Description Standard Digital Formation Log 2"=100' MD (Color Prints) 1 Standard Digital Formation Log 2"=100' TVD (Color Prints) 1 LWD Lithology Log 2"=100' MD (Color Prints) 1 LWD Lithology Log 2"=100' TVD (Color Prints) 1 Gas Ratio Log 2" = 100' MD (Color Prints) 1 Drilling Dynamics Log 2" = 100' MD (Color Prints) 1 Final Well Reports 1 Final Digital Data on CD ROM (with TIFF File) 1 Most sincerely, j004,4- GZ. James R. Carson Alaska Division Manager Canrig Drilling Technology, Ltd. Received by: k 4[1:24(1( Signature Title Date l yg (16 RECEIVE AUG 2 4 2011 Aiiiiti ON&Gas Cam.Gammissiog Anct»rape 1 - 05-6 $chlumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Christine Shartzer Well No OP09-S1 Date Dispatched: Installation/Rig Nabors 245E Dispatched By: Brian Muzny Data No Of Prints No of CDs OP09-S1 -Logs: 1://-l Ci 7y7 2inMD 1 v 2 in TVD 1 - 5inMD 1 5 in TVD 1 Received By: V Please sign and return one copy to: D&M,2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 a C?, muzny1(a�slb.com Brian Muzny Fax:907-561-8317 LWD Log Delivery V2.1,03-06-06 /� _ 3-8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil 0 Gas❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC25.110 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.: 7/19/2011 211-058 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive Suite 300,Anchorage 99503 6/13/2011 50-029-23448-00-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 3194 FSL 1583 FEL S5 T13N R9E UM 1 7/10/2011 OP09-S1 Top of Productive Horizon: 8.KB(ft above MSL): 53.4 • 15.Field/Pool(s): 3476 FSL,2533 FEL,S29 T14N R9E UM Ground(ft MSL): 12.2• Nikaitchuq, Total Depth: 9.Plug Back Depth(MD+TVD): 3,•4,,,, ., ,,�j/.-t-f C'/ 3068 FSL 4967 FEL 19 T14N R9EUM 21740'MD/3868'TVD jtj -..11 ,I 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: - Surface: x- 516696.90 y-6036546.91 Zone- 4 " 22370'MD/3784'TVD_ 355024,373301,390616,388583,391283 TPI: x- 515690.15 y-6047385.35 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 507950.97 y-6052244.32 Zone- 4 none ADL 417493 18.Directional Survey: Yes 0 No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 MC 25.050) (ft MSL) 1772'TVD . 21.Logs Obtained(List all,ogs here and submit electronic and printed information per 20 MC 25.071): GR/RES/NEU/Den 22. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 20" 178.89 X-65 SURFACE 160 SURFACE \ 160 30 Cement to Surface 13-3/8" 68 L-80 SURFACE 2325 SURFACE 2159 16 430 bbls 10.7#ASL 75 bbls 12.5#DeepCRETE ✓ 9-5/8" 40 L-80 SURFACE 13195 SURFACE 3929 12.25 356 bbls 12.5#DeepCRETE r 5.5" 17 L-80 12988 21740 3909 3868 8.75 slotted liner 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 with ESP completion 4.5 10055 NA y v wfr�=ri'j .25. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 1 T 1 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED r ,a� , 26. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: NA NA Test Period .■1•• Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(core): Press. 24-Hour Rate 27. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RECEIVED AUG 16 2.011 RBDMS AUG 1 7 1011-51 Gemmission gate�I Gas CAS E ,� Form 10-407 Revised 2/2007 CONTINUED ON REVERSE Anter>�ge l t..^ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? U Yes H No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top surf surf and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1852 1772 OA sand top 13195 3929 Formation at total depth: OA sand 22370 3784 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: Joseph Longo @ 907-865-3323 Printed Name: Maurizio Grandi Title: Well Operations Project Manager Signature: Cli-012-1--1---"( Phone: 907-865-3320 Date: 8/15/2011 INSTRUCTIONS AITIA to 2500 PSI. This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole Item la: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with prod Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional in Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 oz '� v 0 0 0 0 0 0 N CO N -' (n 'D c 0 N N y NU) * .A cn c� o W R, - Q• CD CD CD CCD CCDD CCDD m o 0 OD n Q -0 -v -0 -0 v = a) 5 Q - O) U) C11 40. W N j CO .,"' 411111T- p1 Iv E CD ▪ in N -, Q1 O O O CD W 00 " 00 V=, 3 Cr Cr 0n UI ,..h r7XIIIP ' /4\ r \1■, • >`\ N N _u -0 - W \\ O ' N CA _ to O N A O uo U9 301 a) X O 0 °) p, 'SI Ui CD W 7 O N X-- Q o Q -Co ' O —, O S Q <(/) N 3 0 n N O N N -0 -1 U1 N. Q C �# —• sv I" co _, N � _1 � � � CnQ o 03 W N Q (n --i - 3 < W D ) 7 Q I E 0 ' < n- < � u) W n- to _. C CD N o ZS N I 'co m --{{ 5• J 2. m Q ' -1 0o cu ° r cn 0 cn -i Q v : r - n - CD ,� CD K CQ II I _ ° co co - 0 n) ' co o_ : o) -L Q I f 1° D (I) C/3 t-- o v�• o r X-0 r= N o N� x=O vU, o O m W oOO - o co 0 C , X — M) 1..„, . . N II 0 n rn -' O m j O cn 9 - U ao m N (r O -0 r r Z m (0• CO _ g • - op°'pov, Q.. G) CD Q r c -, CD C Q Q (D o m CD o J n N 71 Viiiii Eni E&P Division .,i (Well Name:OP09-S. I ENI Petroleum Co.Inc. Daily Report well Code:25601 Field Name:NIKATCHUO �j •n e li N Date:6/11/2011 - Report#: 1 APIIUWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 1 orlool HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date Target Depth(RKB) Target Depth(TVD...Depth Dr.(MD)(ft) I Drilling Hours(hr) 'Avg ROP(fUhr) DFS(days) OP09-S1 DRILLING 6/13/2011 22,371.0 3,826.0 22,310.00 190.91 116.9 -1.00 Daily Information End Depth(ftKB) End Depth(ND)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 79.0 25.7 Partly Cloudy,WC 350°N @ 6.1 mph 18.5° Daily summary operation 24h Summary RID rig from OP14-S3 well and move to OP09-S1 well.Pick up 5"DP and rack back in derrick. Operation at 07.00 P/U 5"DP and rack back in derrick. 24h Forecast PU 5"DP singles 1X1 and rack back in derrick.Prepare to spud OP09-S1 well. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 - 3.00 3.00 MOB 'A 2 P Blow down steam system on drill module/R/D pit room interconnect. 03:00 04:00 1.00 4.00 MOB A '2 P Jack up both rig modules/Install crib block/Set rig down. 04:00 05:00 1.00 5.00 MOB -A "2 P Split drilling&utility modules apart. 05:00 10:30 5.50 10.50 MOB 'A 2 P Remove rig mats/Clean up and dispose of used Herculite/Set new rig mats/Install existing wellbat hatch/production load wellbay w/parts/Electrician change power limit control in SCR room/Fill in low areas on pad wlgravel. 10:30 12:00 1.50 12.00 MOB 'A "2 P Move drill module over well center/Set rig down on rig mats. 12:00 14:00 ' 2.00 14.00 MOB A 2 P Move utility module to drill module and marry up/Drilling module too high/Jack up sub and shim to level up w/utility module. 14:00 18:00 4.00 18.00 MOB A 2 P Connect electrical power between modules I Berm rig/Install steps,stairs&handrails/Hook up interconnect,service lines &flowlines. 18:00 22:00 4.00 22.00 MOB A 2 P Install riser&flowline/Test lower seals on starting head to 5,000 psi for 10 min as per Vetco Gray rep I Ground level: 41.20'-Landing ring load shoulder:37.13'/Install tumbuckles&Katch Kan/Split hatch cover. 22:00 23:00 ' 1.00 23.00 DRILL E 1 P Load pipe shed w/5"drill pipe. 17 23:00 00:00 1.00 24.00 DRILL E 4 P Install mouse hole in rotary table/PU 5"drill pipe singles 1X1/Rack back in derrick. Daily Contacts Position _ Contact Name ' Company Title E-mail Office Mobile Drilling Supt. Frank Cormier "Eni Petroleum Sr.Drg.Spvr. 907-685-1227 337-277-1809 Drilling Supt. Gary Goeriich Eni Petroleum 0119 Spur. 907-685-1277 907-441-6585 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Drig Spvr. 907-685-1277 907-903-7269 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) Viol Eni E&P Division 1 Well Name:OP09-S'r 1 ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO e N•Q Date:6/12/2011 - Report#: 2 APIIUWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) 'Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.401 12.20 0.00 16.27 21.87 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase 'Spud Date !Target Depth(ftKB) Target Depth(TVD...IDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP09-S1 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 0.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..I Depth Progress(ft) !Drilling Hours(hr) Avg ROP(ft/hr) I POB Temperature(°F) Weather Wind 0.0 84.0 29.8 Cloudy,WC 21.2° 57°ENE @ 9.4 mph Daily summary operation 24h Summary • Finish P/U 5"drill pipe and 5"HWDP-rack back in derrick to drill intermediate hole section\Build spud mud\Prep to P/U BHA#1. Operation at 07.00 P/U Clean-Out BHA#1. 24h Forecast P/U Clean-Out BHA#1\Hold pm-spud meeting\Clean out surface conductor 1 P/U BHA#2\Drill 16"hole section Slide/Rotary to proposed 13 3/8"casing point @ 2,321'as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 '03:00 3.00 3.00 DRILL E 4 P P/U 5"drill pipe using the mousehole&rack back in derrick\SLM every row. 03:00 -04:00 1.00 4.00'DRILL E 25 'U Fix hydraulic leak on iron roughneck\Replace fitting. 04:00 12:00 8.00 12.00 DRILL E 4 'P P/U 5"drill pipe and rack back in derrick\SLM\Drift each joint\66 stds m derrick\Mix spud mud\Install M-I Swaco CCB lines. 12:00 22:30 10.50 22.50 DRILL E 4 'P P/U 5"drill pipe and rack back in derrick/SLM/Drift each joint/P/U and rack back a total of 138 stds. 22:30 00:00 1.50 24.00 DRILL E 1 P P/U and std back 14 jts HWDP and 1 it jars. Daily Contacts Position Contact Name _ Company Title I E-mail Office Mobile Drilling Supt. 'Frank Cormier Eni Petroleum Sr.Drig.Spur. 907-685-1227 337-277-1809 Drilling Supt. Gary Goerlich Eni Petroleum Dr-1g Spur. 907-685-1277 907-441-6585 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci lEni Petroleum Drig Spvr. 907-685-1277 907-903-7269 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 Applied(psi) Eq.Mud Weight(Ib/gal) 'Leak Off Pressure(psi) • ■ >� Eni E&P Division (Well Name:OP09-S ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ • • APIIUWI:50-029-23448-00-00 e n Date:611312011 - Report#: 3 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° 'Operator ENI Share(%) !Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) !Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(TVD..J Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP09-S1 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 1.00 Daily Information End Depth(RKB) End Depth(TVD)(f..Depth Progress(ft) Drilling Hours(hr) Avg ROP(fUhr) POB Temperature(°F) Weather Wind 545.0 545.0 385.00 3.13 123.0 84.0 28.4 Partly Cloudy,WC 20°NE @ 4.4 mph 24.6 Daily summary operation 24h Summary P/U 5"HWDP\Prep to P/U BHA\Hold Pre-spud meeting\P/U BHA#1&clean out conductor\POOH&P/U BHA#2 Schlumberger/Gyro Data tools and drill ahead to 252'\Attempt to get Gym Pulse survey 1 Unable to get survey\POOH and L/D all of BHA#2 except for motor&bit\PU BHA#3/Slide/Rotary drill f/252'to 545'. Operation at 07.00 Drill ahead 16"hole rotary/slide at 768'. 24h Forecast Drill 16'section Slide/Rotary f/545'-1/2321'proposed TO-Circulate bottoms-up 3-Sx(K&M model)-POOH back reaming to HWDP 1 Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 8.95 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL E 5 P P/U and M/U 14 joints of HWDP and Jars w/XO 01:00 03:00 2.00 3.00 DRILL E 20 P Top Drive service-Calibrate Blocks 03:00 05:00 2.00 5.00 DRILL E 5 P PLU_Clean4ut_BHA#1-16"bit MX-1(s/n'51915391+_Platimator @183+NM Stab+XO+5"HWDP-, 05:00 06:00 1.00 6.00 DRILL E 7 P Fill stack with mud and check for leaks-Test surface equipment 2000 psi 06:00 07:00 1.00 7.00 DRILL E 3 P Drill Rotary(Cllean out surface conductor)0160'(Q=400 gpm,SPP=350 psi,40 rpm @ 1.5k torque,WOB=5-8k lbs,Up wt=Dn wt=Rot wt=60k lbs,Mud wt=8.7 ppg)-P/U rack back Std HWDP 07:00 09:30 2.50 9.50 DRILL E 5 P -M/U BHA#2:16"bit MX-1(s/n:5191534)+PDM motor @ 1.83+NM Stab+XO+Gyropulse+PowerPulse+ARC 825+ NM Stab+XO+5"HWDP 09:30 10:00 0.50 10.00 DRILL E 20 P Hold pm-spud meeting with all personnel involved-a.med- -..-■• rr 10:00 12:00 2.00 12.00 DRILL E 3 P Spud well OP09-S1:Drill rotary f/160'-1/252'(Q=500 gpm,SPP=550 psi,40 rpm @ 2k torque,WOB=10-15k lbs,Up wt=Dn wt=Rot wt=70k lbs,Mud wt=8.7 ppg) 12:00 13:00 1.00 13.00 DRILL E 11 TD01 Gyropulse unable to get survey(Tried to Cycled pumps several times and Reset tool) 13:00 15:00 2.00 15.00 DRILL E 4 TD01 POOH and L/D BHA#2 15:00 17:00 ' 2.00 17.00 DRILL E 5 TD01 P/U new Gyro Pulse and Power Pulse,P/U NM DC+x2 NM Flex DC+Float Sub+JAR+XO+5"HWDP and M/U BHA #2 17:00 18:00 1.00 18.00 DRILL E 11 P Take Gyro Pulse surveys @ shoe and 247' 18:00 00:00 6.00 24.00 DRILL E 3 P Drill Sliding/Rotary f/252'-11545'(Q=500 gpm,SPP=720 psi,40 rpm @ 1-2k torque,WOB=5-25k lbs,Up wt=Dn wt=Rot wt= 78k lbs,Mud wt=8.8 ppg) ADT=2.58 hrs AST=1.59 hrs ART=0.99 hrs Jars=124.4 hrs Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Orig.Spur. '907-685-1227 337-277-1809 Drilling Supt. Gary Goertich Eni Petroleum Dog Spvr. 907-685-1277 907-441-6585 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Dog Spvr. 907-685-1277 907-903-7269 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(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) 'Leak Off Pressure(psi) Voil Eni E&P Division IWO Name:0P09-S1 I ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO • Date:6114/2011 - Report#: 4 API/UWI:50-029-2344800-00 2l "11 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° 'Operator ENI Share(%) I Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) !Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 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(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P09-51 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 2.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POE Temperature Co Weather Wind 2,207.0 2,068.4 1,662.00 15.50 107.2 86.0 35.1 Cloudy,Light Rain, 66°ENE @ 11.3 WC 27° mph Daily summary operation 24h Summary Drill/Slide Rotary 16"hole from 54510 2,20T MD. Operation at 07.00 Circulate and backream out of the hole @ 2,200'\Rack back one stand per bottoms up. 24h Forecast Circulate and backream out of the hole\LD BHA#3 1 RU GBR casing equipment\Run 13-3/8"casing. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P __Drill/Slide Rotary(/545'to 860'10=475 gpm,SPP=820 psi on 650 psi OA 40 rpm @ 2.6 tq on,1.2 tq off\WOB=15-25k '16s 1 Up Wt=85k lbs,On Wt=85k lbs,Rot Wt=78k lbs\Mud Wt=8.9 ppg\Wipe 30'before connections\Cycling pumps f/Gyro surveys per SLB. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill/Slide Rotary f/860'to 1,205\0=475 gpm,SPP=1,000 psi on 700 psi off\40 rpm©3-4k on,1-2k tq off\WOB=15- 25k\Up Wt=93k lbs,Dn Wt=86k lbs,Rot Wt=88k lbs\Mud Wt=9.0 ppg\ECD=10.9 ppg\Wipe 30'before connections. i ADT=7.55 hrs. AST=5.88 his ART=1.67 hrs. Jars=131.9 hrs. / 12:00 00:00 12.00 24.00 DRILL E 3 P Drill/Slide Rota 1/1,205 to 2,207'\0=596 m SPP=1,200 psi\40 Rotary gp p rpm @Stq on,3 tq off\WOB=10-30k1Up Wt= 120k,Dn Wt=100k,Rot Wt=110k 1 Mud Wt=92 ppg\ECD=10.05 ppg\Wipe 30'before connections. ADT=7.95 hrs. AST=4.68 hrs. ART=3.27 hrs. Jars=139.9 hrs. Daily Contacts Position Contact Name Company Title E-mail Office ' Mobile Drilling Supt. Frank Cornier Eni Petroleum Sr.Drlg.Spvr. 907-685-1227 337-277-1809 Drilling Supt. Gary Goerlich Eni Petroleum DrIg Spvr. 907-685-1277 907-441-6585 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum DrIg Spvr. 907-685-1277 907-903-7269 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 Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) Eni E&P Division .y t 'Well Name:OP09-S■ Vois ENI Petroleum Co.Inc. Daily Repo) Well Code:25601 Field Name:NIKATCHUO eiii Date:6/1512011 - Report#: 5 API/IW1:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header 211-058 Concession N° 'Operator ETROLEUM I ENI Share(%) 100.00 Well ZON Configuration type Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.40 12.20 060 1627 21.87 Rig Information Contractor 'Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase 'Spud Date (Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) DFS(days) 0P09-51 DRILLING 6/13/2011 J 22,371.0 3,826.0 22,31600 190.91 116.9 3.00 Daily Information End Depth(RKB) End Depth(ND)(f..Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,3406 2,168.9 133.00 1.06 125.5 86.0 44.4 Mostly Clear,WC 149°SSE @ 4.1 42.V mph Daily summary operation 246 Summary Drill/Slide Rotary F/2,207'T/2,340'TD I Backream out of the hole I L/D BHA#3\Ran 13-3/8"casing T/2,285'I Circulate&condition mud 1 R/U Schlumberger cement head&lines Operation at 07.00 Cementing 13-3/8"casing as per well plan. 24h Forecast Circulate and condition mud\R/U Schlumberger cement head&lines\Mix&pump surface cement\RID Schlumberger cement head&lines\N/U BOPE. Lithology I Shows I MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL E 3 P DrilVSlide Rotary F//2,207'T/2,340'MD TD\0=600 GPM,SPP 1,300 PSI on-1,200 PSI off\40 RPM @ 4-5K TO on,3K TO off\WOB=15-25K lbs\Up Wt=120K,Dn Wt=100K,Rot Wt=108K 1 Mud Wt=9.2 PPG\ECD=10.1 PPG\Back ream 30'before connections. ADT=1.06 Hrs. AST=0.59 Hrs. ART=0.47 Hrs. Jars=140.9 Hrs. 02:00 04:30 2.50 4.50 DRILL E 6 P Circulate hole clean while backreaming slowly F/2,340'7/2,111'1 Rack back 1 std per BU as per K&M model.1 800 GPM, 190 SPM,1.654 PSI,80 RPM,4-5 TO. 04:30 10:30 6.00 10.50 DRILL E 6 P BROOH F/2,111'T/674'1 0=800 GPM,SPP=1,200 PSI,80 RPM©4-5K TO I Pull slowly I Hole unloaded F/1,500' T/1,430'I Reduce flow rate F/800 gpm-T/475 GPM until shakers cleaned up I No tight spots wl consistent TO I Wash 0 F/674'T/583'1 Circulated 2X bottoms up. ' 10:30 12:00 1.50 12.00 DRILL E 5 P PJSM\Rack back HWDP/Jars\Rack back stand 8"DC\LID BHA#3 per SLB reps. ■ 12:00 14:00 2.00 14.00 DRILL E 5 P UD BHA#3. 14:00 15:00 1.00 15.00 DRILL G 2 P Pump out stack I Make hanger dummy run per Vetco Gray rep\Remove hanger f/landing joint. 15:00 16:00 1.00 16.00 DRILL G 2 P Bring cement head,plugs,centralizers,and handling tools to rig floor\R/U GBR Volant casing tool. 16:00 21:00 5.00 21.00 DRILL G 4 P Hold PJSM\PIU&RIH 13-3/8"68#L-80 BTC casing wIGBR Volant tool I Make up each jt T/makeup triangle\Baker Lock shoe track I Circulate thru floats&check F/holding\Fill each joint on fly,top off every 10 joints I Installed centralizers as per well plan I RIH T/1,422'\Up Wt 125K,Dn Wt 120K. 21:00 22:00 1.00 22.00 DRILL G 25 XR99 Skate buggy not working\Broken eye sensor I Repaired. 22:00 00:00 2.00 24.00 DRILL G 4 P RIH 13-3/8"68#L-80 BTC casing F/1,422 T/2,325 I M/U Hanger and landing joint-Landed at 2,325.5'MD\Up Wt=170K, Dn 04C°i*OR ---. i Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Comfier Eni Petroleum Sr.Dog.Spvr. 907-685-1227 337-277-1809 Drilling Supt. Gary Goerlich Eni Petroleum Dog Spvr. 907-685-1277 907-441-6585 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Dog Spvr. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(RKB) Bottom(ftKB) Run Date CASING 133/8 12.347 L80 36.6 2,3256 6/16/2011 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Vs Eni E&P Division 1 Well Name:OP09-S' EN!Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ � .j •n e p n N Date:6/16/2011 - Report#: 6 API/UWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) !Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor 1Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date !Target Depth(RKB) Target Depth(TVD...I Depth Dr.(MD)(ft) 'Drilling Hours(hr) !Avg ROP(ft/hr) [DFS(days) 0P09-S1 DRILLING 6/13/2011 22,371.0 3,826.0 22,31000 190.91 116.911 4.00 Daily Information End Depth(RKB) End Depth(TVD)(f..l Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB !Temperature(°F) Weather !Wind 2,340.0 2,168.9 0.00 86.0 41.7 Clear,WC 35.4° 97°E @ 10.5 mph Daily summary operation 24h Summary R/U Schlumberger cement equipment\Cement well as per well plan\N/D riser\N/U BOP stack\Test BOPE. Operation at 07.00 Prepare to P/U and M/U BHA#4. 24h Forecast P/U and M/U 12-1/4"BHA#4 for intermediate hole section\RIH above float collar-Test 13-3/8"casing\Drill out float equipment and 20'-50'of new hole\Circulate and displace hole with new LSND mud\Perform LOT\Drill ahead w/12-1/4"hole. Lithology I Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. / 00:00 00:30 0.50 0.50 DRILL G 4 P 'Remove casing slips&land hanger\Casing Shoe @ 2,325'FC @ 2.235'1 P/U WT=180K Dn Wt=105K l 00:30 01:00 0.50 1.00 DRILL H 1 P Load wiper plugs in cement head\R/U cement head&cement lines. G 01:00 04:30 3.50 4.50 DRILL H 7 P Circulate&condition mud @ 5-7 BPM @ 190-300 PSI w/no losses.\P/U l'off hanger profile. 04:30 07:30 3.00 7.50 DRILL H 9 P PJSM with all personnel\Perform cement job per well plan\Test cement lines to 4,000 PSI\Pump 105 bbls Mud Push @ 9„4.74 10.1 PPG. Drop bottom plug\Pump 430 bbls lead cement @ 10.7 PPG[Class Artic Sea Lite 1033 lb,2.45 Yield,mix H2O ...c at 11.513 gaVsk]\Followed by 75 bbls tail cement @ 12.5 PPG[DeepCRETE 299 sacks,1.62 Yield,mix H2O at 5.744 s.i gal/sk]\Drop top plug and pump 10 bbls water. (/ • 07:30 08:30 1.00 8.50 DRILL H 9 P Displace cement with rig pump w/9.2 PPG mud @ 8 BPM-slow to 3 BPM last 15 bbls of displacement\Bump plug with 900 PSI(500 PSI over final circulating pressure)\Release pressure-floats holding\Cement in place @ 0830 hours on 6- 16-2011\Full returns throughout job\Recovered 146 bbls 10.7 PPG lead cement at surface. 08:30 10:30 2.00 10.50 DRILL C 5 P R/D cement head\Back out&L/D landing joint\Clear rig floor of casing and cementing tools\Flush drill riser with rinse pill. 10:30 12:00 1.50 12.00 DRILL C 5 P Clean&R/D KatchKan I L/D mouse hole\Remove flow line. 12:00 14:00 2.00 14.00 DRILL C 5 P 'N/D riser and starting head. 14:00 16:00 2.00 1660 DRILL C 5 P 'N/U wellhead and valves\Test per Vetco Gray @ 5,000 PSI F/10 min. 16:00 21:30 5.50 21.50 DRILL C 5 P 'N/U 13-5/8"riser and BOP stack\Install choke,kill lines,flowline,bell nipple and Katch Kan. 21:30 22:00 0.50 22.00 DRILL E '12 P M/U 5"test joint\Fill stack-purge wlair. 22:00 00:00 2.00 24.00 DRILL E 12 P Test BOPE\Test T/250-3,500 PSI 5 min each-chart recorded\Witness of BOPE tests waived by Lou Grimaldi AOGCC et P rep. Daily Contacts L I Position Contact Name Company Title E-mail Office Mobile I i i1 Drilling Supt. Frank Cormier Eni Petroleum Sr.Ng.Spvr. 907-685-1227 337-277-1809 V f Drilling Supt. Gary Goerlich Eni Petroleum Drig Spvr. 907-685-1277 907-441-6585 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Dug Spvr. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.347 L80 36.6 2,325.0 6/16/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) *Rs Eni E&P Division I Well Name:OP09-S' I ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ (� Date:6/1712011 - Report#: 7 API/UWI:50-029-23448-00-00 `�- page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) I Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) [Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.401 12.20 0.00 16.27 21.87 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(TVD..J Depth Dr.(MD)(ft) [Drilling Hours(hr) Avg ROP(ft/hr) [DFS(days) 0P09-S1 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 5.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,340.0 2,168.9 0.00 84.0 35.1 Clear.WC 26.1° 71°ENE @ 13.6 mph Daily summary operation 24h Summary Test BOPE to ACGCC requirements/Witness wavered by AOGCC Rep.Lou Grimaldi.\Changed out lower[BOP valve and saver sub,work on gripper/dies assembly.Test all valves 6250 psi./3500 psi.\ Pull test plug and install wear bushing-L/D test joint.\ L/D 5"HWDP from derrick(4 stds.)\P/U BHA#4-visual test Power Drive and perform shallow test MWD @ 1000'.\RIH f/1000'-622001 Cut drilling line.\Repair crack finger in derrick(weld)./CBU./Test 13 3/8"csg to 2500 psi.for 30 minutes(chart recorded)./Tag @ 2232'-Drill out plug/cement and float equipment f/2232-02238'. Operation at 07.00 Performing LOT 24h Forecast Finish drilling shoe track clean out 62340',plus 20'new hole 623601 Displace hole to new LSND mud./Circulate and condition until mud weights in&out equal.Establish baseline ECD with K&M.\ Perform LOT/FIT.\Drill ahead as per Well Plan. Lithology [Shows MAASP Pressure(psi) [Mud Weight(lb/gal) 920 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:30 4.50 4.50 DRILL E 12 P Test BOP to AOGCC requirements on 5"tubular.\Annular @ 250 psi./2500 psi./Pipe&blind rams,mud cross valves, choke manifold,floor and top drive valves(lower IBOP failure):250 psi./3500 psi.-Chart record all test for 5 mins.\ Hydraulic and Manual choke valves tested to 1500 psi./Koomey draw down test(Recovery times:(/1950-62150 psi.(200 psi.)in 37 seconds with final @ 3000 psi in 144 seconds-6 Nitrogen bottles @ 2716 psi average).Tested was waived by AOGCC Rep Lou Grimaldi./Test Gas sensors 04:30 10:00 5.50 10.00 DRILL E 25 P Retest lower IBOP valves on top drive failure.\Change out lower valve assembly-work on gripper block/dies assembly and change out saver sub.\Test upper and lower top drive valves 250 psi./3500 psi.(chart recorded). 10:00 11:00 1.00 11.00 DRILL E 5 P Pull test plug and install wear bushing with Vetco Gray. 11:00 12:00 1.00 12.00 DRILL E 1 P L/D test joint and R/D equipment.Install 5"elevators. 12:00 13:00 1.00 13.00 DRILL E 4 P L/D four stands(12 joints)of 5"HWDP form derrick. 13:00 16:00 3.00 16.00 DRILL E 4 P P/U BHA#4 with Schlumberger-visual function test Power Drive with 580 gpm @ 450 psi./good.Perform shallow test MWD @ 1000'. 16:00 17:00 190 17.00 DRILL E 4 P RIH f/1000'-622001 Up wt.=105K-Dn wt.=95K. 17:00 18:00 1.00 18.00 DRILL E 25 P Service rig:blocks,top drive,draw-works and crown. 18:00 20:00 290 2090 DRILL E .25 P Cut drilling line./Nabors repair cracked(welded)derrick finger @ board.\Set and test crown-o-matic.\Calibrate block position with CanRig and Schlumberger. 20:00 20:30 0.50 20.50 DRILL E 7 P Circulate bottom-up to test 13 3/8"csg./Mud wt.=9.1 ppg. 20:30 21:30 1.00 21.50 DRILL E 12 P Test 13 3/8"csg to 2500 psi for 30 mins.(chart recorded). _ 21:30 00:00 2.50 24.00 DRILL E 3 P - Tag @ 2232'/Drill on cement/plug and float equipment 1/2232'-022381 Pump rate 600 gpm @ 700 psi./50 rpm @ 5K torque./WOB=2-8K./Up wt.=110K-Rot wt.=100K-On wt.=95K1 9.1 ppg mud wt. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Drlg.Spur. 907-685-1227 337-277-1809 Drilling Supt. David Smith Eni Petroleum Drig.Spvr. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Drlg Spvr. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.347 L80 36.6 2,325.0 6/16/2011 Last Leakoff Test Depth(ftKB) r.(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) [Leak Off Pressure(psi) Eni E&P Division (Well Name:OP09-St El EN!Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO APIIUWI:50-029-23448-00-00 e 10• Date:6/18/2011 - Report#: 8 - page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator Well Configuration type 211-058 ENI PETROLEUM 1 ENI Share(%) 100.001 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 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(TVD...I Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) 'DFS(days) 0P09-51 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 6.00 Daily Information End Depth(ftKB) 'End Depth(TVD)(f..Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(fUhr) 'POB 'Temperature(°F) Weather I Wind 4,406.0 2,793.4 2,066.00 13.43 153.8 84.0 31.5 Clear,WC 28.2° 1158°ENE @ 3.3 mph Daily summary operation 24h Summary Finish drilling shoe track 52238'-52325'and clean out 1/23401 Drill 1/2340'-112360'plus 20'new hole.\Displace hole to new LSND mud.\Circulate and condition mud weights equal.Establish baseline ECD with K&M.\Perform LOT/FIT.\Drill Rotary Steerable t/2360'-54406'. Operation at 07,00 Drilling ahead as per well plan. 24hForecast Drill ahead rotary steerable 1/4406'as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 920 Time Log Start End 1 Cum Time Time Dur(hr)Ir Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL •E 3 P Drill out cement and shoe track 52238'-52325'-clean out 52340'\Pump rate 600 gpm @ 700 psi.\50 rpm @ 3-4K torque.\ W013=2-8K.\Up wt.=115K-On wt.=92K-Rol wt.=100K\9.1 ppg mud wt. 01:00 01:30 0.50 1.50 DRILL E 3 P Drill 1/2340'-52360'(20'new hole).\Pump rate 600 gpm @ 700 psi.\50 rpm @ 3-4.5K torque.\WOB=2-8K.\Up wt.=115K -Dn wt.=92K-Rot wt.=100K\ADT=0.21 hrs.\Jars=141.11 hrs. 01:30 03:00 1.50 3.00 DRILL E 7 P Held PJSM-Displace hole to new 92 ppg LSND mud-Rotate&reciprocate\Pump rate 435 gpm @ 325 psi.\50 rpm @ 3- 4K torque.\Up wt.=115K-Dn wt.=92K-Rot wt.=100K. 03:00 03:30 0.50' 3.50 DRILL E 1 P Shut down when new 9.2 LSND @ surface.\Clean shaker&empty pit#7 of old mud 03:30 04:00 ' 0.50" 4.00 DRILL 'E 7 P Circulate&condition new LSND mud until 9.?trot balanced mud weights in/out for LOT/FIT\Pumping 860 gpm @ 1120 psi.\ e Rotating&reciprocating.\Establish baseline ECD @ 9.60 ppg.&Rot 9.63 ppg. 1\,O' 04:00 05:00 160 5.00 DRILL E 12 P Perform LOT/FIT on 13 3/8"csg.with 9.2 ppg LSND-surface pressure 247 psi-RAM 11 A pn0 , `G r 05:00 05:30 0.50 5.50 DRILL E 5 P R/D test equipment and blow down-trouble shoot mud pumps blow/oiler. 05:3/5- 12:00 ' 6.50 1260 DRILL E 3 P Drill Rotary Steerable 1/2360'-52956'(2527').1 Pump rate 900 gpm @ 1370 psi.\120 rpm @ 3-6K torque.\WOB=2-10K.\ Up wt.=110K-Dn wt.=92K-Rot wt.=100K\Mud wt.=9.2 ppg.\ECD 9.61 ppg.\ADT=4.17 hrs.\Jars=145.28 hrs. 12:00 18:00 6.00 1860 DRILL E 3 P Drill Rotary Steerable f/2956'-53730'(2702').\Pump rate 905 gpm @ 1530 psi.\120 rpm @ 4-5K torque.\WOB=5-10K.\ Up wt.=110K-Dn wt.=85K-Rot wt.=100K\Mud wt.=9.2 ppg.\ECD 9.95 ppg.\ADT=4.89 hrs.\Jars=150.17 hrs. 18:00 -00:00 ' 660 2460 DRILL E 3 P Drill Rotary Steerable 1/3703'-54406'(2793'TVD).\Pump rate 905 gpm @ 1700 psi.\120 rpm @ 4.5 torque\WOB=5- 15K.\Up wt=110K-Rot wt.=100K-Dn wt.=80K\9.2 ppg mud wt.\ECD 10.15 ppg.\ADT=4.16 hrs.\Jars=154.33 his Total ADT=13.43 his Total Jars=154.33 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Drlg.Spvr, 907-685-1227 337-277-1809 Drilling Supt. David Smith Eni Petroleum Drlg.Spvr. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.347 L80 36.6 2,325.0 6/16/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,325.4 2,158.58 LSND Mud 9.20 246.0 11.39 1,277.6 Or* Eni E&P Division } 'Well Name:OP09-S1 I ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ • Date:6/1912011 - Report#: 9 APIIUWI:50-029-23448-00-00 2'r " page 1 of 1 Wellbore name: OP09-S1 Well Header PermitlConcession N° Operator ENI Share(%) I Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) (Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.401 12.20 0.00 16.27 21.87 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA __ _ NABORS 245E LAND RIG- Job Information Wellbore IJob Phase 'Spud Date Target Depth(ftKB) Target Depth(TVD..J Depth Dr.(MD)(ft) [Drilling Hours(hr) 'Avg ROP(ft/hr) DFS(days) 0P09-51 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.001 190.91 116.9 7.00 Daily Information _ End Depth(ftKB) 'End Depth(TVD)(f..I Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) IPOE 'Temperature(°F) 'Weather Wind 7,850.0 3,254.5 3,444.00 15.74 218.8 84.0 33.4 Clear,WC 26.8° 70°ENE @ 7.8 mph Daily summary operation 24h Summary Drill Rotary Steerable(/4406'-t/7850'./Load pipe shed with 9 5/8"csg.-strap&drift @ 8.75". Operation at 07.00 Drilling ahead as per well plan&parameters. 24h Forecast Drill ahead rotary steerable 67850'as per well plan to proposed TD @ 13,173'. Lithology Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 9.50 Time Log - Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 'P 'Drill Rotary Steerable(/4406'-t/5265'(2902'TVD).\Pump rate 900 gpm @ 1980 psi./120 rpm @ 5.5-6.8K torque.\WOB= 5-15K.\Up wt.=115K-Rot wt.=100K-Dn wt.=80K\9.25 ppg mud wt.\ECD 10.44 ppg.\ADT=3.82 hrs.\Jars=158.15 hrs. 06:00 12:00 6.00 12.00 DRILL E 3 P Dalt Rota.,Steerable V5265,1/6056'(3004'TVD).\Pump rate 900 gpm @ 2200 psi./140 rpm @ 7.8-8.2K torque.\WOB= 5-10K.\Up wt.=122K-Rot wt.=102K-Dn wt.=82K\9.3 ppg mud wt.\ECD 10.48 ppg.\ADT=3.61 hrs.\Jars=161.76 hrs. 12:00 1800 6.00 18.00 DRILL E 3 'P Drill Rotary Steerable 66056'-0/6988'(3135'TVD).\Pump rate 896 gpm @ 2300 psi.\140 rpm @ 7-9K torque./WOB=2- 22K.\Up wt.=132K-Rot wt.=105K-Dn wt.=78K\9.5 ppg mud wt.\ECD 10.51 ppg.\ADT=4.39 hrs.\Jars=166.15 hrs. 18:00 00:00 6.00 24.00 DRILL E 3 P Drill Rotary Steerable f/6988'-1/7850'(3255'TVD).\Pump rate 905 gpm @ 2360 psi.\120-140 rpm @ 8-10K torque.\ WOB=2-10K.\Up wt:135K-Rot wt.=105K-Dn wt.=78K\9.4 ppg mud wt.\ECD 10.35 ppg.\ADT=3.92 hrs.\Jars= 170.07 hrs. Total ADT=29.17 hrs. Total Jars=170.07 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. 'Frank Cormier 'Eni Petroleum Sr.Drlg.Spvr. ' 907-685-1227 337-277-1809 Drilling Supt. David Smith Eni Petroleum Drig.Spvr. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum [Mg Spvr. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date CASING 13 3/8 12.347 L80 36.6 2,325.0 6/16/2011 Last Leakoff Test Depth(ftKB) TVD(BKE) I Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 2,325.4 2,158.58 LSND Mud 9.20 246.0 11.39 1,277.6 Viiiiil Eni E&P Division .,i Well Name:OP09-S i ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ fill il(� Date:6/20/2011 - Report#: 10 API/UWI:50-029-23448-00-00 `�- page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concesslon N° I Operator ENI Share(%) !Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) IRKB-Base Flange(ft) IRKS-Tubing Spool(ft) 53.40 12.20 0.00 1E271 21.87 Rig Information Contractor I Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase 'Spud Date Target Depth(ftKB) Target Depth(TVD..J Depth Dr.(MD)(ft) !Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP09-61 DRILLING 6/13/2011 22.371.0 3,826.01 22,310.00 190.91 116.9 8.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,120.0 3,425.6 1,270.00 10.14 125.2 83.0 33.3 Partly Cloudy,WC 60°ENE @ 18.6 21.9° mph Daily summary operation 24h Summary Drill Rotary Steerable(/7850'-1/9120'-ROP drop-off,consult with town.\Circulate bottoms-up(K&M model)/POOH on elevators(/8422'-08325'-pulled 30K over-pull,RIH 1/86051 Circulated 1x bottoms- up.\POOH back reaming(/8605'-V7085'. Operation at 07.00 POOH back reaming 900 gpm @ 2000 psi.\120 rpm @ 6.5-7K torque. 24h Forecast POOH back reaming to 13 3/8"csg.shoe @ 2325.1 Circulate Bottoms-up+until clean.\POOH on elevators to BHA#4.\L/D BHA#4 and P/U BHA#5-visual/function test Power Drive and test MWD.\RIH 091201 Drill ahead as per well plan(/9120'. Lithology Shows I MAASP Pressure(psi) Mud Weight(lb/gal) 9.25 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00'DRILL E 3 P Drill Rotary Steerable 1/7850'-1/8690'(3366'TVD).\Pump rate 900 gpm @ 2540 psi.\140 rpm @ 9.5-12K torque.\WOB=5- 14K.\Up wt.=155K-Rot wt.=110K-Dn wt.=75K\9.3+ppg mud wt.\ECD 10.44 ppg.\ADT=4.04 hrs.\Jars=174.11 hrs. 06:00 12:00 6.00 12.00 DRILL E 3 P _ Drill Rotary Steerable f/8690'-t/9114'(34255TVQ).\Pump rate 850 gpm @ 2190 psi.\140 rpm @ 10.2-14K torque./WOB= 15-25K./Up wt.165K-Rot wt.=115K-Dn wt.=68K\9.2 ppg mud wt.\ECD 9.96 ppg./ADT=3.26 hrs.\Jars=177.37 hrs. 1200 17:00 5.00 17.00 DRILL E 3 P Drill Rotary Steerable t/9114'-119120'(3426'TVD).\Pump rate 900 gpm @ 2500 psi.\60-140 rpm @ 10-18K torque.\WOB= 20-35K.\Varied WOB and RPM to drill-shock/stick slip as WOB was increased.\Back ream 120'&wash back to bottom with same results.\Up wt.=165K-Rot wt.=115K-Dn wt.=70K\9.5 ppg mud wt.\ECD 9.9 ppg.\ADT=2.84 hrs.\Jars= 180.21 hrs. Total ADT=39.31 hrs. Total Jars=18021 hrs. 17:00 20:30 3.50 20.50 DRILL E 7 P Circulated bottoms-up 3.5X(rack back 2 stds per/hr.-total 7 stds.)(/9120'-1/84221 Reciprocate&rotate pipe./Pump rate 900 gpm @ 2400 psi.\120 rpm©9-11K torque./Monitor well. 20:30 21:00 0.50 21.00 DRILL E 4 P POOH on elevators(/8422'-V8325'(K&M model)-Pulled 30K over©8325'work several times-RIH 1/8325-118605'(lost down weight @ 8333')Wash down 08605'.\Pump rate 230gpm©350 psi.\80 rpm @ 8-9K torque. 21:00 22:00 1.00 22.00 DRILL E 7 P Circulate bottoms-up 10-Pumping 900 gpm @ 2350 psi.\Reciprocate&rotate 120 rpm @ 9-11K torque. 22:00 00:00 2.00 24.00 DRILL E 4 P POOH back reaming f/8605'-1/70851 Pumping 900 gpm @ 2175 psi.\120 rpm @ 8-10K torque./Monitoring torque, pressure,&ECD to dictate speed of back reaming. Daily Contacts Position Contact Name Company TKle E-mail Office Mobile Drilling Supt. Frank Cornier Eni Petroleum Sr.DrIg.Spar. 907-685-1227 337-277-1809 Dolling Supt. David Smith Eni Petroleum Dag.Spar. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Dolling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Dog Spar. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.347 L80 36.6 2,325.0 6/16/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,325.4 2,158.58 LSND Mud 9.20 246.0 11.39 1,277.6 Eni E&P Division 'Well Name:OP09-S■ PY* EN!Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO • 2�, Date:6/21/2011 - Report#: 11 APIIUWI:50-029-23448 00-00 If II page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) !Ground Level(ft) Water Depth(ft) IRKS-Base Flange(ft) I RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor /Rig Name 'Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase I Spud Date Target Depth(ftKB) Target Depth(TVD..JDepth Dr.(MD)(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) DFS(days) OP09S1 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 9.00 Daily Information End Depth(ftKB) End Depth(TVD)(L..Depth Progress(It) Drilling Hours(hr) -Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,120.0 3,425.6 0.00 83.0 33.3 Mostly Cloudy,WC 5°N @ 4.8 mph 28.4° Daily summary operation 24h Summary POOH back reaming f/7085'-03128'\Circulate-clear out flow line and possum belly due to an increase in cutting containing clay chucks-CBU 2.5x-ECD dropped 1/10.25-119.83 ppg.\Continue POOH back reaming f/3128'-112323'@ 13 3/8"shoe.\Circulated 3.5x bottoms-up-reciprocate&rotate sting.\POOH on elevators(/2323'-t/184'.\UD BHA#4\Clear floor and load components for BHA#5\P/U BHA#5. Operation at 07.00 RIH with BHA#5.1 P/U 5"DP singles. 24h Forecast Finish P/U BHA#5-visual/function test Power Drive and test MWD.\P/U 85 joints to replace culled 5"DP./RIH 09120'\Dull ahead as per well plan to proposed TD-13,173'MD. Lithology Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 10:00 1060 10.00 DRILL E 4 P POOH back reaming 1/7085-113128'\Pumping 900 gpm @ 1680 psi./120 rpm @ 4-5K torque.\Rot wt.=95K.\Monitoring torque,pressure,&ECD to dictate speed of back reaming.\UD 14 joints due to worn hard band. 10:00 12:00 ' 2.00 12.00"DRILL 'E 7 P Circulate-Increase in cutting containing clay chucks-unplug and clear out flow line and possum belly CBU 2.5x-stage pump rate up to 900 gpm @ 1600 psi.\ECD's drop from 10.25 ppg to 9.83 ppg.\Reciprocate&rotate 120 rpm @ 4-5K torque./Rot wt.=95K. 12:00 15:00 ' 3.00 15.00 DRILL E 4 P Continue POOH back reaming 1/3128'-02325'(13 3/8"shoe)\Pumping 900 gpm @ 1500 psi.\120 rpm @ 3-4K torque- slow down 080 rpm @ 3K torque 200'f/shoe.\Continue culling 5"DP with wom off hard band. 15:00 16:00 ' 160' 16.00'DRILL E 7 P Circulated bosoms-up 3.5x-until clean./Pump rate 900 gpm @ 1450 psi.\Reciprocate&rotate pipe./120 rpm @ 3-4K torque./Monitor well-static.\Pump dry job. • • 16:00 20:00 " 4.00 20.00-DRILL 'E -4 P POOH on elevators(/2323'-0184'\L/D ghost reamer(1/8"out gauge)\Continue culling 5"DP with bad hard band./UD total 87 joints with worn hard band. 20:00 22:00 2.00' 22.00 DRILL 'E 4 P UD BHA#4-check gauge for OD wear.\All tools in tact with stab showing most wear-NM ILS Stab between Telescope and ARC more down 1.875"out of gauge. 22:00 00:00 ' 2.00' 24.00'DRILL "E 4 'P Clean&clear floor.\Down load data f/LW D.\Load floor with new components and bit.\P/U BHA#5. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum -Sr.Ddg.Spvr. 907-685-1227 337-277-1809 Dolling Supt. David Smith Eni Petroleum Ddg.Spvr. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Dulling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) Run Date CASING 133/8 12.347 L80 36.6 2,325.0 6/16/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) I Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,325.4 2,15658 LSND Mud 9.20 2460 11.39 1,277.6 • I Eni ESP Division 1 Well Name:OP09-S1 1 ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO 2^ • Date:612212011 - Report#: 12 API/UW1:50-029-23448-00-00 �( I'u page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 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(TVD...I Depth Dr.(MD)(ft) !Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P09-S1 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 1169 10.00 Daily Information End Depth(ftKB) I End Depth(TVD)(f.. Depth Progress(ft) !Drilling Hours(hr) Avg ROP(ft/hr) I POB !Temperature(°F) Weather Wind 9,146.0 3,428.2 26.00 7.38 3.5 86.0 32.2 Overcast,WC 25.3° 355°N @ 7.5 mph Daily summary operation 24h Summary P/U BHA#5 02861 Service rig and load 5"DP in pipe shed.\RIH-P/U 5"DP singles(/286'-1/3062'break circulation @ 13 3/8"csg shoe.)Continue RIH from derrick(/3062'-1/8995'-tag @ 2700'w/20K; 4465'w/20K;5078'w/25K and pump thru;5500'w/20K/Ream/wash(/8995'-1/9120'.1 Drill rotary steerable f/9120'-1/9146'(cemented siltstone)-low ROP/Increasing parameters of WOB&pump rates.! Monitor Schlumbereger stick-slip,shock down hole reading and torque to maintain acceptable levels. Operation at 07.00 Drilling ahead rotary steerable. 24h Forecast Drill ahead rotary steerable as per well plan to proposed TD-13,173'MD. Lithology Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.25 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 4 P P/U BHA#5-M/U-ARC 825,NM ILS stab,Telescope,NM stab,NMDC&2 NM Flex DC,Saver/float sub-RIH w/jars&5" HWDP 0286'.1 Loading 5"DP in short side. 03:30 04:30 1.00 4.50 DRILL E 25 P Service Rig;Top Drive&grease rails,Draw-works&Crown,\Load short side with 5"DP&strap to replace culled pipe from trip out. 04:30 08:30 4.00 8.50 DRILL E '4 P RIH P/U 5"DP singles(87 jts.)-(/286'-03062'(drifted to 2.86")\Fill every 20 stds and swallow test MWD @ 9881 700 gpm @ 850 psi.\Break circulation in 13 3/8"csg shoe @ 22921 710 gpm @ 920 psi. 08:30 13:00 4.50 13.00 DRILL E 4 P Continue RIH(/3062'-1/89951 Tag @ 2700'-1/2720 with 20K/(/4465'-04497 with 20K work thru both spots./(/5078'-1/5098' tag with 25K-pump thru with 500 gpm @ 850 psi.)Tag 5500'-05546'with 20K and work thru.)Filling pipe @ 4114' pumping 711 gpm @ 1410 psi./Displace DP volume @ 6028'. 13:00 13:30 0.50 13.50 DRILL E 6 P Ream/wash(/8995'-09120'-Pumping 750 gpm @ 2100 psi.)55 rpm @ 11K torque. 13:30 00:00 10.50 2490 DRILL E 3 P _Drillin�g1 rotary steerable 09120'-1/9146'(TVD 3429')\Adjusted bit weight accordingly to maintain acceptable level of ..... Schlum3erger slick-slip and shock/vibration reading,14-26K torque.)Stage rate up 8750 gpm @ 2050 psi.-1/900 psi.@ 2500 psi.)62 rpm @ 14-17K torque)WOB=5-25K.\Up wt.=165K-Rot wt.=115K-Dn wt.=70K/9.2 ppg mud wt.\ECD 9.85 ppg.\ADT=7.38 hrs.)Jars=187.59 hrs. Total ADT=7.38 hrs. Total Jars=187.59 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.DrIg.Spvr. 907-685-1227 337-277-1809 Drilling Supt. David Smith Eni Petroleum DrIg.Spvr. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Drig Spvr. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 133/8 12.347 L80 36.6 2,325.0 6/16/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,325.4 2,158.58 LSND Mud 9.20 246.0 11.39 1,277.6 li#41 Eni E&P Division (Well Name:OP09-S i EN!Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO • e n u n Date:6/23/2011 - Report#: 13 APIIUWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) 'Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 1827 21.87 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase 'Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP09-S1 DRILLING I 6/13/2011 22,371.0 3,826.0 22,310.00 190.91 116.9 11.00 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,158.0 3,429.4 12.00 16.01 0.7 84.0 34.2 Cloudy,Rain,WC 46°@ 16 mph 24.V Daily summary operation 24h Summary Drill rotary steerable 1/9146'-69152'(cemented siltstone)-Varied parameters of WOB,RPM&pump rates to increase ROP.\Back ream 1/9152'-1/8995-Ream/wash section twice at slow rate.\Drill rotary steerable 1/9152'-09158'hard formation(cemented siltstone)Monitor stick-slip,shock/vibration down hole and torque while varying parameters to increase ROP and maintain acceptable levels.\POOH back ream 1/9158'-06506'\Circulate bottoms-up @ 6506'reciprocate&rotate pipe 1/6411'. Operation at 07.00 POOH with BHA#5 on elevators. 24h Forecast Finish CBU @ 6506'2x\Flow check-static.\POOH on elevators with BHA#5\P/U tools to change configuration and mill tooth bit for BHA#6-Perform visual/function on Power Drive and shallow hole test MWD.\RIH 09158'.\Drill ahead as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drilling rotary steerable(/9146'-09152'(TVD 3435)1 900 gpm @ 2440 psi.\42-77 rpm @ 10-19K torque\WOB=24-28K.\ Slow ROP due to cemented siltstone and inclination @ bit building.\Up wt.=165K-Rot wt.=110K-Dn wt.=70K\9.2 ppg mud wt.\ECD 9.76 ppg.\ADT=5.11 hrs.1 Jars=192.70 hrs. 06:00 08:30 2.50 8.50 DRILL E 3 P Drilling rotary steerable(/9152'-09152'(TVD 3430')/900 gpm @ 2520 psi.\100 rpm @ 12-15K torque\WOB=11K.\ Reduce weight on bit and increased rpm to maintain acceptable level of stick-slip and shock/vibration on Schlumberger tools.1 Drilled down to depth due to running of higher WOB.\Up wt.=165K-Rot wt.=110K-Dn wt.=75K\9.2 ppg mud wt.\ ECD 9.76 ppg.\ADT=2.4 hrs.\Jars=195.10 hrs. 08:30 09:30 1.00 9.50 DRILL E 7 P Back ream(/9152'-08995\900 gpm @ 2520 psi.\100 rpm @ 12-15K torque\Rot wt.=110K\9.2 ppg mud wt\ECD 9.84 ppg\Wash&ream back to bottom twice at slow rate. 09:30 12:00 2.50 1200 DRILL E 3 P Drilling rotary steerable f/9152'-69154'(TVD 3430')\900 gpm @ 2500 psi\100 rpm @ 12-15K torque\WOB=16K\Up wt.= 165K-Rot wt.=110K-Dn wt.=70K/9.2 ppg mud wt.\ECD 9.78 ppg\ADT=2.36 hrs.\Jars=197.46 hrs.\Varied drilling parameters to increases ROP. 12:00 18:30 6.50 18.50 DRILL E 3 P Drilling rotary steerable f/9154'-1/9158'(TVD 3431')\900 gpm @ 2500 psi./100-130 rpm @ 13-15K torque\WOB=14-20K.\ Up wt.=165K-Rot wt.=110K-Dn wt.=70K\9.2 ppg mud wt.\ECD 9.77 ppg.\ADT=6.14 hrs.1 Jars=203.60 hrs. Total ADT=23.39 hrs. Total Jars=203.60 hrs. 18:30 23:30 - 5.00 23.50 DRILL E 4 P POOH back reaming f/9158'-06506\Pumping 900 gpm @ 2080 psi.\120 rpm @ 7.5K torque.\Rot wt.=103K\9.2 ppg mud wt.\ECD 9.77 ppg.\Monitoring torque&pump pressure plus ECD for rate of back reaming. 23:30 00:00 0.50 24.00 DRILL E 7 P Circulate bottoms-up-rotate&reciprocate string.\Pumping 900 gpm @ 2080 psi\120 rpm @ 7.5K torque.\ROT wt.= 103K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Comrier Eni Petroleum Sr.Drig.Spur. 907-685-1227 337-277-1809 Drilling Supt. David Smith Eni Petroleum Drlg.Spvr. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Ddg Sow. .907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 133/8 12.347 L80 36.6 2,325.0 6/16/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,3254 2,158.58 LSND Mud 820 2480 11.39 1,277.6 Viiiiii Eni E&P Division Well Name:OP09-S EN/Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO •p e n N Date:6/24/2011 - Report#: 14 APIIUWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) !Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor I Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) I Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP09-S1 DRILLING 6/13/2011 22,371.0 3,826.0 22,310.00 190.91 116.9 12.00 Daily Information End Depth(ftKB) I End Depth(ND)(f..Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) I POB !Temperature(°F) Weather Wind 9,158.01 3,429.4 0.00 85.0 33.6 Fog.WC 27.1° 69°ENE @ 7.3 mph Daily summary operation 24h Summary Finish circulate bottoms-up @ 6506'reciprocate 8 rotate pipe 064111 Monitor well-static.\POOH on elevators f/6026'-1/2869 L/D BHA#5\P/U BHA#6 visual/function test.\RIH P/U 18 joints 5"drill pipe t/950'and pipe from derrick 01042'perform shallow test on MWD-good.\RIH t/1042'-06975'-Break circulation @ 13 3/8"csg.and fill every 20 stds.-Schlumberger check shot survey. Operation at 07.00 Drilling rotary steerable on cemented siltstone formation. 24h Forecast RIH with BHA#6-fill pipe&MWD survey every 20 stands.\Wash 8 ream f/8986'to tag @ 91101 Drill ahead rotary steerable Lithology Shows MAASP Pressure(psi) Mud Weight(113/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 7 P Circulate bottoms-up(total 2x)-rotate&reciprocate string.\Pumping 900 gpm @ 2080 psi\120 rpm @ 7K torque.\ROT wt.=100K.\Flow check-static. 00:30 05:00 4.50 5.00 DRILL E 4 'P POOH on elevators f/6506'-03923'per K&M model:f/6500-06000'@ 7 min/std-f/6000'-64500'5 min/std-f/4500'-03000' 2.5 min/std.\Work thru areas f/5632'-05510'&114190'-04180'.\Culling 5"DP with wom hard band 05:00 05:30 0.50 5.50 DRILL E 25 XR99 Downtime:due to iron roughneck hydraulic hose developed a leak-replaced with new. 05:30 09:00 3.50 9.00 DRILL E 4 P POOH on elevators 63923'-0286'per KW model:1.5 min/std f13000'-0surface.\Work thru f/2760'-02740'.1 Total 18 its.5" DP L/D due worn hard band. 09:00 11:30 2.50 11.50 DRILL E 4 P Held PJSM-L/D BHA#5. 11:30 12:30 1.00 12.50 DRILL E 4 P Clean&clear floor.\Load floor with new components and but for BHA#6. 12:30 13:30 1.00 13.50 DRILL E 4 P RIH with stand of NMDC-L/D bottom DC and P/U new Flex NMDC\rack back in derrick. 13:30 18:00 4.50 18.00 DRILL E 4 P Held PJSM-P/U BHA#6 as per Schlumberger.\M/U Power Drive-Receiver-Power Pulse MWD-NM ILS stab-ARC 825-NM stab\Perform visual/function test on Power Drive.\RIH with NM Flex DC,Saver/float sub and stand of jars&5" HWDP 0277'. 18:00 18:30 0.50 18.50 DRILL E 25 P Service rig-draw-works,crown,top drive also change out lube filter and clean y-strainer on lube system.\Load 5"DP in short side. 18:30 19:30 1.00 19.50 DRILL E 4 P RIH with BHA#6-P/U 18 joints of 5"DP singles(1277-0950'continue RIH with stands f/950'-01042'-perform shallow test i on MWD-good. 19:30 00:00 4.50 24.00 DRILL E 4 P RIH(11042'-069751 Break circulation and pump drill pipe volume @ 13 3/8"shoe and fill every 20 stands-Schlumberger MWD survey @ 2957'.4100',6014'.1 Pump rate 640 gpm @ 1546 psi.\Up wt.=111K-Dn wt.=70K. Daily Contacts Position Contact Name 1 Company Title E-mail ) Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Drlg.Spvr. Jack.Keener@enipetroleum.com 1907-685-1277 907-715-6434 • Drilling Supt. David Smith Eni Petroleum Dug.Spur. 907-685-1277 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Drip Spur. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 133/8 12.347 L80 36.6 2,325.0 6/16/2011 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 2,325.4 2,158.58 LSND Mud 9.20 246.0 11.391 1,277.6 fI"" j Eni E&P Division .} Well Name:OP09-S I 1 ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ • Date:6/25/2011 - Report#: 15 API/UWI:50-029-23448-00-00 e i ii page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share)%) I Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) !Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore IJob Phase 'Spud Date Target Depth(RKB) Target Depth(TVD..]Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(fUhr) I DFS( days) 0P09-51 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 13.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 10,254.0 3,575.7 1,096.00 12.34 88.8 87.0 35.4 Mostly Clear,WC 69°ENE @ 11 mph 27.5° Daily summary operation 24h Summary RIH with BHA#6 t/8986'-Schlumberger survey @ 7932'\Wash&ream 1/8986'-09158'-Tag @ 9110'took 8-20K WOB t/9118'broke thru and continue to bottom\Drill ahead rotary steerable f/9158'- 010254'varying parameters as formation dictated. Operation at 07.00 Drilling rotary steerable @ 10,422'MD. 24h Forecast Drill ahead rotary steerable(/10,254'to proposed 9 5/8"csg TD-13,173'as per well plan. Lithology Shows I MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr)_Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 4 P RIH f16975'-08986'\fill every 20 stands-Schlumberger MWD survey @ 7932'.\Pump rate 720 gpm @ 1780 psi.\Up wt.= 168K-Dn wt.=68K. 01:30 04:30 3.00 4.50 DRILL E 6 P Ream and wash f/8986'-09158'-Tag @ 9110'took 8-20K weight to ream thru to 9118'fell thru,continue reaming to bottom.\Pumping 850 gpm @ 2420 psi.\65 rpm @ 12K torque./Up wt.=168K-Dn wt.=68K-Rot wt.=118K. 04:30 12:00 7.50 12.00 DRILL E 3 P Drilling rotary steerable f/9158'-1/9561'(TVD 3482')1 900 gpm @ 2540 psi./135 rpm @ 12-15K torque\WOB=20-40K.\Up wt.=165K-Rot wt.=112K-Dn wt.=70K\9.3 ppg mud wt.\ECD 10.19 ppg.\ADT=5.46 hrs.\Jars=209.06 hrs. 12:00 14:00 2.00 14.00 DRILL E 25 XR04 Downtime:Top Drive-change out encoder replace with new.Service rig. 14:00 18:00 490 18.00 DRILL E 3 P Drilling rotary steerable f/9561'-010,040'(TVD 3549')/880 gpm @ 2660 psi.\100-135 rpm @ 11.7-17K torque\WOB=30- 40K.\Back ream 30'every connection.\Up wt.=180K-Dn wt.=60K-Rot wt.=108K-(Dry Rot wt.=118K @ 16.5K torque)\ 9.3 ppg mud wt.\ECD 10.48 ppg.1 ADT=2.78 hrs.\Jars=211.84 hrs 18:00 00:00 6.00 24.00 DRILL E 3 P Drilling rotary steerable 1/10,040'-010.254'(TVD 35351\901 gpm @ 2850 psi.\100-130 rpm @ 16.4-18K torque WOB=8- 30K.\Back ream 30'every connection.\Up wt.=175K-On wt.=62K-Rot wt.=110K-(Dry Rot wt.=119K @ 15.9K torque)/ 9.3 ppg mud wit ECD 10.27 ppg.\ADT=4.10 hrs.\Jars=215.94 hrs Total ADT=12.34 hrs. Total Jars=215.94 hrs. - Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Drig.Spvr. Jack.Keener@enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. David Smith Eni Petroleum Drig.Spar. 907-685-1277 907-632-3058 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Dng Spar. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.347 L80 36.6 2,325.0 6/16/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,325.4 2,158.58 LSND Mud 9.20 246.0 11.39 1,277.6 Eni E&P Division 'Well Name:OP09-S-1 Volt ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ e n i Date:6126/2011 - Report#: 16 APIIUWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header PermitlConcession N° Operator ENI Share(%) 1Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information 'Contractor (Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase 'Spud Date Target Depth(ftKB) Target Depth(TVD..J Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P09-51 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 14.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) 'POB Temperature(°F) 'Weather Wind 11,856.0 3.785.6 1,602.00 17.15 93.4 88.0 38.5 Clear,WC 28.6° 90°E @ 19.5 mph Daily summary operation 24h Summary Drill rotary steerable f/10,254'-511,320'\Service rig.\Drill rotary steerable f/11,320'-611,856'per well plan. Operation at 07.00 Drilling ahead with rotary steerable assembly @ 12,185'MD. 24h Forecast Drill ahead rotary steerable(/11,856'to proposed 9 518"csg TD-13,173'as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00'DRILL E 3 P Drilling rotary steerable(/10,254'-510,550'(TVD 3612')\900 gpm @ 2820 psi.\135 rpm @ 13-16K torque\WOB=11-25K.\ Back ream 30'every connection.\Up wt.=170K-Dn wt.=70K-Rot at 120K\9.2+ppg mud wt.\ECD 10.17 ppg.\ADT= 4.82 hrs.\Jars=220.76 hrs. 06:00 12:00 6.00 12.00 DRILL E 3 P Drilling rotary steerable(/10,550'-511,188'(TVD 36771\900 gpm @ 2960 psi.\135 rpm @ 15-18K torque\WOB=30-40K.\ Back ream 30'every connection.\Up wt.=180K-Dn wt=70K-Rot wt.=120K\9.2+ppg mud wt.\ECD 10.51 ppg.\ADT= 4.01 hrs.\Jars=224.77 hrs. 12:00 13:30 1.50 13.50 DRILL E 3 P Drilling rotary steerable 1/11,188'-511,320'(TVD 36911\901 gpm @ 3150 psi.\135 rpm @ 18-20K torque\WOB=25K.1 Back ream 30'every connection.\Up wt.=180K-Dn wt.=70K-Rot wt.=120K-(Dry Rot wt.=122K @ 16.2K torque)\9.4 ppg mud wt.\ECD 10.59 ppg.\ADT=0.83 hrs.\Jars=225.60 hrs. 13:30 14:00 0.50 14.00-DRILL E 25 P Service rig-Clean motor radiators due to ovemeatirg. 14:00 18:00 4.00 18.00 DRILL E 3 P Drilling rotary steerable f/11,320'-511,377'(TVD 37281\900 gpm @ 3170 psi\135 rpm @ 18-20K torque\WOB=25K.\ Back ream 30'every connection.\Up wt.=186K-Dn wt.=62K-Rot wt.=110K-(Dry Rot wt.=122K @ 17.8K torque)\9.4 ppg mud wt.\ECD 10.59 ppg.\ADT=3.14 hrs.\Jars=228.74 hrs. 18:00 00:00 6.00 24.00 DRILL E 3 P Drilling rotary steerable f/11,377'-511,856'(TVD 37851\901 gpm @ 3220 psi.\135 rpm @ 18-21K torque\WOB=25K.\ Back ream 30'every connection.\Up wt.=190K-Dn wt=70K-Rot wt.=110K-(Dry Rot wt.=122K @ 18.9K torque)\9.4 ppg mud wt.\ECD 10.63 ppg.\ADT=4.35 hrs.\Jars=233.09 hrs Total ADT=29.49 hrs. t Total Jars=233.09 hrs. Daily Contacts Position Contact Name Company Title E-mall _ Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Drlg.Spvr. Jack.Keener@enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. David Smith Eni Petroleum Ddg.Spvr. 907-685-1277 907-632-3058 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Em Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push .Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Dolling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Dug Spvr. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.347 L80 36.6 2,325.0 6/16/2011 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) 'Leak Off Pressure(psi) 2,325.4 2,158.58 LSND Mud 9.20 246.0 11.39 1,277.6 Viks Eni E&P Division I Well Name:OP09-S i ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ e n i Date:6/27/2011 - Report#: 17 APIIUWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(k) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(k) 5340 12.20 0.00 16.27 21.87 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(TVD..]Depth Dr.(MD)(ft) !Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P09-51 DRILLING 6/13/2011 22,3710 3,826.01 22,310.00 190.91 116.9 15.00 Daily Information End Depth(ftKB) •End Depth(TVD)(f..Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 13,220.0 3,9296 1,364.00 10.86 125.6 88.0 38.3 Mostly Clear,WC 9V E @ 25.4 mph 27.3° Daily summary operation 24h Summary Drill rotary steerable(/11,856'-1/13,2209 Circulate bottoms-up-setting back one stand(/13,220'-1112,908'&set back two stand(/12,908-1112,621'after each bottoms-up. Operation at 07.00 POOH back reaming as per well plan&K&M model 5-10 mins per stand or as hole condition dictates. 24h Forecast Finish circulating bottoms-up,setting back two stands each CBU.\POOH back reaming to 13 318"csg shoe.K&M model:5-10 minslstds speed or as well bore condition dictates./Circulate bottoms-up until clean @ shoe.\POOH L/D BHA#6\Change upper rams to 9 5/8"csg.and test 250/3500 psi. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P 'Drilling rotary steerable(/11,856'-1112,408'(TVD 3844')\900 gpm @ 3420 psi./135 rpm @ 13-20K torque\WOB=30-35K.\ Back ream 30'every connection.\Up wt.=180K-Dn wt.=72K-Rot wt.=122K-(Dry Rot wt.=122K @ 18.9K torque)/9.4 ppg mud wt.\ECD 10.85 ppg.\ADT=4.4 hrs.\Jars=237.44 hrs. 06:00 12:00 6.00 12.00 DRILL E 3 P Drilling rotary steerable f/12,408'-1112,908'(TVD 3899)1 888 gpm @ 3540 psi.\135 rpm @ 15-21K torque\WOB=35-40K.\ Back ream 30'every connection.\Up wt=185K-Dn wt.=70K-Rot wt.=122K\9.4 ppg mud wt.\ECD 10.99 ppg.\ADT= 4.08 hrs.\Jars=241.52 hrs. /(p 12:00 17:00 5.00 17.00 DRILL E 3 P Drilling rotary steerable f/12,908'-1/13,220'(TVD 393011 880 gpm @ 3560 psi.\135 rpm @ 18-20K torque\WOB=20-25K.1 t _ °back ream 30'every connection.\Up wt.=188K-Dn wt.=68K-Rot wt.=112K-(Dry Rot wt.=125K @ 19K torque)\9.4 ppg ,. mud wt.\ECD 11.06 ppg.\ADT=2.38 hrs.\Jars=243.90 hrs. I ,v' Total ADT=40.35 hrs. } Total Jars=24390 hrs. 17:00 21:00 4.00 21.00 DRILL E 7 P Circulate bottoms-up(/13,220'-1/12,9081 Pumping 900 gpm @ 35501 140 rpm @ 17.8K torque.\Rot wt.=115K\Rack back one stand every bottoms-up.\Mud wt.=9.4 ppg\ECD=10.9 ppg.•21:00 00:00 3.00 24.00 DRILL E 7 P Circulate bottoms-up 1/12,908'-1/12,6211 Pumping 900 gpm @ 35101 140 rpm @ 17.8K torque.1 Rot wt.=114K\Rack back two stand every bottoms-up./Mud wt.=9.4 ppg\ECD=11.06 ppg. Daily Contacts Position Contact Name Company Title E-mail Office i Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Drlg.Spvr. Jack.Keener@enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. David Smith Eni Petroleum Mtg.Spa. 907-685-1277 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 EN representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 • Drilling Supt. Mirko Musumeci Eni Petroleum Dug Spvr. 907-685-1277 907-903-7269 i Last Casing seat Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.347 L80 36.6 2,325.0 6/16/2011 Last Leakoff Test Depth(RKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,325.4 2,158.58 LSND Mud 9.20 246.0 11.39 1,277.6 Sitiil Eni E&P Division ..L 'Well Name:OP09-Si EN!Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ (��H II'' •g ,yam,yam N Date:6/28/2011 - Report#: 18 APIIUWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° 'Operator ENI Share(%) 'Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.401 12.20 0.0011. 16.27 21.87 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(TVD..J Depth Dr.(MD)(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) DFS(days) OP09-51 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.9111 116.9 16.00 Daily Information End Depth(ftKB) 'End Depth(TVD)(I..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(fUhr) 'DOB 'Temperature(°F) 'Weather Wind 13,220.0 3,929.6 0.00 90.0 30.6 Fog,WC 21.6° 11°N @ 10.6 mph Daily summary operation 2411 Summary Finished CBU-rack back two stands during each bottoms-up 1/12,621'-012,1421 POOH back reaming(/12,142'-04,584'per plan and K&M model. Operation at 07.00 POOH back reaming @ 3,210'per plan and K&M model. 24h Forecast Finish POOH back reaming f/4,584'-62325'@ 13 3/8"csg shoe.\Circulate bottoms-up 3-5X or until clean.\POOH on elevators and L/D BHA#6\Change upper rams to 9 5/8"csg.and test 250/3500 psi.\ Install short wear ring.\R/U Tesco 9 5/8"csg.running tool&equipment-function test.\P/U shoe track&check Float equipment.\RIH-P/U 9 5/8"csg. Lithology Shows 'MAASP Pressure(psi) Mud Weight(lb/gal) 9.45 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 7 P Circulate bottoms-up(2 1/2x more)612,621-012,1421 Pumping 900 gpm @ 34601 140 rpm @ 17.8K torque.\Rot wt.= 110K\Rack back two stand every bottoms-up.1 Mud wt.=9.45 ppgl ECD=10.88 ppg.1 Monitor well-static.\SLM.\ Circulated a total 7x after TD. 03:30 12:00 8.50' 12.00 DRILL E 4 P POOH back reaming(112,142'-119,465'as per well plan/K&M model:5-10 mins/std.\Pump rate of 900 gpm @ 3020 psi.' 140 rpm @ 14.6K torque.\Rot wt.=108K\Mud wt.=9.45 ppg\ECD=10.75 ppg.\SLM 12:00 18:00 6.00 18.00 DRILL E 4 P 'POOH back reaming f/9,465'-06,910'as per well plarVK&M model\Pump rate of 900 gpm @ 2400 psi.\140 rpm @ 8.5K torque.\Rot wt.=104K\Mud wt.=9.5*ppg\ECD=10.53 ppg.\SLM. 18:00 00:00 ' 6.00 24.00 DRILL E 4 'P 'POOH back reaming(/6,910'-04,584'as per well plan/K&M model.\Pump rate of 900 gpm @ 1800 psi.\140 rpm @ 5K torque.\Rot wt.=98K1 Mud wt.=9.5 ppg\ECD=9.90 ppg.\SLM\Tight spot f/4,650'-04,610'torque increase,but with no pump pressure increase,work through&cleaned up. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Drip.Spvr. Jack.Keener@enipetroleum.com °907-685-1277 +907-7156434 V Drilling Supt. David Smith Eni Petroleum Drig.Spvr. 907-685-1277 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 EN representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Dolling Supt. Mirko Musumeci EN Petroleum Drig Spur. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) Run Date CASING 133/8 12.347 L80 36.6 2,325.0 6/16/2011 Last Leakoff Test Depth(MB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) 'Leak Off Pressure(psi) 2,325.4 2,158.58 LSND Mud 9.20 246.0 11.391 1,277.6 16* Eni E&P Division 1 Well Name:OP09-S1 EN/Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO • e n p N Date:6/29/2011 - Report#: 19 API/UWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° 'Operator ENI Share(%) (Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.401 12.20 0.00 16.27 21.87 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(TVD...I Depth Dr.(MD)(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) DFS(days) OP09-51 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 17.00 Daily Information End Depth(ftKB) 'End Depth(ND)((..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB •Temperature(°F) 'Weather 'Wind 13,220.01 3,929.6 0.00 91.0 30.7 Cloudy,WC 24.3° 355°N @ 6.6 mph Daily summary operation 24h Summary Finish POOH back reaming f/4,584'-t12,382'./Circulate bottoms-up f/2,382-1/1,999'-set back one stand each BU-Circulate bottoms-up 2x&clean @ 1,999'\POOH on elevators and L/D BHA#6\ Change upper rams to 9 5/8"csg.and test 250/3500 psi.\Install short wear ring.\R/U Tesco 9 5/8"csg.running tool&equipment-function test.\P/U shoe track&check float equipment.\RIH-P/U 9 5/8" csg.(40#/L-80/Hydril 563/Special drift 8.75"(-empty/floating in the hole.\Notified AOGCC(left a message)of 9 5/8"csg.run and up coming BOPE test Friday July 1st. Operation at 07.00 P/U 9 5/8"csg.(40#/L-80/Hydril 563/Special drift 8.75")-RIH empty(floating csg.in hole). 24h Forecast RIH-P/U 9 5/8"csg.(40#/L-80/Hydril 563/Special drift 8.75")as per well plan with K&M model to 13,195' Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:30 5.50' 5.50 DRILL E 4 P POOH back reaming f/4,584'-62382'as per well plan/K&M model./Pump rate of 900 gpm @ 1430 psi.\140 rpm @ 2K torque.\Rot wt.=95K\Mud wt=9.4 ppg\ECD=9.78 ppg.\SLM\Wipe section twice(/4,441'-1/4,380'due to torque increase to 7-8K,no psi increase. 05:30 08:00 2.50 8.00 DRILL 'E 7 P Circulate bottoms-up 1/2,386'-1/1,999'(32°inclination)rack one stand each BU\Circulate clean @ 1,999'(BU 2x).\Pump rate of 900 gpm @ 1370 psi.\140 rpm @ 1.8K torque.\Rotate&reciprocate string.\Rot wt.=94K\Mud wt.=9.4 ppg\ECD= 9.63 ppg./Monitor well-static./Pump dry job. 08:00 09:00 ' 1.00 9.00 DRILL E 4 P POOH on elevators(/1,999'-V277'to BHA#6/SLM. 09:00 12:00 3.00 12.00 DRILL E 4 P Held PJSM\UD BHA#6-all components from 5"HWDP to bit.\Clear&clean floor and unload pipe shed./Load Schlumberger tools on truck to Deadhorse. 12:00 15:00 3.00 15.00 DRILL G 5 P Change top rams from 4 1/2"x 7"variables to 9 5/8"csg. / l� 15:00 15:30 0.50 15.50 DRILL G 5 P Pull wear bushing&set test plug with Vetco Gray. 1 15:30 17:00 1.50 17.00 DRILL G 12 P Test 9 5/8" `� csg.rams to 250 psi.Low/3500 psi.High-to AOGCC requirements(chart record). Re-torque test joint. �y 17:00 17:30 0.50 17.50 DRILL G 5 P Pull test plug&Vetco Gray install special short wear ring. t 17:30 20:00 2.50' 20.00 DRILL G 1 P 'Held PJSM-R/U Tesco casing/drilling system on top drive to run 9 5/8"csg./Function test equipment same. 20:00 20:30 0.50' 20.50 DRILL G 1 P Held PJSM to run 9 5/8"csg.(40#/L-80/Hydril 563/Special deft 8.75")with Tesco-discussed procedures in well plan, well control.and tally. 20:30 00:00 3.50 24.00 DRILL G 4 P P/U 9 5/8"csg.(40#/L-80/Hydril 563/Special drift 8.75")-fill shoe track and check float equipment-good.\RIH 6853'- running speed @ 1-1 1/2 mins./jt./Make-up 13.4K\On wt.=52K\Mud weight=9.4 ppg. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. 'Jack Keener Eni Petroleum Sr.Deg.Spvr. 'Jack.Keener@enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. David Smith Eni Petroleum Deg.Spvr. 907-685-1277 907-632-3058 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter 69 Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Drtg Spvr. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 -5.8 13,195.0 6/30/2011 Last Leakoff Test Depth(RKB) ND(RKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,325.4 2,158.58 LSND Mud 9.20 246.0 11.39 1,277.6 411i* Eni E&P Division Well Name:0P09 S i I EN!Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO Q e n u U Date:6/30/2011 - Report#: 20 API/UWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° 'Operator ENI Share(%) 'Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) 'RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0001 16.27 21.87 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore 'Job Phase 'Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(Br) Avg ROP(ftlhr) DFS(days) 0P09-51 DRILLING 1 6/13/2011 22,371.0 3,826.0 22,310.00 190.91 116.9 18.00 Daily Information End Depth(ftKB) End Depth(ND)(f..Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather Wind 13,220.0 3,929.6 0.00 90.0 38.7 Cloudy,WC 37° 297°WNW @ 1.8 mph Daily summary operation 24h Summary P/U 9 5/8"csg.(40#/L-80/Hydril 563/Special drift 8.75")Floating in the hole./Slack-off f/853'-1/50931 Rotated(/5093'-1/12,008'started with 45 rpm @ 2.3K torque and stage increase to 75 rpm @ 7.9K torque.Rotating 36K\Final slack-off friction factor 1.66 @ 12,008'.\Called AOGCC @ 0900 hrs.for 24 hrs notification,talked to Chuck Scheve and we will up date in the morning. Operation at 07.00 Filling 9 5/8"csg with 9.4 ppg LSND mud. 24h Forecast Continue RIH 1/12,008'-613,195'casing point-P/U 9 5/8"csg.(408/L-80/Hydril 563/Special drift 8.75")\R/U fill 9 5/8"csg with 9.4 ppg LSND mud.\P/U&R/U Schlumberger cement head-circulate& condition mud.\PJSM with Schlumberger-mix&pump cement-displace&bump plugs with rig pumps./Perform injective test with mud.\P/U BOP stack-cut and install emergency slips-set BOP&test pack-off\Freeze protect.\R/U to test BOP. Lithology Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act Plan Oper.Descr. 00:00 07:30 7.50 7.50 DRILL G 4 P P/U 9 5/8"csg.(408/L-80/Hydril 563/Special drift 8.75")Floating\RIH f/853'-1/5093'-running speed @ 1-1.5 min/jt.\ Make-up 13.4K\Dn wt=47K(top drive wt.)\Mud weight=9.4 ppg. 07,30 12:00 4.50 12.00 DRILL G 4 P P/U 9 5/8"csg.(408/L-80/Hydril 563/Special drift 8.75")Floating\Started rotating RIH(/5093'-673871 45 rpm @ 2.3K torque-Rot wt.=54K\6712'increased to 50 rpm @ 3.5K torque-Rot wt.=50K\Speed©1-1.5 min/jt.\Make-up 13.4K\ Mud weight=9.4 ppg.\Slack-off friction factor 087©7387'. 12:00 18:00 6.00 18.00 DRILL G 4 P P/U 9 5/8"csg.(40#/L-80/Hydril 563/Special drift 8.75")Floating\RIH rotating f/7387'-09884160 rpm @ 6.5K torque- Rot wt.=47K static\Speed @ 1.5-2.5 minljt.\Make-up 13.4K\Mud weight=9.4 ppg.1 Slack-off friction factor 1.09 @ 9886'. 18:00 00:00 600 24.00 DRILL G 4 P P/U 9 5/8"csg.(40#/L-80/Hydril 563/Special drift 8.75")Floating\RIH rotating 1/9884'-1/12,008165 rpm @ 6.9 torque- Rot wt.=45K\11,000'increased to 75 rpm @ 7.9K torque-Rot wt=49K static\11,625'increase slack-off weight to 36K while RIH\Speed @ 2.5-5 miijt.\Make-up 13.4K\Mud weight=9.4 ppg.\Total 118 bbls.lose.\Slack-off friction factor 1.66 @ 12,008'. j Daily Contacts v/ Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Drig.Spvr. Jack.Keener@enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. David Smith Eni Petroleum Drig.Spvr. 907-685-1277 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. 'Mirko Musumeci Eni Petroleum Dug Spvr. 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 -5.8 13,195.0 6/30/2011 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) 'Eq.Mud Weight(Ib/gal) 'Leak Off Pressure(psi) 2,3254 2,158.58 LSND Mud 9.20 246.0 11.39 1,277.6 • Vos Eni E&P Division 'Well Name:OP09-S i I ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ • e n Date:7/112011 - Report#: 21 API/UWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) I Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore 'Job Phase I Spud Date Target Depth(ftKB) Target Depth(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P09-51 DRILLING 1 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 19.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 13,220.0 3,929.6 0.00 89.0 43.4 Mostly Cloudy,WC 97°E @ 8.2 mph 38.1° Daily summary operation 24h Summary Continue RIH 9 5/8"csg.40#/L-80/Hydril 563 to shoe depth 13195'-R/D Tesco casing equipment-P/U cement head-Fill 9 5/8"csg-Circulate&condition mud-9 5/8"Csg Cement Job Operation at 07.00 N/U BOP Stack 24h Forecast Complete cement job-Injection test-P/U BOP stack-Well head job-L/D BOP stack-Freeze protect 13 3/8"x 9 5/8"csg w/diesel-Change upper rams to Variable 4 1/2"x 7"-L/D DPS with bad hard band-Install WEI ECD sub Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(Er) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00 DRILL G 4 P P/U 9 5/8"csg.(40#/L-80/Hydril 563/Special drift 8.75")Floating-RIH rotating f/12008'013151'(75 rpm @-9.2k torque -Rot wt=45k-slack off min HKLD 27k while RIH Speed @ 3/5 min/jt-Make-up 13.4k-Mud weight=9.4 ppg 04:00 05:00 1.00 5.00 DRILL G 2 P R/D Tesco casing/drilling tool from top drive and equipment and remove from rig floor-C/O 350 ton air slip and land casing using rotary slip-P/U 350 ton spider elevator and latch onto casing 05:00 05:30 0.50 5.50 DRILL H 5 P M/U new fill up casing tool-The tool don't work,connections are too close to M/U hammer Union-R/D new fill up tool and M/U cement head to fill&bleed operation on 9 5/8"csg with 9.3+ppg mud(Check to confirm no plug inside cement head) 05:30 15:00 9.50 15.00 DRILL H 7 P Fill&bleed 9 5/8"csg.with 9.3+ppg mud-Pumped 500 bbl and shut down f/15 min-Pumped 250 bbl and shut down 015 min-Filled with 245 bbl-Fluid static at surface(Tot pumped 995 bbl) 15:00 20:30 5.50 20.50 DRILL G 7 P Load cement head with two plugs(witness by ENI&Schlumberger rep)-Switch lines to Schlumberger cement head- Break circulation @ 1/2 bpm @ 190 psi and stage rate up every 15 min to 8 bpm @ 780 psi-Circulate x2 BU to condition er mud for cement job(0=6 bpm @ 500 psi) C/A4. 20:30 21:00 0.50 21.00 DRILL H 20 P Held PJSM with Schlumberger for cement job / c. 21:00 0000 3.00 24.00 DRILL H 9 P SLB pump 5 bbl Mud Push II and test lines to 3700 psi OK-SLB pump 65 bbl Mud Push II @ 10.5 ppg(0=5 bpm @ 440 1 ' psi)-Drop Bottom Plug-SLB mix and pump 356 bbl Slurry @ 12.5 ppg[LiteCRETE 1298 sacks,1.54 Yield,mix fluid 5.185 gal/sk](Q=3->5.8 bpm @ 550->350 psi)-Drop Top Plug-SLB pump 10 bbl H2O-Switch to Rig Pump and Displace with 607 bbl @ 9.3+ppg mud(0=8 bbl/min©350->490 psi)-Displacement ongoing Daily Contacts Position _ Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum "Sr.Ddg.Spvr. Jack.Keener@enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1277 907-903-7269 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 -5.8 13,195.0 6/30/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ibigal) I Leak Off Pressure(psi) 2,325.4 2,158.58 LSND Mud 9.20 246.0 11.39 1,277.6 lifillilli*' Eni E&P Division 1 Well Name:OP09-S i ENI Petroleum Co.Inc. Daily Report well Code:25601 Field Name:NIKATCHUQ 2 Date:7/2/2011 - Report#: 22 APIIUWI:50-029-23448-00-00 " II page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL 1 Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore IJob Phase Spud Date Target Depth(ftKB) Target Depth(TVD..J Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) 0P09-S1 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 20.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 13,220.0 3,929.6 0.00 87.0 38.5 Clear,WC 29.3° 70°ENE @ 16.5 mph Daily summary operation 24h Summary Complete cement job-Injectivity test-P/U BOP stack-Well head job(installed 9 5/8"emergency slip and pack oft)-Set BOP stack-Freeze protect 13 3/8"x 9 5/8"csg w/diesel-Change upper rams to 4 1/2"x 7"Variable-L/D DPS with bad hard band-Install WEI ECD sub Operation at 07.00 BOP Test 24h Forecast Complete UD DP with bad hard band and Install WEI ECD sub-Test BOP to AOGCC requirements-Replace DP discarded -P/U BHA#7-RIH w/4 1/2"joints Lithology Shows I MAASP Pressure(psi) Mud Weight(113/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL H 9 P Complete displacement with 381 bbl 9.3+ppg mud(Q=8->3 bbl/min @ 490-0940 psi)-[Total pumped for displace 988 bbl, Total loss during job 23 bbl,Bump plug OK,Cement in place 01:001- Pressure casing to 1410 psi(500 psi over FCP)hold 2 min and bleed off-Check float equipment OK 01:00 01:30 0.50 1.50 DRILL H 9 P WOC-Close Bag preventer and perform 20 bbl injectivity test with mud 9.3+ppg(2 bpm @ 560 psi) 01:30 03:00 1.50 3.00 DRILL H 2 P WOC-R/D Schlumberger cement head-Displace 9 5/8"csg down to the well head-Prep to P/U BOP 03:00 07:00 4.00' 7.00 DRILL C 1 P WOC-R/D Ketch Kan assembly-L/D mouse hole-Slide flow line back-Remove kill line-R/U BOP Handling Cylinders and Safety Slings-Clean active and raw mud pits 07:00 14:00 700 14.00 DRILL C 5 P Held PJSM-Raise BOP stack with Multi bowl&install Safety Slings-Installed 9 5/8"csg emergency slips(98k lbs transferred)-Cut 9 5/8"cso-UD landino inint with c tagt,Remove long Wear Bushing-Install 9 5/8"csg pack-off-Install short Wear Bushing-Set BOP stack with Multi bowl and test pack off to 2500 psi f/10 min OK-N/U BOP equipment(install Kill lines,flow line,fill-up&bleeder lines,Katch Kan) 14:00 15:00 1.00 15.00 DRILL C 9 P 'Little Red freeze protected 95/8"x 13 3/8"annulus with diesel 130 bbl(Q=1 bpm @ 375-'1040 psi,SICP 940 psi) 15:00 16:00 1.00 16.00 DRILL 'C 5 P Change out upper rams from 9 5/8"to 4 1/2"x 7"variables-Clean active pits. 16:00 21:00 5.00 21.00 DRILL E 4 P 'RIH w/5"DP 08784' 21:00 00:00 3.00 24.00 DRILL 'E 5 P 'POOH f/9500'-06966'installing WEI ECD Subs-UD 21 DP joints with bad hard band Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.DrIg.Spvr. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Mirko Musumeci Eni Petroleum DrIg Spvr. 907-685-1277 907-903-7269 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 - 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) Run Date CASING 95/8 8.835 L80 -5.8 13,195.0 6/30/2011 Last Leakoff Test Depth(ftKB) ND(RKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 2,325.4 2,158.58 LSND Mud 9.20 246.0 11.39 1,277.6 Vriiii. Eni E&P Division 'Well Name:OP09-S r ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ n• e n N Date:7/3/2011 - Report#: 23 APIIUWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) I Water Depth(ft) I RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.40 12.20 0.00 1627 21.87 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase 'Spud Date Target Depth(RKB) Target Depth(TVD..J Depth Dr.(MD)(ft) 'Drilling Hours(Br) Avg ROP(ft/hr) I DFS(days) 0P09-51 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116 9 21.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 13,220.0 3,929.6 0.00 87.0 34.5 Cloudy,Light Rain, 11°N @ 11.5 mph WC 27.1° _ Daily summary operation 24h Summary L/D DP with bad hard band and Install WEI ECD sub-Test BOP to AOGCC requirements-Top dove service Operation at 07.00 M/U BHA#7 24h Forecast Complete UD DP with bad hard band and Install WEI ECD sub-M/U and RIH at float equipment BHA#7 with 8 3/4"Bit-Displace WBM with OBM Lithology Shows MAASP Pressure(psi) I Mud Weight(1b/gall 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL 'E -4 P POOH(/8784'-t/Surface installing WEI E-CD Subs(92 Std with ECD Sub Total)-UD 4 DP Jt(25 Total)with bad hard band 06:00 '07:00 1.00 7.00 DRILL C 5 P Pull wear bushing and install test plug and 4 1/2"test joint-Fill BOP stack and choke manifold with water and purge out air. 07:00 '13:00 6.00 13.00 DRILL 'C 12 P Test BOP to AOGCC requirements=Annular @ 250-02500 psi-Rams,choke manifold,floor and top drive valves @ 250- p3 e f .,>3500 psi-Chart record-BOP test witness by AOGCC rep.Chuck Scheive (Q TEST FAILED on 4 1/2"x 7"Variable Rams and IBOP I I t( 13:00 17:00 4.00 17.00 DRILL C 5 TRO5 Replace 4 1/2"x 7"Variable rams and IBOP seal pack with new once 17:00 '18:00 1.00 18.00 DRILL C 12 TRO5 'Function and pressure test IBOP and 4 1/2"x 7"Variable rams @ 250-03500 psi 18:00 '18:30 0.50 18.50 DRILL C 5 P R/D test equipment-pull test plug&install wear bushing(Vetco Gray)-Blow down choke manifold. 18:30 '22:00 3.50 22.00 DRILL 'E 25 TRO4 TDS services-cleared torque transmission system due to a discovery of metal scale-Checked filter and changed oil due to a discovery of metal scale-Checked bearing and gear-wheel dimensional tolerance of the torque transmission system after observance of excessive noise. 22:00 '00:00 2.00 24.00 DRILL E '5 TRO4 Changed wash pipe due to leak,operation extended due to a difficulty to remove the failed component Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener 'Eni Petroleum Sr.Drlg.Spvr. Jack.Keener@enipetroleum.com '907-685-1277 '907-715-6434 Drilling Supt. Mirko Musumeci Eni Petroleum Dug Spvr. 907-685-1277 907-903-7269 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 -5.8 13,195.0 6/30/2011 Last Leakoff Test Depth OMB) ND(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) I Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,325.4 2,158.58 LSND Mud 9.20 246.0 11.39 1,277.6 is* Eni E&P Division 'Well Name:OP09-S i I ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO • API/UWI:50-029-23448-00-00 2^ Date:714/2011 - Report#: 24 II 'i page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° I Operator ENI Share(%) 'Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.40 12.20 000 16.27 21.87 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(TVD..JDepth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P09-51 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 22.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 13,2200 3,929.6 0.00 89.0 37.9 Cloudy,Rain,WC 77°ENE @ 6.8 mph 32.7° Daily summary operation 24h Summary Complete L/D DP with bad hard band and Install WEI ECD sub-M/U and RIH 115700'BHA#7 with 8 3/4"Bit Operation at 07.00 Displace WBM With OBM 24h Forecast Pressure test 9 5/8"Csg-Displace WBM with OBM-Pressure test WEI manifold-Drill out float equipment and 20'of new formation-Formation Integrity Test-Drill 8 3/4"Section Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50' 2.50 DRILL E 5 TRO3 Trouble shoot SCR,install circuit board with the power off-Fix rotary table lock 02:30 '09:00 6.50' 9.00'DRILL E 5 P RIH w/5"DP-UD 37 DP Jt with bad hard band[58 Jt Total]-P/U 5 DP Jt to replace discarded 09:00 "10:30 1.50— 10.50-DRILL E 5 P POOH installing 8 E-CD Subs[Total 100 Std w/ECD Valves,35 Std without valves] 10:30 -15:30 5.00' 15.50-DRILL E 5 P Held PJSM-P/U and M/U BHA#7[Bit 8 3/4"RSR616M-D1(s/n E144067)+Xceed675+Periscope 675+Telescope 675 +L W D-ADN6+NM Stab+x3 NM Flex DC+Float Sub+6"Jar+x2 5"HWDP+XO and RIH Picking up DP 4 1/2"(16.6#, NC46,2.867"OD Drift)11588' 15:30 "17:30 2.00' 17.50-DRILL E 4 TR99 Trouble shoot,Repair electrical cable on pick up machine 17:30 00:00 6.50 2400 DRILL E 4 P Fill string and shallow test-Continue RIH picking up 4 1/2"DP(16.68,NC46,2.867"OD Drift)f/588'115710 filling pipe every 45 Jts VI Daily Contacts Position Contact Name Company _ Dig. E-mail _ Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr. g.Spvr. Jack.Keener@enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Mirko Musumeci Eni Petroleum DrIg Spvr. 907-685-1277 907-903-7269 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 -5.8 13,195.0 6/30/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) 'Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) 'Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 9.40 733.0 12.99 2,651.9 Tio1 Eni E&P Division !Well Name:OP09-S i 1 EN!Petroleum Co.Inc. Daily Repo/.,t Well Code:25601 Field Name:NIKATCHUO e n Q•u Date:7/5/2011 - Report#: 25 API/UWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° 'Operator ENI Share(%) 'Well Configuration type 211-058 ENI PETROLEUM _ 100.00 HORIZONTAL Rotary Table Elevation(ft) (Ground Level(ft) Water Depth(ft) 'RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.4011 12.20 0.00 1627 21.87 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(TVD..I Depth Dr.(MD)(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) DFS(days) 0P09-61 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 1169 23.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(fUhr) POB Temperature(°F) Weather Wind 13,240.0 3,929.7 20.00 0.15 133.3 89.0 40.3 Clear,WC 33.6° 71°ENE @ 10.7 mph Daily summary operation 24h Summary Pressure test 9 5/8"Csg-Displace WBM with OBM-Pressure test WEI manifold-Drill out float equipment and 20'of new formation-Drill 20'8 3/4"Section Operation at 07.00 Drill 8 3/4"Section 24h Forecast Formation integrity test-Drill 8 3/4"Section Lithology Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr.• 00:00 05:00 5.00 5.00 DRILL -E 4 P RIH picking up 4 1/2"DP(16.68,NC46,2.867.00 Drift)t/5710'59615'filling pipe every 45 Jts 05:00 08:00 3.00 8.00 DRILL 'E 4 P Continue RIH w/5"DP f/9615'513097'(Top float collar)filling pipe every 2000' 08:00 09:00 1.00 9.00 DRILL -G 7 P Circulate BU for 9 5/8"Csg pressure test reciprocating&rotating sting(0=550 gpm,55 rpm,2200 psi,9k torque) 09:00 10:00 1.00 10.00 DRILL G 19 P Pressure test 9 5/8"csg @ 3000 psi for 30 min(chart record)-Pumped 10.6 bbl,bleed back 9.8 bbl y/ 10:00 13:00 3.00 13.00 DRILL E 7 P Displace well from LSND to FazePro 9.4 ppg OBM(0=10 bpm,2300 psi)-Reciprocate and rotate 50 rpm @ 8/9k torque, Up wt=150k,Dn wt=75k,Rot wt=105k 13:00 14:30 1.50 14.50 DRILL E 20 P 'Slip and Cut 140'drilling line-TDS service-Clean Shakers and pits 14:30 15:00 0.50 1600 DRILL E 12 P Test WEI manifold system @ 4500 psi(charted record) 15:00 16:00 1.00 1600 DRILL E 20 P Calibrate block height-Record PWD baseline with K&M for model-PL @ 13062'35/45 spm->#1 300/380 psi,#3 300/380 psi 16:00 22:00 6.00 22.00 DRILL E 14 'P Drill out float equipment&clean out(/13097'513220'(0=450 gpm @ 2460 psi,53 rpm @ 8/9 torque,WOB=3/4k Ibs,Up wt=165,Dn wt=587k,Rot wt=112k,MW=9.4 ppg.ECD=10.7 ppg) 22:00 22:30 0.50 22.50 DRILL E 3 P Drill rotary steerable 20'new hole f/13220'013240'(3931 TVD)(0=500 gpm @ 2900 psi,58 rpm @ 10k torque,W08= 5/6k Ibs,Up wt=165,Dn wt=70k,Rot wt=110k,MW=9.4 ppg,ECD=10.7 ppg) ADT=0.15 hrs Jars=0.15 hrs 22:30 00:00 1.50 24.00 DRILL E 7 'P 'POOH into shoe-Circulate BU Reciprocate and rotate 60 rpm @ 8.8k torque-Pump rate 500 gpm @ 3000 psi Daily Contacts -Position • Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.DrIg.Spvr. Jack.Keener@enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Mirko Musumeci Eni Petroleum Dog Spvr. 907-685-1277 907-903-7269 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 6835 L80 -58 13,195.0 6/30/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) 'Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 9.40 733.0 12.99 2,651.9 cat* Eni E&P Division (Well Name:OP09-S i I EN!Petroleum Co.Inc. Daily Report t Well Code:25601 Field Name:NIKATCHUO •enn Date:7/6/2011 - Report#: 26 APIIUWI:50-029-23448-00-00 " II II page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) !Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 1220 0.00 16.27 21.87 Rig Information Contractor !Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..lDepth Dr.(MD)(ft) !Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P09-S1 DRILLING 6/13/2011 22,371.0 3,826.0 22,310.001 190.91 116.9 24.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(f/hr) POB Temperature(°F) Weather Wind 15,540.0 3,918.3 2,300.00 13.01 176.8 89.0 44.2 Clear,WC 37.6° 76°ENE @ 14.8 mph Daily summary operation 24h Summary Formation integrity test(EMW=13 ppg)-Drill 8 3/4"Section(/13240'to/15540' Operation at 07.00 Drill 8 3/4"Section 24h Forecast Drill 8 3/4"Section to proposed TD 22371'-Drift and strap 5 1/2"Liner and 4 1/2"Tbg Lithology Shows MAASP Pressure(psi) !Mud Weight(Ib/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL E 11 P 'Rig up lines,Fluid pack and perform FIT with 9.4 ppg FazePro OBM-Surface pressure of 733 psi-EMW=13 ppg 01:00 06:00 5.00 6.00 DRILL E 3 P 'Drill rotary steerable 8 3/4"section 613240'V13395'(0=550 gpm @ ON=3300 OFF=3280 psi,80 rpm @ OFF=9k ON=10/15k torque,WOB=12/20k Ibs,MW=9.4 ppg,ECD=10.85 ppg) • 06:00 12:00 6.00 12.00'DRILL E 3 P Drill rotary steerable 8 3/4"section(/13395'014195'(0=550 gpm©ON=3350 OFF=3300 psi,120 rpm @ OFF=9/10k ON=11/15k torque,WOB=6/15k Ibs,MW=9.4 ppg,ECD=11.35 ppg) 12:00 18:00 6.00 18.00 DRILL E 3 P Drill rotary steerable 8 3/4"section(/14195'014900'(0=555 gpm©ON=3720 OFF=3690 psi,120 rpm @ OFF=10/11 k ON=14/15k torque,WOB=6/8k Ibs,MW=9.4 ppg,ECD=11.2 ppg) 18:00 00:00 6.00 24.00 DRILL E 3 P Drill rotary steerable 8 3/4"section(/14900'V15540'(0=555 gpm @ ON=3740 OFF=3700 psi,120 rpm @ OFF=12/13k ON=14/18k torque,WOB=5/8k Ibs,MW=9.4 ppg,ECD=11.36 ppg) ADT=13.16 hrs-JAR=13.16 hrs Daily Contacts . Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Dog.Spvr. Jack.Keener@enipetroleum.com 907-685-1277 907-7158434 Drilling Supt. Mirko Musumeci Eni Petroleum Drig Spvr. 907-685-1277 907-903-7269 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 -5.8 13,195.0 6/30/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) !Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 9.40 733.0 12.99 2,651.9 Eni E&P Division 'Well Name:OP09-8 ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ •p e n N Date:7/7/2011 - Report#: 27 APIIUWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share)%) 'Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 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)TVD..J Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP09-51 DRILLING Il 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 25.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 18,575.0 3,925.4 3,135.00 18.07 173.5 90.0 38.1 Overcast,Fog,WC 70°ENE @ 21.6 27.3° mph Daily summary operation 24h Summary Drill 8 3/4"Section f/15540'to/18000' Operation at 07.00 Drill 8 3/4"Section 24h Forecast Drill 8 3/4"Section to proposed TD 22371'-Drift and strap 5.5"Liner Lithology 'Shows !MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P 'Dell rotary steerable 83/4"section(/15540'616208'(0=550 gpm @ ON=3720 OFF=3690 psi,80/120 rpm @ OFF=15/16k ON=17/20k torque,WOB=8/15k Ibs,MW=9.4 ppg,ECD=11.5 ppg) 06:00 12:00 6.00 12.00 DRILL E 3 P Drill rotary steerable 8 3/4"section f/16208'016850'(0=550 gpm @ ON=3850 OFF=3790 psi,120 rpm @ OFF=14/16k ON=16/19k torque,WOB=4/15k Ibs,MW=9.4 ppg,ECD=11.66 ppg) 12:00 18:00 6.00' 18.00 DRILL E 3 'P Drill rotary steerable 8 3/4"section f/16850'017293'(0=555 gpm @ ON=3930 OFF=3920 psi,120 rpm @ OFF=15/16k ON=16/17k torque,WOB=5/7k Ibs,MW=9.4 ppg,ECD=11.6 ppg) 18:00 00:00 6.00 24.00 DRILL E 3 P Drill rotary steerable 8 3/4"section(/17293'018000'(0=555 gpm @ ON=4000 OFF=3995 psi,120 rpm @ OFF=16/17k ON=18/19k torque,WOB=7/10k Ibs,MW=9.4 ppg,ECD=11.85 ppg) Daily ADT=13.77 hrs [ADT=26.93-JAR=26.93 Firs] Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener Eni Petroleum Sr.DrIg.Spvr. 'Jack.Keener @enipetroleum.corn 907-685-1277 907-715-6434 Eni representative Mirko Musumeci Eni Petroleum Ng Spvr. 907-685-1277 907-903-7269 Vr Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING - -9 5/8 8.835 L80 . -5.8 13,195.0 6/30/2011 Last Leakoff Test Depth(ftKB) r°(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) 'Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 9.40 733.0 12.99 2,651.9 Ifiiiis Eni E&P Division `Well Name:OP09-S'i 1 ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO • en! Date:7/812011 - Report#: 28 APIIUWI:50-029-23448-00-00 page 1 of 1 Welibore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) !Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor I Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(RKB) Target Depth(TVD...I Depth Dr.(MD)(ft) I Drilling Hours(hr) 'Avg ROP(ft/hr) DFS(days) 0P09-S1 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 26.00 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 19,848.0 3,877.0 1,273.00 12.61 101.0 88.0 34.0 Cloudy,Fog,WC 40°NE @ 8.5 mph 26.6° Daily summary operation 24h Summary Drill 8 3/4"Section f/18,000'619,848'MD reaming 30'up/dwn,recording dry ROT/TO every three stds. Adjusted drilling parameters for encountered hard spots @ 1/18320 t/18330 and 618749 618759. Operation at 07.00 Drill 8 3/4"Section 24h Forecast Drill 8 3/4"Section to proposed TD 22371'-Drift and strap 5.5"Liner Lfthology Shows I MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 '06:00 6.00 6.00 DRILL E '3 P Drill rotary steerable 8 3/4"section 618000'018560'(0=550 gpm @ ON=4050 psi OFF=3950 psi,80/120 rpm @ OFF=16k ON=17/19.5k torque,WOB=10/15k lbs,MW=9.4 ppg,ECD=11.6 ppg) 06:00 '12:00 6.00 12.00 DRILL E -3 P Drill rotary steerable 83/4'Section 1/18560'619061'(0=550 gpm @ ON=4080 psi OFF=3970 psi,80/120 rpm @ OFF=16/17k ON=17/20k torque,WOB=8/15k lbs.MW=9.4 ppg,ECD=11.7 ppg). SPR @ 18860'(3932'TVD)Mud Pump #1 25/425 psi-35/525 psi&Mud Pump#3 25/420 psi-35/520 psi. 12:00 '18:00 6.00 18.00 DRILL E '3 P Drill rotary steerable 83/4"section 1/19061'019399'(0=550 gpm @ ON=4065,80/120 rpm @ ON=20/22k,WOB=8/10k lbs,MW=9.4 ppg,ECD=11.84 ppg) 18:00 00:00 6.00 24.00 DRILL E 3 P Drill rotary steerable 8 3/4"section 1/19399'019848'(0=550 gpm @ ON=4110,120 rpm @ ON=17/19k torque,WOB= 8/10k lbs,MW=9.4 ppg.ECD=12.07 ppg) Daily ADT=15.08 hrs [ADT=42.01-JAR=42.01 hrsj Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener Eni Petroleum Sr.Dig.Spvr. Jack.Keener@enipetroleum.com '907-685-1277 907-715-6434 Eni representative Angelo Lamaina Eni Petroleum Drig Spvr. 907-685-1277 907-903-7269 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 -5.8 13,195.0 6/30/2011 Last Leakoff Test Depth(RKB) I TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) 'Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 9.40 733.0 1299 2.6510 Eni E&P Division I Well Name:OP09-S i I ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO eno Date:7/912011 - Report#: 29 API/UWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) 'Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) !Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) !Target Depth(TVD..J Depth Dr.(MD)(ft) [Drilling Hours(hr) 'Avg ROP(ft/hr) DFS(days) 0P09-S1 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.001 190.91 116.9 27.00 • Daily Information End Depth(RKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21,084.0 3,876.1 1,236.00 11.43 108.1 90.0 38.7 Cloudy,Fog,WC 85°E @ 9 mph 31.3° Daily summary operation 24h Summary Drill 8 3/4"Section 1/19,848'1121,084'MD reaming 30'up/dwn,recording dry ROT/TO every three stds. Operation at 07.00 Drill 8 3/4"Section. 24h Forecast Drill 8 3/4"Section to proposed TD 22371'-Circulate Bottoms-Up. Lithology Shows MAASP Pressure(psi) 'Mud Weight(Ib/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(Er) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill rotary steerable 83/4"section(/19848 020330'(0=538 gpm @ ON=4175 psi OFF=4100 psi,80/120 rpm @ OFF=17- 18k ON=19/20k torque,WOB=5/10k lbs,MW=9.4 ppg,ECD=12.1 ppg). Cycling pumps for MWD survey several times per connection. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill rotary steerable 8 3/4"section f/20330'020536'(0=530 gpm @ ON=4180 psi OFF=4100 psi,80/120 rpm @ OFF=17k ON=19k torque,WOB=10/15k Ibs,MW=9.4 ppg,ECD=12.1 ppg).Hardspot 1/20,467'920,488'. 12:00 1800 6.00 18.00 DRILL E 3 P Drill rotary steerable 8 3/4"section 1/20536'1120732'(0=524 gpm @ 4020 psi,80/120 rpm @ OFF=18k ON=18/20k torque, WOB=4/10k Ibs,MW=9.4 ppg,ECD=11.97 ppg).SPR @ 20,634'(3896'TVD)Pump#2 25/470 psi 35/580 psi-Pump#3 25/480 psi 35/585 psi. 1800 00:00 6.00 24.00 DRILL E 3 P Drill rotary steerable 8 3/4"section U20732'1/21084'(Q=528 gpm @ 4060 psi,80/120 rpm @ OFF=18k ON=19/20k torque, WOB=2/13k Ibs,MW=9.4 ppg,ECD=12.08 ppg).Controlled ROP @ maximum 150 ft/hr for better data acquisition. Daily ADT=9.93 hrs [ADT=52.13-JAR=52.13 hrs] V Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum Sr.Dig.Spvr. 907-685-1227 337-277-1809 Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. 907-685-1277 907-903-7269 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 I Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 -5.8 13,195.0 6/30/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) 'Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 9.40 733.0 12.99 2,651.9 • • Eni E&P Division a I Well Name:OP09-S i 1 EN/Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ ■ • APIIUWI:50-029-23448-00-00 2�, Date:7/10/2011 - Report#: 30 il �I I) page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) !Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 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(TVD..]Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) 0P09-51 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 28.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 22,370.0 3,784.0 1,286.00 12.90 99.7 91.0 37.9 Cloudy,Fog,WC 63°ENE @ 9.8 mph 31.3° Daily summary operation 24h Summary Drill 8 3/4"Section f/21,084'622,370'TD reaming 30'up/dwn,recording dry ROT/TO every three stds. Operation at 07.00 Circulate B/Up. 24h Forecast Circulate 110 B/Up-BROOH. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(Er) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill rotary steerable 8 3/4"section(/21084'621365'(0=525 gpm,pressure ON=4195 psi OFF=4100 psi,80/120 rpm, OFF=18k ON=19/20.5k torque,WOB=8/20k lbs.MW=9.4 ppg,ECD=12.0 ppg).Encountered several hard spots. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill rotary steerable 8 3/4"section(/21365'621650'(Q=517 gpm,pressure ON=4190 psi OFF=4100 psi,80/120 rpm at OFF=20k ON=21k torque,WOB=5/20k Ibs,MW=9.4 ppg,ECD=12.0 ppg).Encountered several hard spots.SPR at 21,500'(3,860TVD)Mud Pump#1 25/475 psi 35/600 psi-Mud Pump#2 25/485 psi 35/610 psi. ,-c___'(J 12:00 23:00 11.00 23.00 DRILL E 3 P Drill rotary steerable 8 3/4"section(/2165021022370'TD(3781'TVD)(Q=500 gpm,pressure 4120 psi,80/120 rpm, OFF=20k ON=21k torque,WOB=2/15k Ibs,MW=9.4 ppg,ECD=12.32 ppg).Take on bottom survey @ TD.SPR at 22,307'Mud Pump#1 25/480 psi 35/590 psi-Mud Pump#3 25/490 psi 35/600 psi. IAf ' Daily ADT=12.9 hrs [ADT=66.53-JAR=66.53 hrs] ■ 23:00 00:00 1.00 24.00 DRILL E 7 'P Circulate B/U while reaming stand @ 120 rpm-500 gpm-4100 psi. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum Sr.DrIg.Spur. 907-685-1227 337-277-1809 Eni representative Angelo Lamanna Eni Petroleum Drlg Spur. 907-685-1277 907-903-7269 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 -5.8 13,195.0 6/30/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) 'Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 9.40 733.0 12.99 2,651.9 • 16.74% Eni E&P Division 4 Nell Name:OP09-S, I ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO• e rn o• Date:7/1112011 - Report#: 31 API/UWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header PermiUConcession N° Operator ENI Share(%) I Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor IRig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase 'Spud Date !Target Depth(RKB) Target Depth(TVD..J Depth Dr.(MD)(ft) !Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) OP09-S1 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 29.00 Daily Information End Depth(RKB) End Depth(ND)(f..Depth Progress(ft) Drilling Hours(hr) Avg ROP(fUhr) POB Temperature(°F) Weather Wind 22,370.0 3,784.0 0.00 91.0 48.0 Cloudy,Fog,Rain, 67°ENE @ 22.3 WC 33.8° mph Daily summary operation 24h Summary Circulate 11x B/Up-BROOH f/22,370'019,258'. Operation at 07.00 BROOH. 24h Forecast BROOH to 9 5/8"csg shoe-circulate bottoms-up. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 10:00 10.00' 10.00'DRILL E '7 P Circulate 6x bottoms-up reciprocating&rotating pipes.Pump rate 505 gpm,SPP=4140 psi,120 rpm,19K torque 105K, ECD=12.1 ppg.Rack back one stand every bottom-up f/22,370'0 21,820',using WEI-CD sub for connection. 10:00 19:30 9.50 19.50 DRILL E 7 P Circulate 5x bottoms-up reciprocating&rotating pipes.Pump rate 525 gpm,SPP=4050 psi,120 rpm,18K torque,ECD= 11.8 ppg.Rack back two stands every bottom-up f/21,820'0 20,732',using WEI-CD sub for connection. 19:30 '00:00 4.50 24.00 DRILL E 6 P BROOH(/20,732'019,258'(5-10 min/std).Pump rate 535 gpm,SPP=4015 psi,120 rpm,16-17K torque,ECD=11.6 ppg, using WEI-CD sub for continuos circulation. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Frank Cormier Eni Petroleum Sr.Drig.Spvr. 907-685-1227 337-277-1809 Eni representative Angelo Lamarina Eni Petroleum Dug Spvr. 907-685-1277 907-903-7269 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dulling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 0835 L80 -5.8 13,195.0 6/30/2011 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) !Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 9.40 733.0 12.991 2,651.9 Iiiiiii Eni E&P Division i I Well Name:OP09-Si ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO � j•p e n N Date:7112/2011 - Report#: 32 APIIUWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) [Ground Level(ft) [Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore [Job Phase 'Spud Date Target Depth(ftKB) [Target Depth(TVD...I Depth Dr.(MD)(ft) !Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P09-S1 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 30.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 22,370.0 3.784.0 0.00 90.0 40.6 Cloudy,Fog,Rain, 69°ENE @ 17.1 WC 31.8° mph Daily summary operation 24h Summary BROOH to 9 5/8"csg shoe and continue back reaming to 12,390'. Operation at 07.00 Circulate B/Up. 24h Forecast BROOH to 10,000'-circulate B/U-Pump slug and POOH on elevator-L/D BHA#7-R/U GBR-P/U,M/U 8 RIH 0 5 1/2"liner. Lithology [Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.DesCr. 00:00 09:00 9.00 9.00 DRILL E 6 P -BROOH(/19,258'1116,370'(5-10 min/std).Pump rate 550 gpm,SPP=4100 psi,120 rpm,15-18K torque,ECD=11.4 ppg, using WEI-CD sub for continuous circulation.No tightspots encountered. 0900 13:30 4.50 13.50 DRILL E 25 TR99 Found stand pipe hammer union leaking.Bleed off pressure and R/U to circulate using cementing line. Circulate @ 300 gpm and 2450 psi while replacing gasket in hammer union(1002 union)in standpipe.Pressure test same to 3500 psi:ok,no leaks. 13:30 00:00 10.50 24.00 DRILL E 6 P Continue BROOH f116,370'1/12,390'(5-10 min/std),reduce speed and rpm when pulled into shoe. Pump rate 550 gpm,SPP=3175 psi,120 rpm,10-11K torque,ECD=10.8 ppg,using WEI-CD sub for continuous circulation.No tightspots encountered. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier 'Eni Petroleum Sr.Dig.Spur. 907-685-1227 337-277-1809 Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. •907-685-1277 907-903-7269 ✓ Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dolling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftK8) Run Date CASING 95/8 8.835 L80 -5.8 13,195.0 6/30/2011 Last Leakoff Test Depth(kKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) 'Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 9.40 733.0 12.99 2,651.9 • • I"" l Eni E&P Division (Well Name:OP09-S i ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO �.j •q e N II& Date:7/13/2011 - Report#: 33 API/UWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header PermitlConcession N° Operator ENI Share(%) I Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor 1 Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date !Target Depth(ftKB) Target Depth(TVD..JDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P09-S1 DRILLING 6/13/2011 22,371.0 3,826.01 22,310.00 190.91 116.9 31.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 22,370.0 3,784.0 0.00 93.0 40.5 Partly Cloudy,WC 71°ENE @ 13.5 32.5° mph Daily summary operation 24h Summary BROOH to 10,000'-circulate 2x B/U-POOH on elevator-L/D BHA#7-R/U GBR-P/U,M/U&RIH 0 5 1/2"slotted liner. Operation at 07.00 RIH 0 5 1/2"slotted liner. 24h Forecast RIH 0 5 1/2"slotted liner-Set ZXP packer/hanger and test.Displace well with Brine KCI @ 9.0 ppg.POOH and L/D drill pipe. Lhhology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.35 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:30 5.50 5.50 DRILL E 6 P 'Continue BROOH 1/12,390'1/10,000'(5 min/std).Pump rate 550 gpm,SPP=3000 psi,120 rpm,8-10K torque,ECD=10.6 PIN. 05:30 '07:00 1.50 7.00 DRILL E 7 P "Circulate 2x B/U and condition mud while reprocating and rotating pipe.Pump rate 550 gpm,SPP=2945 psi,120 rpm,6- 9K torque,ECD=10.5 ppg,shakers clean. 07:00 08:00 1.00 8.00'DRILL E 4 P Monitor hole 10 min:static.Pump slug,POOH on elevators nr.5 stands DP's 0 5",drop rabbit 0 23/8"and change handling equipment to 4 1/2". 08:00 '15:00 7.00 15.00 DRILL E 4 P POOH with 4 1/2"DP on elevators as per K&M indications:no swab,proper hole fill. 15:00 18:30 3.50 18.50 DRILL E 5 P Held PJSM with Schlumberger DD/MWD(radio active source).POOH and L/D BHA#7. Bit Dull:2-2-WT-T-X-I-CT-TD. 18:30 19:30 1.00" 19.50"DRILL E 1 P Clear rig floor of BHA handling equipmente.Prepare to run 5 1/2"liner. 19:30 '21:00 1.50 21.00'DRILL G '5 'P P/U GBR tongs and equipment to floor.R/U GBR equipment and torque turn for 5 1/2"liner.Held PJSM. 21:00 00:00 3.00 24.00'DRILL G 4 P P/U,M/U&RIH shoe+nr.37 joints 5 1/2"15.5#L-80 Hydrill 521 slotted liner(M/U torque 5500 ft'Ibs)+7 joints 5 1/2"17#L -80 Hydrill 521 slotted liner(M/U torque 6200 Bibs)to 1,832'.Up Wt 70K-Dw Wt 70K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Frank Cormier 'Eni Petroleum Sr.Drig.Spvr. 907-685-1227 337-277-1809 Eni representative Angelo Lamarina Eni Petroleum DrIg Spvr. 907-685-1277 907-903-7269 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Alvin Criswell Em Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dulling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Gas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 L80 12,988.4 21,740.0 7/14/2011 Last Leakoff Test Depth(RKB) r.(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 13,240.0 3,92971 FazePro 9.40 733.0 12.99 2,651.9 V* Eni E&P Division I Well Name:OP09-S i ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUQ � j•p e 11 N Date:7/14/2011 - Report#: 34 APIIUWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(R) IRKS-Base Flange(ft) I RKB-Tubing Spool(ft) 53.40 12.20 0.001 16.27 21.87 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(TVD...Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP09-51 I DRILLING 6/13/2011 22,371.0 3,826.0 22,310.00 190.91 116.9 32.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..I Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(R/hr) POB 'Temperature(°F) Weather Wind 22,370.0 3,784.0 0.00 94.01 40.5 Clear,WC 32.7° 82°E @ 14 mph Daily summary operation 24h Summary RIH 0 5 1/2"slotted liner. FINAL DRILLING REPORT. Operation at 07.00 POOH&L/D drill pipes. 24h Forecast Set ZXP packer/hanger and test.Displace well with Brine KCI @ 9.0 ppg.POOH and L/D drill pipe. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 11:00 11.00 1180 DRILL '0 4 P Continue P/U,M/U&RIH 5 1/2"178 L-80 Hydrill 521 slotted liner(M/U torque 6200 R'_Ibs)to 8,718'.Dw Wt=70K.Proper displacement. Total:205 joints slotted liner 5 1/2"+11x blank 5 1/2"+6x Oil swell packers. ✓ 11:00 12:30 1.50 12.50 DRILL 'G 5 P Change out elevators,P/U ZXP liner hanger/packer and M/U-mix fill tie-back sleeve with pal-mix,wait 30 minutes to set up.M/U first stand 4-1/2"DP,RIH-break circulate @ 3 bpm 80 psi.Up Wt=105K-Dw Wt=78K. 12:30 00:00 11.50 24.00 DRILL G 4 P RIH 5-1/2"slotted liner on 98x stands 4-1/2"DP+38x stands of 5"DP+1x joint 5"DP to 21,740'.Fill up pipe and record data every 10 stands.Rot Wt=115K @ 35 rpm TO=10-11K FINAL DRILLING REPORT Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum Sr.Drlg.Spur. 907-685-1227 337-277-1809 Eni representative Angelo Lamanna Eni Petroleum Drlg Spvr. 907-685-1277 907-903-7269 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(In) Grade Top(RKB) Bottom(RKB) Run Date LINER 51/2 L80 12,988.4 21,740.0 7/14/2011 Last Leakoff Test Depth(ftKB) TVD(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 13,240.0 3,92971 FazePro 9.40 733.0 12.99 2,651.9 Eni E&P Division {Well Name:OP09-S EN!Petroleum Co.Inc. Daily Report` Well Code:25601 Field Name:NIKATCHUQ � j•n e 11(1 Date:7/15/2011 - Report it: 1 API/UWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) I RK8-Tubing Spool(ft) 53.40 1220 0.00 16.27 21.87 Rig Information Contractor I Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase I Spud Date Target Depth(ftKB) Target Depth(TVD..I Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP09-S1 COMPLETION 7/15/2011 I 1.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 860 41.7 Partly Cloudy,WC 85°E @ 21.4 mph 32.7° Daily summary operation 24h Summary Put 5 1/2"production liner on depth @ 12,740'\Set SLZXP hanger/packer as per Baker Rep.liner.\Test backside to 1500 psi.f/10 mins.(chart recorded).\Release SLZXP liner/packer and pull to 12,893'.1 Displace well bore from 9.4 ppg OBM(FazePro)to 9.0 ppg KCL Brine.\Cut drilling line.\Circulate&condition 9.0 ppg KCL Brine to neutral 6+pH.\POOH with running tool UD 5"&4 1/2"drill pipe.\Inspect&made service breaks on liner running tool. Operation at 07.00 RIH with 5"DP and L/D WEI CD sub. 24h Forecast RIH with 5"drill pipe-L/D WEI CD sub.\POOH UD 5"drill pipe.\R/U Baker Centring equipment to run completion assembly. Lithology I Shows MAASP Pressure(psi) I Mud Weight(1b/gall 9.05 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 COMP K 19 P Pull 5 1/2"liner on depth @ 21,740'-Circulate 25 bbls.with pump rate of 186 gpm @ 620 psi.\Set SLZXP packer/hanger as per Baker Rep.\Drop ball-start pumping 210 gpm @ 650 psi.with 98 bbls away slowed rate to 126 gpm @ 410 psi. and 126 bbls.away reduce to 63 gpm @ 240 psi.-ball seated @ 148 bbls.Stage pump pressure up-setting pusher tool sheared @ 3500 psi.-continue to 4000 psi.&hold-bleed off pressure.Top of liner @ 12,988'.1 Pressure test annulus to Baker SLZXP packer top to 1500 psi.for 10 minutes on chart recorder,bleed off.\BOT released tons SLZXP liner/packer- P/U to 200K no release-S/O to 50K-P/U 210K no release-S/0 to 50K.Pressure up to 4000 psi.and P/U to 150K tool released,set back 1 stands to 12,893'. 02:30 06:00 3.50 6.00 COMP K 7 P Held PJSM-Displace well from 9.4 ppg OBM(FazePro)to 96 ppg KCL Brine-pumped 40 bbls.LVT pill-followed by 120 bbls(10 ppg)citric acid spacer pill and displace 1250 bbls 9.0 ppg KCL Brine until clean.Circulating 420 gpm @ 850 psi. reciprocating pipe-no rotation.Flushed mud pumps&lines. 0600 06:30 0.50 6.50 COMP K 20 P Clean drill floor and L/D handling tools-clean under shakers 06:30 08:30 2.00 8.50 COMP K 25 P Cut drilling line 125'-service/inspect draw-works.Reset crown saver&recalibrate blocks. 08:30 09:30 1.00 9.50 COMP K 7 P Circulate and condition 9.0 ppg.KCL Brine to 6+pH as per MI Swaco Rep.-pumping 420 gpm @ 450 psi. 09:30 13:30 4.00 13.50 COMP K 4 P Monitor well for 10 mins static.\POOH L/D 5"drill pipe t/12,893'-1/9,334'-inspect and culled total 51 joints. 13:30 23:00 9.50 23.00 COMP K 4 P L/D XO and change handling equipment from 5"to 4 1/2".POOH L/D 4 1/2"drill pipe f/9,334'-1/BOT liner running tool(total 294 joints). 23:00 00:00 1.00 24.00 COMP K 4 P BOT rep.inspected and made service breaks on liner running tool and L/D. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative -Frank Cornier Eni Petroleum Sr.DrIg.Spvr. 907-685-1227 337-277-1809 Eni representative Angelo Lamarina Eni Petroleum Dreg Spvr. 907-685-1277 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Eni representative David Smith Eni Petroleum DrIg.Spvr. 907-685-1277 907-632-3058 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 L80 12,988.4 21,7406 7/14/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 9.40 733.0 12.99 2,651.9 ifitii Eni E&P Division 'Well Name:OP09-S r I EN!Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO �j •n API/UWI:50-029-23448-00-00 II N Date:7/16/2011 - Report#: 2 - _ page 1 of 1 Wellbore name: OP09-S1 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) I Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor I Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore 'Job Phase Spud Date Target Depth(ftKB) 'Target Depth(TVD..J Depth Dr.(MD)(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) DFS(days) OP09-S1 COMPLETION 7/15/2011 I 2.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..I Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) I POB 'Temperature(°F) Weather Wind 0.0 88.0 43.7 Rain,WC 43.5° 67°ENE @ 2.2 mph Daily summary operation 24h Summary POOH-RIH with 5"drill pipe,surface-51446'-L/D WEI-CD subs.\Downtime:Iron rough neck down(change out hydraulic valve block on spinners)\RIH w/5"DP f/1446'-51818'&UD WEI-CD subs.) Downtime:Bridge crane in pipe shed fouled/damage-cut section cut&re-spool-function tested.)RIH w/5"DP f/1818'-59383'&L/D WEI-CD subs.\Circulate surface to surface to remove OBM residue in drill pipe&hole.)POOH-L/D 5"drill pipe f/9383'-Usurface.(Total of 294 its.&culled 143 jts.)\Pull wear bushing&install test plug with 4 1/2"test joint-fill stack&choke manifold. Operation at 07.00 Test BOP as per AOGCC requirements-Jeff Jones waived witness of test @ 0800 hrs.7/16/2011. 24h Forecast Test BOP with 4 1/2"tubular to AOGCC requirements(due 7-17-2011)-Jeff Jones waived witness of test.\R/U Centrilift and GBR equipment.\Hold PJSM-P/U Centrilift ESP components and service/assembly.)RIH with Centrilift ESP completion assembly-P/U 4 1/2"flog.\Off line activity:R/D CCB lines&unit. Lithology Shows MAASP Pressure(psi) 'Mud Weight(Iblgal) 9.05 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00:00 '01:00 1.00 1.00 COMP 'K 1 P Change out to 5"handling equipment.\Load floor with WEI-CD sub baskets and 4 1/2"IF thread protectors. 01:00 '02:30 1.50 2.50 COMP K 4 P RIH with 5"drill pipe with mule shoe 51446'-L/D WEI-CD sub from tops of stands.)Up wt.=70K-Dn wt.=60K. 02:30 03:30 1.00 3.50 COMP "K 25 XR99 Down Time:Iron rough neck-hydraulic valve block leaking on pipe spinners-change o-ring,but still leaked-change out complete valve block on same&function tested good. 03:30 04:00 0.50 4.00'COMP 'K 4 P Continue RIH with 5"drill pipe 1/1446'-51818'-UD WEI-CD subs from stands.)Up wt.=76K-Dn wt.=65K. 04:00 "06:30 2.50 6.50'COMP K 25 XR99 Down Time:Bridge crane in pipe shed used to transfer WEI-CD sub basket-cable fouled and damaged(flattened)-cut and remove damage section,re-spool line on drum and function tested. 06:30 '11:30 5.00 11.50 COMP K 4 P RIH with 5"drill pipe-1/1818'-59383'-UD WEI-CD subs from stands.\Up wt.=160K-Dn wt.=120K.\Called AOGCC @ 0755 hrs.for BOP test notice(due on 7-17-2011)-left a message-Jeff Jones returned call @ 0800 hrs and waived witness of test. 11:30 "13:00 1.50 13.00 COMP K 7 P Circulated surface to surface to remove OBM residue in dell pipe and annulus-pumping 535 gpm @ 700 psi. • 13:00 '22:30 9.50 22.50 COMP 'K 4 P POOH-L/D 5"drill pipe f/9383'-1/surface.(294 jts.)\Inspect&culled pipe(total 143 joints with worn hard band).• 22:30 00:00 1.50" 24.00'COMP K 5 P Drain stack-Pull wear bushing&install test plug with 4 1/2"test joint-fill stack&choke manifold. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier "Eni Petroleum Sr.Ddg.Spvr. 907-685-1227 337-277-1809 Eni representative Angelo Lamarina Eni Petroleum Dug Spvr. 907-685-1277 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Eni representative David Smith Eni Petroleum Drlg.Spvr. 907-685-1277 907-632-3058 Last Casing seat Cas.Type OD(In) ID(In) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 L80 12,988.4 21,740.0 7/14/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 9.40 733.0 12.99 2,651.9 • Vois Eni E&P Division 1 Well Name:OP09-S i EN/Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO �j e 11 n Date:7/17/2011 - Report#: 3 API/UWI:50-029-23448-00-00 N page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) [Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 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(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP OM* DFS(days) OP09-S1 COMPLETION 1 7/15/2011 3.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 85.0 41.7 Clear,WC 41.4° 285°WNW @ 1.8 mph Daily summary operation 24h Summary Test BOP with 4 1/2"tubular to AOGCC requirements-Jeff Jones waived witness of test.\R/U Centrilift and GBR equipment.\Hold PJSM-P/U Centrilift ESP components and service/assembly.\Gator splice MLE&ESP cable-perform electrical integrity test and gauge readings./RIH with Centring ESP completion assembly as per well plan-P/U 4 1/2"tbg.1/209'. Operation at 07.00 P/U 4 1/2"tbg.(12.68;L-80;IBTM;3.833"drift)RIH with ESP completion assembly. 24h Forecast RIH with ESP completion assembly and cable-P/U 4 1/2"tbg(12.6#;L-80;IBTM;3.833"drift)/Install Cannon single channel clamps as per well plan.Perform electrical integrity test and gauge reading every 1000'. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:30 4.50' 4.50 COMP K 12 P Test BOP to AOGCC requirements on 4 1/2"tubular./Annular @ 250 psi./2500 psi./Pipe&blind rams,mud cross valves, choke manifold,floor and top drive valves 250 psi./3500 psi.-Chart record all test for 5 mins./Hydraulic and Manual choke � valves tested to 1500 psi./Koomey draw down test(Recovery times:f/1750-t/1950 psi.(200 psi.)in 46 seconds with final @ 3000 psi in 183 seconds-6 Nitrogen bottles @ 2717 psi average)./Test Gas sensors.\Nabors&ENI reps.witness all Z. testing./Tested was waived by AOGCC Rep Jeff Jones @ 0800 hrs.on 7/16/2011. ' �)l/ 04:30 05:30 1.00 5.50 COMP 'K 5 P Pull test plug with Vetco Gray and LID same./Blow down equipment and lines. f f 05:30 10:30 5.00 10.50 COMP K 1 P Held PJSM-R/U Centrilift and GBR equipment./Load floor with Centring equipment&hang ESP cable&cap tube sheaves in derrick and pull lines through sheaves to dg floor. 10:30 12:00 1.50 12.00 COMP K 4 P P/U and M/U-TTC,XO tbg.intake,Joint#1 of 4 1/2"tbg.to set pump assembly. 12:00 13:00 1.00 13.00 COMP K 1 P R/U Halliburton slick-line sheaves&equipment to install pump assembly&pack-off. 13:00 15:00 2.00 1560 COMP K 19 P Set pump and tubing pack-off assembly with Halliburton on GS tool./Install pressure test tool and fill tbg.-test to 1000 psi for 15 mins./Retrieve test tool and install tbg.stop. 15:00 15:30 0.50 15.50 COMP K 1 P R/D Halliburton slick-line equipment and sheaves. 15:30 19:00 3.50 1960 COMP K 19 P P/U Centrilift ESP motor and tandem seal assembly-check free rotation and service/fill with oil to TTC intake./Install 1/4" cap tube to check valve @ centralizer and 1/4"TEC line to WellLift gauge./Attached MLE to pot head,test-RIH to discharge pressure sub installing(Christolizer and Cannon)clamps as per well plan. 19:00 22:00 3.00 22.00 COMP K 19 P Splice&connect 1/4"TEC wire to discharge pressure sub.\Performed electrical check on MLE and ESP cable(goody Install gator splice on MLE and ESP cable and connect same.Splice 1/4"to 3/8"cap tube @ PDF gator splice connection. 22:00 23:00 1.00 23.00 COMP K 4 P P/U second joint(splice 15'from top of DGU pup jt.)Install clamps over splices./RIH U 144'-Performed electrical integrity test on ESP cable and gauge readings[Phase to Phase 4 ohms/Pressures:intake=82.1 psi;discharge=37.8 psi./ Temperatures:intake=48.5;discharge=527;motor=49.1;electrical=49.1/Vibration:X=0.067;Y=0.064/System current=11.8;System voltage=162/Meg:1.58 gig Ohms]. 23:00 00:00 1.00 24.00 COMP K 4 P RIH-P/U 4 1/2"tbg.with ESP completion assembly as per tally-f/144'-1/209'-P/U bottom GLM-installing cannon clamps as per well plan. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum Sr.Ddg.Spvr. 907-685-1227 337-277-1809 Eni representative Angelo Lamarina Eni Petroleum Dug Spvr. 907-685-1277 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Eni representative David Smith Eni Petroleum Dag.Spvr. 907-685-1277 907-632-3058 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 L80 12,988.4 21,740.0 7/14/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) I Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) I Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 9.40 733.0 12.99 2,651.9 fiai#1 Eni E&P Division 'Well Name:OP09-S■ I EN!Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO e n i Date:7/18/2011 - Report ft: 4 APIIUWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 12.20 0.00 16.27 21.87 Rig Information Contractor -- - I Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase 'Spud Date Target Depth(ftKB) Target Depth(TVD..I Depth Dr.(MD)(ft) 'Drilling Hours(hr) Avg ROP(fUhr) I DFS(days) OP09-S1 COMPLETION 7/15/2011 I 4.00 Daily Information End Depth(ftKB) End Depth(ND)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 85.0 42.3 Mostly Clear,WC 137°SE @ 4.5 mph 39.4° Daily summary operation 24h Summary RIH with ESP completion assembly and cable f/209-1/7740'-P/U 4 1/2"tbg(12.6#;L-80;IBTM;3.833'drift)/Install clamps as per well plan.Perform electrical integrity test and gauge reading every 1000'.\Change out ESP cable spools in spooling unit.\RIH(/7740-If 7998'\Centrilift spliced ESP cable with PTF Gator splice.\RIH 1/7998'-V 10,0221 P/U tbg.hanger with landing joint.\Make penetrator to ESP cable splice and install and cap tube thru tbg.hanger. Operation at 07.00 N/D BOPE. 24h Forecast Finish penetrator to ESP cable splice and install penetrator into hanger.\Land tbg.hanger @ 10,055'and test to 5000 psi.)L/D landing joint&install BPV.\N/D BOPE.\N/U tree.\Test tree 1/5000 psi.and perform final electrical integrity test&gauge readings.\Freeze protect well.\R/D and move rig. Lithology I Shows I MAASP Pressure(psi) I Mud Weight(lb/gal) [Shows 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 13:30 13.50 13.50 COMP K 4 P RIH(/209'-1/7740'-P/U 4 1/2"tbg.(12.6#;L-80;IBTM)with ESP completion assembly as per tally and installing cannon clamps on ESP cable as per well plan.)Perform electrical integrity test and gauge reading every 1000'.1 Dn wt.=63K. 13:30 15:00 1.50 15.00 COMP K 5 P Change out ESP cable spools in spooling unit.Attached ESP cable together with snake to pull to floor for splice. 15:00 15:30 0.50 15.50 COMP K 4 P RIH 1/7740'-1/7998'-P/U 4 1/2"tbg.(12.6#;L-80;IBTM)-Cannon clamp ESP cable as per well plan. 15:30 18:30 3.00 18.50 COMP 'K 5 P Centrilift made splice for reel change on ESP cable with PTF gator splice.\Clamp splice 7'down on joint#141 @ 2024'on depth.-(installed cannon single channel clamps below&above PFT gator splice,didn't have cannon PFT gator splice clamp).)Check ESP cable and gauge reading after splice-[Phase to Phase 5.0 ohms/Pressures:intake=1567 psi; discharge=1553 psi./Temperatures:intake=75;discharge=77;motor-75;electrical=75/Vibration:X=0.058;V=0.043/ System current=11.8/System voltage=161/Meg:1.12 gig Ohms]. 18:30 21:30 3.00 21.50 COMP K 4 P RIH 1/7998'-1/9983'-P/U 4 1/2"tbg.(12.64;L-80;IBTM)-Cannon clamp ESP cable as per well plan.\Perform electrical integrity test and gauge reading every 1000'. 21:30 23:00 1.50 2100 COMP K 4 P R/U GBR compensator to P/U VIT joints and XO-RIH 1/9983'-1/10,0229 P/U Vetco Gray tbg.hanger with landing joint- M/U and orientate hanger.\Up wt.=102K-Dn wt.=65K 23:00 00:00 1.00 24.00 COMP K 5 P Vetco Gray dressed hanger with cap tube and Centrilift began splicing penetrator pigtail to ESP cable for tbg.hanger.\ Perform electrical integrity test and gauge reading before splice. - Daily Contacts Position Contact Name Company Title E-mall _ Offce Mobile Eni representative Frank Cormier Eni Petroleum Sr.DrIg.Spvr. 907-685-1227 337-277-1809 Eni representative Angelo Lamarina EN Petroleum Dug Spvr. 907-685-1277 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Eni representative David Smith Eni Petroleum Drlg.Spvr. 907-685-1277 907-632-3058 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 51/2 L80 12,988.4 21,740.0 7/14/2011 Last Leakoff Test Depth(ftKB) ND(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 9.40 733.0 12.99 2,651.9 Eni E&P Division I Well Name:OP09-S i toos ENI Petroleum Co.Inc. Daily Report Well Code:25601 Field Name:NIKATCHUO e n•®M Date:7/19/2011 - Report#: 5 API/UWI:50-029-23448-00-00 page 1 of 1 Wellbore name: OP09-S1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211-058 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) I RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.40 1220 0.001 16.27 21.87 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase (Spud Date Target Depth(ftKB) Target Depth(TVD..JDepth Dr.(MD)(ft) I Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) OP09-S1 COMPLETION 7/15/2011 I 5.00 Daily Information End Depth(ftKB) End Depth(ND)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 84.0 50.9 Mostly Clear,WC 118°ESE @ 7.7 50.9° mph - Daily summary operation 24h Summary Finish penetrator to ESP cable splice and install penetrator into hanger.\Land tbg.hanger @ 10,055'and test to 5000 psi.f/10 mins.\L/D landing joint&install BPV.\N/D BOPE.\N/U tree.\Test tree 05000 psi.and perform final electrical integrity test&gauge readings.\Freeze protect well./Flush lines&clean pits-R/D and prep for and move rig. Operation at 07.00 Moving rig from OP09-S1 to OP18-08. FINAL COMPLETION REPORT. 24h Forecast R/D and move rig to well OP18-08.\Maintenance on top drive-Canrig Rep.and Nabors mechanic will install shims to put main bearings and ring&pinion gear back into factory specification during rig move. Lhhology 'Shows I MAASP Pressure(psi) I Mud Weight(Iblgal) 9.00 Time Log Start End Cum . Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 COMP K 19 P Finish penetrator to ESP cable splice and install penetrator into hanger-perform electrical integrity test and gauge reading.\ RIH landing tbg.hanger on depth @ 10,055'\Up wt.=102 K-Dn wt.=68K\Lock down tbg.hanger&test upper&lower hanger voids to 5000 psi.f/10 mins.each.\L/D landing joint and install BPV.\Centrilift clamp count in hole=3 Christolizers/ 13 various cannon/222-4 1/2"/2-4 1/2"and x 5 1/2"/1-4 1/2"single.\Clean active pits and change mud pumps to 6" liners 02:30 08:00 5.50 8.00 COMP K 5 P N/D BOP-remove Katch-Kan and curtain./L/D mouse hole./Remove choke&kill lines./Set BOP stack back./Pull raiser and UD same.\Clean active pits and change mud pumps to 6"liners. 08:00 12:30 4.50 12.50 COMP K 5 P N/U tree adapter&tree valves,including wing and actuator valves to production lines.\Perform final electrical integrity test and gauge reading @ penetrator:[Phase to Phase 5.0 ohms/Pressures:intake=1681 psi;discharge=1680 psi./ Temperatures:intake=79;discharge=80;motor=79;electrical=79/Vibration:X=0.055;Y=9055/System current=11.8/ System voltage=161/Meg:120 gig Ohms[.\Pull BPV&install TWC-test tree&components 65000 psi.10 mins.\Vetco Gray pulled TWC. 12:30 14:30 2.00 14.50 COMP K 7 P R/U Little Red&returns lines on tree to freeze protect annulus./Pressure test lines to 2500 psi. 14:30 17:30 3.00 17.50 COMP K 1 P Little Red pumped diesel down IA with returns from tbg.-returns to surface @ 19 bbls pumped.\Started with 1 bpm @ 300 psi.increasing to maximum 600 psi @ wellhead-final pressure of 500 psi.\Pumped total 138 bbls.with 69.5 bbls.retums.\ Blow down lines&R/D lines.\Secure well. 17:30 00:00 6.50 24.00 COMP K 1 P Demobilization of rig for move-pump pill through surface equipment-clean pits-raise cellar box-secure BOP stack- remove temp cutting box&liner/mats for same&CCB equipment-R/D flow&service lines from rig to utility module. 00:00 00:00 24.00 COMP • Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Frank Cormier Eni Petroleum Sr.Drlg.Spvr. 907-685-1227 337-277-1809 Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. 907-685-1277 907-903-7269 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Dulling Tour Pusher 907-670.8539 Eni representative David Smith Eni Petroleum Drlg.Spvr. 907-685-1277 907-632-3058 Last Casing seat • Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date i LINER 51/2 L80 12,988.4 21,740.0 7/14/2011 Last Leakoff Test Depth(RKB) ND(RKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) I Leak Off Pressure(psi) 13,240.0 3,929.71 FazePro 940 733.0 12.991 2,651.9 • 0-40N N QM Q 4 ci % 1III1;u1h11 e tv 0 g Is JJ { s + m_ _ VV mmm E ? m zto V 8 Ep EVuW Ip FW E WWII SM. 29240 g V m Ae DYp pG CpV N NV - 22+g O+yONP V ,A A+ gWr+2- 5 0 o z z o s o o o z m VV N I t N O gN -- zP4 8+ 77° M ggNI:0 W M-WV a .Aktg Ogu N gANNAg NOW i:. aA-00 0O 000 iJ p E` § nNnsa yG10 WOI gOggA WWy0p0 Wry Wt N YNppN 22480e 220o2 ' 4 V - N y pt p s+ b!J $ J sw m = ''4 N N 3 mmA A W a W NN+ W a.. 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C k3.1 1 . 2 II PPP Z ` w w m w 0 I ` Zit0 FF< .+ ..� vv vv vvvww ww w 7 ?Yo $ :747-10g mp,tC VN � mE 1 x II I1 ieWie S Gt4T6 �k3SSa !l$135f3 N 0 x O O� p� 11 .M§S T 2 R s 10 P ; 4 3 0 I pW 4 t 2 2i43,7;t1121 ;;,1104t!= M NNm V A - 0 w s I- 6 STV nn 3 fRN6w g "Pt grll 11 4"P O-PLON -.!05.,-9 p b -'-'-'PP L pPP OGO r'. : 0 r)I P Tn §§LGLb1 ZI + y a NA t.. 13228 M t'zmaz m NNmu p pw V w4w mNV V..OJVi SQSits gs8pp V ,9°m+:1, ,3 , y V 0 0 "0 O"O0 0 8:e40 O O O O O winuo.w wiAi.win Ntinwm wi'Pg E EMS I S I R N iomwiA c = S m E I s s A v m u w o i ie el D a p a mEi io mAmto mmb0& 4A#04 a mbtie visig o §v-=Age 4 vet I3v.5�E1 $ $.N , . 0 N JETI; q il SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Maurizio Grandi Well Operations Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP09-S 1 ENI US Operating Co. Inc. Permit No: 211-058 Surface Location: 3194' FSL, 1583' FEL, SEC. 05, T13N, R9E, UM Bottomhole Location: 3047' FSL, 4980' FEL, SEC. 19, 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. Sin•-re • dirAl i � . No an o i boner DATED this/day of April, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA APR 9 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AI ka Oil&Gas Cons.Commission 20 AAC 25.005 /0 4•V•fill nthar tgn 1a.Type of Work: lb.Proposed Well Class: Development-Oil El • Service- Winj ❑ Single Zone lc.Specify if well is proposed for: Drill 0 • Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket gi Single Well ❑ 11.Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627 • OP09-S1 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 22493 " TVD: 3826 • Nikaitchuq 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): ` ' e ibti . Surface: 3194 FSL, 1583 FEL,S5 T13N R9E UM ADL 355024,373301,390616;388583,391283' •7� Ol T'r,,ZA it Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: I/� 3669 FSL,2541 FEL,S29 T14N R9E UM ADL 417493 5/28/2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3047 FSL,4980 FEL,S19 T14N R9E UM 1280 13603.25'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 52.2 15.Distance to Nearest Well Open Surface:x- 516697. y- 6036547 - Zone- 4 GL Elevation above MSL: 12.2 to Same Pool: 1133'SE to OPO4-07 16.Deviated wells: Kickoff depth: 400 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 95.00 degrees Downhole: 1749 psig • Surface: 1325 psig • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 160 36 36 160 160 pre-installed 1303 TOTAL sx 16" 13-3/8" 68 L-80 BTC 2291 35 35 2331 2172 LEAD:1039 sx 10.7 ppg ASL TAIL:265 sx 12.5 ppg DeepCrete 12.25" 9-5/8" 40 L-80 Hydril 563 13418 33 33 13458 3922 772 TOTAL sx 772 sx 12.5 ppg DeepCrete 8-3/4" 5.5" 17 L-80 Hydril 521 9234 13258 3603 22493 3826 Slottled liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis Q Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements EI 21. Verbal Approval: Commission Representative: Date 4/14/2011 22. I hereby certify that the foregoing is true and correct. Contact Joseph Longo @ 907-865-3323 Printed Name Maurizio Grandi Title Well Operations Project Manager Signature Phone (907)865-3325 Date 4/14/2011 Commission Use Only Permit to Drill/ / API Number: (�Q��ry� Permit App a ,r See cover letter for other Number: f 50-IZ9" V418(J (/D Date: � ri� I I requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce c albed met ane,gas hydrates,or gas contained in shales: lYr Other: I' 5 S 3 0� � i (30/0 (e 5t- Samples req'd: Yes❑ No Mud log req'd: Yes �No it- 2 5 o0 ps 4. Ann P".w�•r rG S-1 ( �1 H2S measures: Yes ❑ No I ectional svy req'd: Yes No ❑ D;v�,r4-Ltr w4 i hr.4 ,t 2 0 A/4G 2.77 035(1+) 5VS p/4LG wrr rov4.X -. Zcl . 7•)(i) DATE: f' r / PROVED BY THE COMMISSION 2 J '// IN�, COMMISSIONER I This permit is valid f 2 nt �; approval( ' 25.005(g)) Sub in plic • Enil PetiroIkuim RECE,v e &at, nll 4PR x 9 2011 Alaska Gil&68s Cons.Gonvnission 4nalcrege 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi @enipetroleum.com April 14,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer OP09-S1 Dear Commissioners, Eni US Operating Co.Inc.hereby applies for a Permit to Drill for the onshore production well OP09-S 1. This well will be drilled and completed using Nabors rig 245E. The planned spud date could be as early as 5/28/2011. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Joseph Longo at 907-865-3323. Sincerely, Maurizio Grandi Well Operations Project Manager *101 Oliktok Point Nikaitchuq Field North em petroleum 0P09-S1 Slope - Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD I TVD SIZE SPECS INFO Cement to Surface 20" Hole Angle X-65 0° 20"Conductor Shoe 160' 160' I Driven Welded N/A N N GR/Res o saws-cal Dir/PWD $ 13-3/8" 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor Surface T/Tail Cement 1831 1757 r• L-80,BTC 8.8-9.5 Lost Circulation w Hole Cleaning u, Casing Sections i5 KOP:400' Casing Wear DLS: B/Permafrost 1900 1818 0-3.75°/100' Hole Angle 42.39 Deq 13-3/8"Csg 2,331' 2,172' ` 16" 50°F WBM GR/RES Neutron/Density/PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 40 lb/ft MW(ppg) Hole Cleaning L-80,Hydril 563 8.8-9.5 Torque&Drag Casing Sections Tangent Angle: Casing Wear 84.50 Deg T BHA Expense Intermediate TOC 11,000' 3,638' Pick-up Top of Sand .. N N 9 N Top 12,000' 3,767 D 7 n TOL 13,258' 3,903' 3 Hole Angle ►I4 84.50 Deg 9-5/8"Csg 13,458' 3,922' 12.25" 85"F LSND GR/RES Neutron/Density/PWD Wellbore Stability Lost Circulation x, Slotted Uner Hole Cleaning a 5-1/2" Torque&Drag m° 17 lb/ft MW(ppg) Casing Sections Xceed 675 w L-80,Hydril 521 8.7-9.4 Casing Wear E 4 BHA Expense g F a Hole Angle 92.23 Deg 5-1/2"Liner 22,493' 3,826' 8-3/4" 85°F MOBM It* Ant Eni Petroleum Application for Permit to Drill 0P09-S1 Saved: 14-Apr-11 Application for Permit to Drill Document Producer Well OP09-S1 Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005(0 3 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) 3 P/ease see Attachment 7:Surface Platt 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 AAC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 AAC 25.005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 5 8. Drilling Fluid Program 6 Requirements of 20 AAC 25.005(c)(8) 6 Surface Hole Mud Program(extended bentonite) 6 Intermediate Hole Mud Program(LSND) 6 Lateral Mud Program(MI FazePro Mineral Oil Base) 6 9. Abnormally Pressured Formation Information 6 Requirements of 20 AAC 25.005(c)(9) 6 10. Seismic Analysis 7 Requirements of 20 AAC 25.005(c)(10) 7 AOGCC PERMIT Document.doc Page 1 of 9 Printed:14-Apr-11 EnD Petroleum .ena Application for Permit to Drill OP09-S 1 Saved:14-Apr-11 11. Seabed Condition Analysis 7 Requirements of 20 AAC 25.005(c)(11) 7 12. Evidence of Bonding 7 Requirements of 20 AAC 25.005(c)(12) 7 13. Proposed Drilling Program 7 Requirements of 20 MC 25.005(c)(13) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 Requirements of 20 MC 25.005(c)(14) 8 15. Attachments 9 Attachment 1 Directional Plan 9 Attachment 2 Drilling Hazards Summary 9 Attachment 3 BOP and Diverter Configuration 9 Attachment 4 Cement Loads and CemCADE Summary 9 Attachment 5 Well Schematic 9 Attachment 6 Formation Integrity And Leak Off Test Procedure 9 Attachment 7 Surface Platt 9 AOGCC PERMIT Document.doc Page 2 of 9 Printed:14-Apr-11 2131- • Eni Iroleur Application for Permit to Drill OP09-S 1 Saved: 14-Apr-11 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 25040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: OP09-S1 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 3194 FSL, 1583 FEL, S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 52.2'AMSL Northing 6,036,546.91' Easting: 516,696.90' Pad Elevation 12.2'AMSL Location at Top of Productive Interval 3669 FSL, 2541 FEL, S29 T14N R9E UM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 13458' _ Northing: 6,047,57782' Easting:515,680.94' Total Vertical Depth, RKB: 3922' Total Vertical Depth,SS: 3870' Location at Total Depth 3047 FSL, 4980 FEL, S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 22493' Northing:6,052,222.40' Easting: 507,937.80' Total Vertical Depth, RKB: 3826' Total Vertical Depth,SS: 3774' Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(6) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent we//bores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and AOGCC PERMIT Document.doc Page 3 of 9 Printed:14-Apr-11 Amu EnD role Jmi Application for Permit to Drill OP09-S1 Saved:14-Apr-11 (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 MC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the fo/%wing items,except for an item a/ready 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 MC 25.036, or 20 MC 25.037,as applicable; Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 MC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item a/ready on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient, The expected reservoir pressure in the Schrader Bluff sand is 0.45 psi/ft, or 8.6 ppg EMW (equivalent • mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the OA sand formation is: MPSP = (3,856'TVDss)(0.45 - 0.11 psi/ft) = 1325 psi • (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 MC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item a/ready on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 MC 25.030(>) Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc Page 4 of 9 Printed:14-Apr-11 ■ role R gnu Application for Permit to Drill OP09-S1 Saved: 14-Apr-11 6. Casing and Cementing Program Requirements of 20 MC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (R) (R) (R) Cement Program 20 Driven 178.89 X-65 Welded 120 36/ 36 1607 160' Pre-Installed 1303 TOTAL sx 13-3/8 16 68 L-80 BTC 2291' 35/ 35 2331'/ 2172' IL: 2 sx 2x 10.7 ppg ppg Cr TAIL: 265 sx 12.5 ppg DeepCrete 772 TOTAL sx 9-5/8 12-1/4 40 L-80 Hydril 563 13418' 33/ 33 13458'/ 3922' 772 sx 12.5 ppg DeepCrete TOC: 11000'MD/3638'TVD 8-3/4"OA 5-1/2 Sand 17 L-80 Hydril 521 9234' 13258'/ 3603' 22493'/ 3826' Slotted Liner-no cement Lateral 7. Diverter System Information Requirements of 20 MC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please see Attachment 3: BOP Configuration. ENI requests that AOGCC waive diverter requirements per 20 MC 25.035. (h). (2). ✓ AOGCC PERMIT Document.doc Page 5 of 9 Printed:14-Apr-11 wok Eni Petroleum A Application for Permit to Drill OP09-S1 Saved: 14-Apr-11 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) 8.8 9.2 9.2 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/100 sf) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program Lateral Mud Program (LSND) (MI FazePro Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point a Value Density(ppg) 8.7-9.4 , Density(ppg) 8.8 -9.5 Plastic Viscostiy _ Funnel Viscosity 45 -60 (CP) (seconds) Yield Point 15 - 20 Plastic Viscostiy 12 - 18 (lb/100 si (CP) HTHP Fluid loss Yield Point (ml/30 min @ <5.0 (lb/100 sf 18-24 200psi&100°F API Filtrate Oil/Water (cc/30 min)) 4 6 Ratio 60/40 Chlorides(mg/I) <500 Electrical >600 pH 9.0- 10.0 Stability MOT <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: AOGCC PERMIT Document.doc Page 6 of 9 Printed:14-Apr-11 isk EnH tiroleu _era Application for Permit to Drill 01309-S1 Saved: 14-Apr-11 (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f), Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 MC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 MC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(b),• Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 MC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items,except for an item a/ready 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 MC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in/ rig up Nabors 245E. • atucrTetC WAILIEO V 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. 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. 1 10. Install 9-5/8"casing rams in the BOP and test to 3500 PSI. • AOGCC PERMIT Document.doc Page 7 of 9 Printed:14-Apr-11 • Eno Petroleu Application for Permit to Drill OP09-S 1 Saved:14-Apr-11 11. RU casing drive system. 12. Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 13. Install 9-5/8"Emergency Slips. 14. Install 9-5/8"packoff and test to 5000 psi. 15. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 16. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 17. PU 8-3/4" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 18. Drill out cement and between 20'and 50'of new hole. Perform formation integrity test, recording • results. 19. Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 20. PU and run 5-1/2"slotted liner to TD. • 21. Land liner, set liner hanger with 200'Liner lap inside the 9-5/8"intermediate casing. POOH laying down • DP as required. 22. PU ESP completion as required and RIH to depth. Land tubing. Set BPV ° 23. Nipple down BOP, nipple up tree and test. Pull BPV. • • ENI requests that the AOGCC waive surface safety valve requirements per 20 AAC 25.265. (c). ✓ (1). • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. 24. Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 25. 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 a/ready on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 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MN m 2 r O MMr10 N r NM 21 mm 0 rd g 000 2r'NN 24200 544r N O M M rr N C m^O g dg V O dg ng d V 2222 mn6'r 4mm mC Am m mm m 0 mNm N N22, m 2O tm` 2 mm 22 m 21r 1 2 m 09,%,%MM 0 W 0 O N c C o g �Q W N 1 2'n m m N d m b m N N A N n 0 O N 1 1Q 2 r 0 2 O Q N N 1 2 2 2 2 2 00-q M M 1 1 m O C mN 2 N 2Yem mG C C C C m C bC Om 0 mm 81111 201 222 m mmmmm mmm.m 5416'1c btG V>tC mtC b NmtC b1G NtU tU mlO O u G G p p p p p p 10 0 0 0 0 0 8 0 0 0 0 0 0 8 0 0 o S !0 0 0 0 1°O' p S o S°o M o 8 8 8 0 5 8 0 i 2 2 2 2 2 2 2 2 S S S S S S S 8 8 0 0 0 0 J 0 0 0 0 0 0 G� O �0 0 O M M M M 1 y MMM M M 1.j M M M M M M M O M M M 0 0 0 0 0 OO O N 1 V N N(V l V l V N f V(V C N l V O NNN O N N N O 1E N N O 2M J n 0 J J N N M m 0 ;m < m =____ 22'1?N;e rm = Jd;== N Ji m N 0 d mw2 22 m m Am0 82222 2 mr 2820 2 o20 1 v;44 ; 00° N S O a 3 K O M M b 1 M 0 n N CND r h n m r 1p p N�r M r 2 4 Z b N r m 2 O m b 0 N 01 8 1 m O 12 M g 01 120,2 100 CMD O M 2 8D O o n<r O d N a map�d r m M b d 0 d r d M O S O N N m�M N O P r N �p N 21°0 RA 1M Na dM mb2 IO d4 C!D° 0!1 tM G11pb NM r 2Oi C1� ml m2� OO Nn 0 mi-v!iuml a %22128I2r Mm 2Mr O M M M o1 N N N N N N N N N'M .-N N 17 M N 110 10 m m m 0 0 0 0 N M M d 2 r r r N N M 2 2 2 0 N NNN N N NNN M o O y t 80M0 i.N Cr)2 N M rN r'D 2 N!N°r O Q O N O N m G N 222 821X1 M�1N pp^1 M N MQ� p?N Nd M N N O O N 7Eg 2p a c%721?7 m 1a NMOM Ny NMM 18p .m O O I0 OrA /20 0 ONN 888°m p NO qM bNr 10 m ON N NNN N Q N T C O 2 X 2'4'4 O N Q28 mN t:8N 8 A OI=0 V 201 S 8 M �1pp 88 SN p 8�CNDm N i0?2N!8 NCN O eN 222 p N Y 1 mS 121 QOgrO r °NO M li 2O Nb Nrr 111E 1 0000 aNM !''" 0 PP'a° 6102 O V C E 0�0; 2 N N O 2 0 2 d r -r p 2 2 2 O N O O:m pp i md:N d 2 O Yl d C� O N O N yy 2 2 0 1° mdMC O O NO M m N O N 6'y m p h m V m m NM 0O 0r R O 0 N M N N N V O MtM f M C M M M y 0 0 K, 2 2 2 0 0 N N m 8 10''M r p 2 2 N O N M O N r m 8 0 0 0 0 O N N w O Q 8 NON Q 8 Ord p N O�M m y r O N�Np Oyry 9,N 01 <Omm Imp 00 m 19,m�d dNm mr �P1pp C9,1rp 2 O Nn1?b 00 m dd r Nr NN N m mr tQ7m N�mrO �OMf O O tNh V 10120 ANMNM nhp 12020 Or�NM 't01MD rCND mq O b' h hbN1p 120 Nrl�6'2 1546'r2 rom M N 1D LINO tN01012D rroCO rom Nm m A 101 N2 N 2M M MMMM Mn MMM M M M r6'212 om,1 m mmm m mmmmm MMM MM MMM 11'1 M M MM mb MMMMM N N N NNM M M M M ry I M M 1 y M M M 1.>1.1 M M 1 y M M 1.1 M M M Y e 2N•- N N N NNp 1 4 22 ry Q O p Q m m r M M 7,m O N mmN O 8 SS°8 80088 0008 a 201 1!0 28288 22082 �} �{ p Q M N C-O N 0101 m N N N m 0 S 0 M O r 110.— -01 2 01 0;1 D M 0 p j o g g g 9,$QO$ p°o�o d0 10,110,101 a,01 8 °O m m°O°O 1°0,1°0°0°O S 1°0,1°010 5°O yEy M 1.2j 127 M MMM 1 1 1 1 M M M M C CN'1 M M tom'1 M M M MOM M M M M MMM M M M M M M NNM M M M M M M M M C C O A 1 N A 1 b b 1 1 C 2 N< d d a 1 n n 110 N N 2 0 r 1 12.1 N 1 N p N a 2 N 2 y 21 2 !N g y2j i(Q1 g a S Or1 O O m C 0 8 O 2 8 6'8.8 8 8 10 N N N 222 88282 2282222 222222 882222 22222 W,1111 ,1111! !12!2 8822dm2 12228 882222 2220222 R C 22 2 8 01086' 28882 !88p8! 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N Z O 1' 1 1 - ii°5 i i iiii °o e 1 1 0 ;1 I I I 1 111■ a, n x 2 1 I q :! 0 I 1. i 1 i iiii m is I W i3 g i i 6 i i$ i i iiiii '4' °u ? w i i 0 i A ■ i iHE! n Z m f i i> i i i iiiii s m I ■ -1 1 1 1 1 1 1 II i y U•Ij Ij ••> I 1 I 1 4 1 1 1 1 6 0 0 •• '1 1 1 1 4 14.M ii p o ■ 1 :1 1 1 ■ 1 1 iii■ M O 0 0 0 O O 0 N C 10 N co (4)OOZI:(u0 I.=ale3S and (4)00Z 1.:(U!)1.=e'en a/u en. Schlumberger WELL I FIELD I STRUCTURE OP09-S1 (P3b) Nikaitchuq Oliktok Point Magmas Parameters Surface Loceeon NRD27 Ness Strata Flare,Zone 00,US Feet I Miscellaneous Model'. BOOM 2010 Dip. 81.009' Dete: June 15.2011 Let: N 703038.725 NoMing: 6036506.91 SUS Grul Core 0.12860319' 5a: 0009 TVD Ref: Rotary TabM(522f1 above MSS) Mag Dec: 21.070' FS: 57639 3n Lan: W 1095108.127 Eavis0 51669680818 Scala Fad:099990032 Plan'. 0P09.51(P30) Sney lab:March 30.2011 -10000 -8000 -6000 -4000 -2000 0 J End Cry QP09-S1(P3.) 51-51 Tgt 16 TD Cry 2/100 End Cry End Cry 51-51 Tgt 14 'N SIS1 Tgt 17 Cry 2/100 End Cry CA,2/100 • SIS1 Tgt 12 ,41 14 End Cry Cry 2/100 �� SIS1 Tgt 16 Cf4 2/100 End Cry 14000 ` End Cry A-St Xgt.1A.., 14000 Cry 2/100 SIS1 Tgt 13 E0d(ry Cry 2/100 End CN - SIS I Tgt 6 SI-51 Tgt 41 Ch 2/100 Cry 2/•00 End Cry End Cry SIS1 Tgt 6 End Cry •SIS7 Tgt 9 Cry 2/100 r,,,2/100 SIS4 Tgt 4 EM c„, Chi 2/100 SI81 Tgl 7 End Cry Cry 2/100 i SISI Tgt 3 12000 a End a.... .Crvs/460End Cry 12000 SIS7 Tgt Cry 2/100 CA,2.6/100 End Cry A 51-S1 Tgt 2 i Cry 2/109 - Cry 2.5/100 94/6"Csg 5141 heel End Cry 10000 0 10000 A n n z K Cry 3/100 O O O N c 8000 8000 ii m U U) N V V V 6000 I 6000 End Cry 1 4000 4000 Cry 1/100 2000 2000 End Cry Cs Cry 3.76/100 Civ 0.5/100 P Bld 2.75/100 0 K PId1'.50 0•-10000 -8000 -6000 -4000 -2000 0 RTE «< W Scale=1(in):2000(ft) E >>> I • Schlumberger OP09-S1 (P3b) Anti-Collision Summary Report Analysis Date-24hr Time: March 30,2011-10:06 Analysis Method: Normal Plane Client: ENI Reference Trajectory: OP09-S1(P3b)(Non-Def Plan) Field: Nikaitchuq Depth Interval: Every 5.00 Measured Depth(ft) Structure: Oliktok Point Rule Set: 0554 Anti Collision Standard Slot: OP09 Min Pts: All local minima indicated. Well: OP09-S1 Borehole: OP09-S1 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Restricted within 41010.5 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 I Minor I Major OP10-09(Def Survey) Warning Alert 7.17 4.76 3.85 4.98 244.07 244.07 OSF<5.00 Enter Alen IIIIIIIIIIIII 1 2.98 2.14 2.77 349.01 349.01 MinPt-CtCt 5.9 EIM 2.02 2.61 368.99 368.99 MinPt-O-EOU 6.09 2.96 MMial 2.55 378.98 378.98 MinPt-O-ADP 7.64 3.61 2.21® 438.91 438.91 MinPt-O-SF 63.53 41.86 ME 1 3.05 1018.35 1012.09 MinPt-O-ADP 81.67 50.58 35.66[ raar 1198.75 1184.10 MinPt-O-SF 177.58 141.08 123.45 5.00 1663.54 1607.09 OSF>5.00 Exit Alert 2803.30 2702.68 2652 86® 5594.70 2944.71 MinPt-O-SF 3521.10 3398.94 3338.36® 6742.00 3092.12 MinPt-O-SF 3784.66 3653.10 3587.81 28.98 7145.64 3143.81 MinPt-O-SF 3992.63 3853.58 3784.5 Min 746090 3184.18 MinPt-O-SF 6025.30 5804.94 5695.25® 11769.65 3737.41 MinPt-O-SF 5785.27 5587.0 5488.43 29.33 12254.67 3798.26 MinPt-O-ADP 5783.0, T-• 5488.95 29.59 12286.68 3802.09 MinPt-O-EOU NOM 5588.82 5493.35 30.27 12360.63 3810.84 MinPt-CtCt 4522.18 4391.10 18.25 18310.34 3911.41 MinPt-CtCt 4425.00 4280.54 16.32 1942059 3908.56 MinPt-CtCt 4718.01'1 4274.44 15.99 19675.89 3891.78 MinPt-O-EOU 4721.11 4422. •MERE 15.86 19775.81 3885.00 MinPt-O-ADP 5055.60 4687.77 4504.3 EliE 22492.82 3826.45 MinPt-O-SF 0107-04(Def Survey) Warning Alen M11111111111111:11/30.11101 351004.00 3.88 3.88 MinPts Milig 11.95 10.59 5.38 494.18 494.17 MinPt-C1C1 15.98 min 10.44 5.13 519.25 519.23 MinPt-O-EOU 16.05 11.90 MirlE 5.06 529.28 529.25 MinPt-O-ADP 16.20 11.97 10.47 4.98 54432 544.28 OSF<5.00 Enter Alert 38.98 28.60 21.021 3.381 878.76 876.15 MinPt-O-SF 148.79 117.81 102.93 4.96 1334.30 1309.91 OSF>5.00 Exit Alert 531.21 456.4-•r' 2256.17 2115.84 MinPts P ".r, 1137.90 1104.75 18.16 4509.18 2802.84 MinPt-CtCt 1205.5 MEM 1104.16 17.99 4579.07 2811.98 MinPt-0-EOU 1206.15 1137.7, t E 1 17.88 4623.97 2817.84 MinPt-O-ADP 1117. 1036.61 996.47 13.91 6083.75 3007.82 MinPt-Ctet 1118. 1036.4 996.03 13.83 6123.64 3012.92 MinPt-O-EOU 1118.73 1038. 995.921 13.76 6158.56 3017.40 MinPt-0-ADP 1015.27 970.21 12.27 6757.37 3094.08 MinPt-CtCt 1 107 �tr 26 1014.66 968.86 12.08 6857.01 3106.84 MinPt-O-EOU 861.30 791.65 7.18 9240.10 3412.04 MinPt-CtCt 1005.72111 785.88 6.89 9549.52 3451.66 MinPt-O-EOU 1006.70 859.0.Nun 6.86 9589.36 3456.76 MinPt-O-ADP 1020.01 864.3 NEM 6.59 9952.43 3503.26 MinPt-O-ADP 1011.56 828.95 738.1 E 11161.30 3658.12 MinPt-O-SF 1011.16 828 65 737.8'miam 11190.99 3661.96 MinPt-O-SF 1011 1• 828.64 El= 5.57 11197.59 3662.81 MinPts IMMO 828.64 737.88 5,57 11200.88 3663.24 MinPt-CtCt 1026.88 845.44 755.21 5.69 11397.21 3688.81 TO 0111-01(Def Survey) - .F _ - . IWYa11lh A(Mt,- I 15.91 14.77 _ 12.61 58276.32 3.95 3.95 MinPts 15.08 11.53 10.37 5.96 428.86 428.86 MinPt-CtCt 15.21 11.41 10.11 5.42 458.77 458.77 MinPt-0-EOU 15.60 11.48 10.04 4.97 49366 493.65 05F<5.50 Enter Alen 93.05 52.84 33.35 2.361 1240.46 1223.15 MinPt-O-SF 229.22 182.36 159.53 5.00 1886.62 1805.95 OSF>5.00 Exit Alert 1762.92 1671.84 1626.7.MEE 5527.28 2935.92 MinPt-O-SF 1846.51 MEM MEMO 19.44 6048.28 3003.27 MinPts 1941.59 1837.87 1786.8'Mr 1 6480.25 3056.03 MinPt-O-SF 5213.97 5063.631 4989.3 35.08 12660.82 3844.48 MinPt-O-ADP 5211' 4989.77 35.49 12686.74 3847.23 MinPt-O-EOU 5209 92 5065.12 4993.60 36.41 12740.42 3852.84 MinPt-CtCt MB= 5023.35 4950.22 35.35 13740.96 3934.37 MinPt-CtCt 517170=DM 4949.19 35.11 13801.32 3932.45 MinPt-O-EOU 5172.81 5023.06--E 34.91 13852.84 3929.56 MinPI-0-ADP 5173.48 5026.18 4953.34 35.50 14009.89 3918.44 MinPt-CICI 5169 221 5023 171 4950.98 35.78 14319.38 3915.36 MinPts 0111-01PB1(Def Survey) Warning-Alert .. fI 15 99 14 771 12.661 58276.32 3.95 3.95 MinPts 15 081 11 53 10.37 5.96 428.86 428.86 MinPt-CtCt Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\0P09-S1\OP09-S1\0P09-S1(P3b) 3/30/2011 10:08 AM Page 1 of 12 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 15 21 11.41 10.11 5.42 458.77 458.77 MinPt-O-EOU 1550 11.48 10.0 4.97 493.66 493.65 OSF<5.00 Enter Alert 93.05 52.84 33.35 2.361 1240.46 1223.15 MinPt-O-SF 229.22 182.36 159.53 5.00 1886.62 1805.95 OSF>5.00 Exit Alert 1762.92 1671.84 1626.79® 5527.28 2935.92 MinPt-O-SF 1959.97 1855.62 1803.95 , 6529.85 3064.95 MinPt-O-SF 2015.46 1908.47 185546 19.00 666659 3082.46 TD OP03-P05PB1(Def Survey) "�:�..,-e - _,. • Weming Alert ® 54.61 MEE 739.11 64.00 64.00 MinPts ® 53.79 wt 5478 244.00 244.00 MinPts 56.16® 52.83 42.65 299.00 299.00 MinPt-O-EOU 56.191 52.86 41.74 304.00 304.00 MinPt-O-EOU 77.78 65.07 j 6.67 947.42 943.27 MinPt-O-ADP 85.14 66.97 58.50 4.95 1058.83 1051.09 OSF<5.00 Enter Alert 87.81 67.57 MEL 4.55 1094.05 1084.84 MinPt-O-ADP 89.26 68..'�r 8 4.40 1109.10 1099.20 MinPt-O-ADP 102.92 75.14 61.86 ilEl 1203.45 1188.51 MinPt-O-SF 153.55 121.68 106.32 4.97 1400.68 1370.29 OSF>5.00 Exit Alert 2451.66 2385.42 2352,7'MalE 4827.43 2844.44 MinPt-O-SF OP03-P05(Del Survey) Werning Alert mmcp 54.61 NEM 739.11 64,00 64.00 MinPts =Ell 53.7'- 54.78 244.00 244.00 MinPts 56.16.4$ 52.83 42.65 299.00 299.00 MinPt-O-EOU 56.19 MiErE 52.86 41.74 304.00 304,00 MinPt-O-EOU 77.78 65.0 - 6.67 947.42 943.27 MinPt-O-ADP 85.14 66.97 58.50 4.95 1058.83 1051.09 OSF<5.00 Enter Alert 87.81 67.5 58 07 4.55 1094.05 1084.84 MinPt-O-ADP 89.26 68. 58.05 4.40 1109.10 1099.20 MinP1-0-ADP 102.92 75.14 61.86 3.831 1203.45 1188.51 MinPt-O-SF 153.55 121.66 106.32 4.97 1400.68 1370.29 OSF>5.00 Exit Alert II 2196 971 2115.85 2075.78 27.40 6035.50 3001.64 MinPt-CtCt 21973811 2115.0 i 207441 27.01 6110.49 3011.24 MinPt-O-EOU 2197.58 2115 11 2074 31 26.96 6120.48 3012.52 MinPt-O-ADP 1 , 2162.84 2110.19 21.54 7376.82 3173.41 MinPt-CtCt 2021.04 1943.67 14.06 9810.24 3485.05 MinPt-CtCt 2177.571 1942.06 13.92 8884.70 3494.59 MinPt-O-EOU 2185.7.1 2019.6. 1937.03 13.23 10282.47 3545.53 MinPt-O-EOU Min 2007.94 1919.16 12.31 10839.43 3616.85 MinPt-CtCt 2187.1 2006.0.MEM MEC 10952.49 3631.33 MinPts OP03-P05PB2(Def Survey) F77 54.61 52.58 739.11 64.00 64.00 MinPts 56.02 53.79 52 54.78 244.00 244.00 MinPts 56.18 52.83 42.65 299.00 299.00 MinPt-O-EOU 56.19 53.65 52.86 41.74 304.00 304.00 MinPt-O-EOU 77.78 65.07 59.331 6.67 947.42 943.27 MinPt-O-ADP 85.14 66.97 58.50 4.95 1058.83 1051.09 OSF<5.00 Enter Alen 87.81 67.5 T'I. 455 109405 1084.84 MinPt-O-ADP 89.26 68.. 58..: 4.40 1109.10 1099.20 MinPt-O-ADP 102.92 75.14 61.86 3.81 1203.45 1188.51 MinPt-O-SF 153.5555111 121.66 106.32 4.97 1400.68 1370.29 OSF>5.00 Exit Alert 1 2196 97' 2115.85 2075.78 27.40 6035.50 3001.64 MinPt-CtCt 2197 38 2115.0 2074.41 27.01 6110.49 3011.24 MinPt-O-EOU 2197.58 2115.11 2074. 26.96 6120.48 3012.52 MinPt-0-ADP 1 2269 131 2162.84 2110.15 21.54 7376.82 3173.41 MinPt-CtCt /f 2198 69 2067.021 2001.68 16 821 8617.87 3332.35 MinPts OP12.01(Def Survey) S w s,„ ;.. Werning Alert Emu 22.15 49.85 132.62 132.62 MinPts 23.9 - 20.60 33.08 172.62 172.62 MinPt-O-EOU 24.05 mEg3 20.73 28.00 192.61 192.61 MinPt-O-EOU 25.03 22.251 MM, 15.30 287.56 287.56 MinPt-O-ADP 49.13 38.31 3351 4.99 750.89 750.02 OSF<5.00 Enter Alert 121.89 88.98 73.14 11111 1111.02 1101.04 MinPt-O-SF 201.23 159.97 139.95 5.00 1341.89 1316.86 OSF>5.00 Exit Alert 3794.92 3681.79 3625.72rell 6378.73 3045.59 MinPt-O-SF 3915.13 3798.56 3740.77 6533.80 3065.45 MinPt-O-SF 6353.64 6176.67 6088.6:'. 8 9031.79 3385.36 MinPt-O-SF 7191.81 6988.34 6887.1.MIMI 10140.20 3527.31 MinPt-O-SF 6940.88 6720.26 6610. 'Nam 11721.68 3731.19 MinPt-O-SF 6490.04 6308..• 35.85 12517.94 3828.87 MinPt-O-ADP 6489.1 6307.8• 6217.74 35.98 12528.26 3830.02 MinPt-O-EOU 6488•• 6309.05 6219 84 36.36 12555.11 3833.00 MinPt-CtCt � 262.401�12 17177.32 3920.74 MinPts OPO4-07(Def Survey) Warning Alert 1117 44.64 43.8 34.01 278.84 278.84 MinPts 47 32 44. 43.79 30.00 31584 318.84 MinPt-O-EOU 47.45 44.5 43.77' 28.28 338.84 338.84 MinPt-O-ADP 48.2 43.95 42.43 15.52 555.26 555.21 MinPt-CtCt I 1 48.366 43.781 42.10 14.04 590.58 590.48 MinPt-O-EOU 48.88 43 87 41 98�12 61 626.04 625.86 MinPt-O-ADP 69.31 57.19 51,74 6.25 1084.92 1076.11 MinPt-O-SF 70.77 58.42 52 85 6 2 1105.47 1095.75 MinPt-O-SF 267.61 213.25 186.56 4.99 4462.78 2796.78 OSF<5.00 Enter Alert T8 147.34 106.83 2.82 5416.21 2921.40 MinPl-CtCt 230.01 r" 1. 1 104.69 2.76 5505.20 2933.03 MinPt-O-EOU 230.79 146.3 maim 2.75 5551.49 2939.08 MinPt-O-ADP 231.62 146.67 1045' 5597.82 2945.12 MinP1-0SF 234.23 150.05 108.. 06 6052.68 3003.84 MinPt-O-SF 234.20 150.03=OM 2.80 6062.53 3005.10 MinPt-O-ADP Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\0P09-S1\0P09-S1\0P09-S1(P3b) 3/30/2011 10:08 AM Page 2 of 12 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft), Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 234.18 150.03 108.44 2.80 6067.46 3005.73 MinPt-O-EOU IL 234.16 150.06 108.51 2.81 6092.08 300888 MinPt-CtCt 302.40 241.00 210.79 4.99 7205.65 3151.49 OSF>5.00 Exit Alert 472.2, 368.09 6.85 8661.71 3337.96 MinPt-O-EOU 473.06 402.6 '.61 6.80 8716.69 3345.00 MinPt-O-ADP 419.85 335.02 293.10 5.00 9678.14 3468.13 OSF<5.00 Enter Alert 252.98 133.71 74.5611111111113E 11589.73 3714.00 MinPt-O-SF 237.45 126.8' 2.16 11658.30 3722.95 MinPt-O-ADP 196.7 100.41 52.73 2.05 11968.47 3762.88 MinPt-CtCt 208.7 87.8 27.92 1.73 12072,13 3775.90 MinPt-O-EOU 218.27 89.7 25.981 1.70 12107.17 3780.25 MinPt-O-ADP 222.01 91.19 26.27 1.701 12118.70 3781.68 MinPt-O-SF 298.74 150.08 76.24 2.02 12271.29 3800.25 TD OP08.04P61(Def Survey) Warning Alert I 7.9 6.761 4.651 193944.70 0.00 0.00 MinPts 8.361` 6.101 5.04 6.85 188.89 188.89 MinPt-O-EOU 9.43 6.54 5.71 4.93 238.86 238.86 OSF<5.00 Enter Alert 12.68 8.91 7.6'lllllllllllllfe' 298.72 298.72 MinPt-O-SF 19.49 14.60 12.77 4.98 378.36 378.36 OSF>5.00 Exit Alert 45.91 35.73 31.26 4.99 808.33 806.83 OSF<5.00 Enter Alert 47.461 36.291 31.31 4.65 915.69 912.32 MinPt-O-EOU 48.31 36.5 31.21 4.45 1002.62 996.88 MinPt-O-ADP 57.84 43.32 36.6 4.261 1198.40 1183.77 MinPt-O-SF 78.36 61.69 53.97 4.99 1421.80 1389.41 OSF>5.00 Exit Alert 118.31 97.06 87... L14 1913.60 1829.87 MinPt-O-SF 132.50 105.01 91.89 5.00 2265.74 2123.19 OSF<5.00 Enter Alert 132.2 =EEC=KEE 4.77 2302.60 2151.16 MinPts 1=EIM 96.35 79.69 3.89 2482.61 2265.59 MinPt-CtCt 131.8 76.68 3.62 2542.72 2318.34 MinPt-O-EOU 132.64 94.8'MIME 3.58 2562.44 2330.84 MinPt-O-ADP 135.57 96.51 77.47® 2611.12 2360.84 MinPt-O-SF 18498 146.90 128.35 4.96 2834.73 2482.37 OSF>5.00 Exit Alert 848.4 794.94 768.70 16.15 5442.17 2924.79 MinPt-CtCt 849.9 1 793.2 765.37 15.23 5602.55 2945.73 MinPt-O-EOU 850.83 793.4 765.24 15.06 5645.50 2951.32 MinPt-O-ADP 1 793.651 717.15 679.40 10.50 6979.56 3122.54 MinPt-CtCt • 794.3 716.62 678.24 10.34 7029.10 3128.88 MinPt-O-EOU 795.39 716.8,91 678.06 10.24 7058.73 3132.68 MinPt-O-ADP 988.09 873.25 816.3 8.61 7907.03 3241.31 MinPt-O-SF 1323.55 1190.76 1124.85 10.03 8295.24 3291.03 TO 0708-04(Def Survey) "?y n Waming Alert ( 7.9811 6,761 4.651 193944.67 0.00 0.00 MinPts 8 36 6.10 5.04 6.85 188.89 188.89 MinPt-O-EOU 9.43 6.54 5.71 4.93 238.86 238.86 OSF<5.00 Enter Alert 1268 8.91 7.6 =L8 298.72 298.72 MinPt-O-SF 19.49 14.60 12.77 4.98 378.36 378.36 OSF>5.00 Exit Alert 45.91 35.73 31.26 4.99 808.33 806.83 OSF<5.00 Enter Alert 47. 36. 31.31 4.65 915.69 912.32 MinPt-O-EOU 48.31 36. 31. 4.45 1002.62 996.88 MinPt-O-ADP .' 57.84 43.32 36.6684 4.261 1198.40 1183.77 MinPt-O-SF 78.36 61.69 53.97 4,99 1421.80 1389.41 OSF>5.00 Exit Alert 118.31 97.06 87. 5.8 1913.60 1829.87 MinPt-O-SF I 13280 105.01 91.89 5.00 2265.74 2123.19 OSF<5.00 Enter Alert 132.27 4.77 2302.60 2151.16 MinPts NI= 96.35 79.69 3.89 2462.61 2265.59 MinPt-CtCt 131.8 IMZIZ 76.68 3.62 2542.72 231834 MinPt-O-EOU 132.64 94.81 3.58 2562.44 233084 MinPt-O-ADP 135.57 96.51 77.47■ 2611.12 2360.84 MinPt-O-SF 184.98 146.90 128.35 4.96 2834.73 2482.37 OSF>5.00 Exit Alert 848.401 794.94 768.70 16,15 5442.17 2924.79 MinPt-CtCt 849.9"1 793.2 765.38 15.23 5602.55 2945.73 MinPt-O-EOU 850.83 793.4 765.211 15.06 5645.50 2951.32 MinPt-O-ADP 717.16 679.40 10.50 6979.56 3122.54 MinPt-CtCt 794.3 MM. 678.25 10.34 7029.10 3128.88 MinPt-O-EOU 795.39 716.8' 678.0 10.24 7058.73 3132.68 MinPt-O-ADP 959.87 848.61 793. ,. :30 7835.14 3232.11 MinPt-O-SF 3907.85 3764.6 27.47 12822.35 3861.16 MinPt-O-ADP 3902.3• 3694.75 28.32 12883.21 3867.15 MinPt-O-E0U 391489 3772.54 3701.: IMO 13167.64 3894.42 MinPt-O-SF SP27-N1(P2)(Def Plan) Warning Alert 17848.07' 7843 971=II 6211.03 40034 400.34 MinPts 17853.73 17852.51 17820 93 N/A 0.00 0.00 Surface 1104.75 878.79 768.86 5.00 20909.77 3867.28 OSF<5.00 Enter Alert 372.80 205.07 122.7611111111 11M 21843.85 3850.68 MinPt-O-SF 359.00 197.70 118.41 II® 21876.61 3850.06 MinPt-O-SF 1 290 76 143.83 70 86 1.99 2228428 3834.56 MinPt-CtCt 294.82 116.981 28.551 1.661 22492.82 3826.45 MinPts OPO4-07781(Del Survey) Warning Alert 47.21 44.6 43.89 34.01 278.84 278.84 MinPts �,1 47 32 44.56 43.79 30.00 318.84 318.84 MinPt-O-EOU 47 45 44.59 43 771 28.26 338.84 338.84 MinPt-O-ADP LJ 43.95 42.43 15.52 555.26 555.21 MinPt-CtCt 48.36=cm 42.10 14.04 590.58 590.48 MinPt-O-EOU 48.88 43.87 MIMI 12.61 626.04 625.86 MinPt-O-ADP 69.31 57.19 51.7-111MM 1084.92 1076.11 MinPt-O-SF 70.77 58.42 52.86[ W 1105.47 1095.75 MinPt-O-SF 267.61 213.27 186.60 5.00 4462.78 2796.78 OSF<5.00 Enter Alert =ME 147.37 106.86 2.82 5416.21 2921.40 MinPt-CtCt Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\0P09-S1\0P09-S1\0P09-S1(P3b) 3/30/2011 10:08 AM Page 3 of 12 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)J EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 230.01 146.15 104.72 2.76 5505.20 2933.03 MinPt-O-EOU 230.79 146.35 104.62 2.75 5551.49 2939.08 MinPt-O-ADP 231.62 146.69 104.73 2.75 5597.82 2945.12 MinPt-O-SF 234.23 150.06 108.48 2 88 6052.68 3003.84 MinPt-OSF 234.20 150.051 108.47 2.80 6062.53 3005.10 MinPt-O-ADP 234.1 150.0 108.47 2,80 6067.46 3005,73 MinPt-O-EOU 1 234.16 150.08 108.53 2.81 6092.08 3008.88 MinPt-CtCt 302.40 241.00 210.80 4.99 7205.65 3151.49 OSF>5.00 Exit Alert 472.2•'1 368.09 6.85 8661.71 3337.96 MinPt-O-EOU 473.06 402.6 =Can 6.80 8716.69 3345,00 MinPt-O-ADP 419.85 335.02 293.10 5.00 9678.14 3468.13 OSF<5.00 Enter Alert ' 308.891 186 461 125.74 2.541 10763.10 3607.08 MinPts 5125-N2(P2)(Def Plan) ,"ak' '1- - Warning Alen I 17845.191 17841971 17812.38 618117 400,36 400.36 MinPts 3100.92 2907.74 2813.14r 'I.61 3905.74 MinPt-O-SF 17852.13 17850.91 17819.33 N/A 0.00 0.00 Surface 1086.82 863.79 755.60 4.99 20236.16 3871.65 OSF<5.00 Enter Alert 1 578.981 314.07 185.15 2.22 22140.83 3840.14 MinPt-CtCt 579.43 313.621 184.26 2.21 22175.50 3838.79 MinPt-O-EOU 580.08 313.76 184.15 221 22195.30 3838.02 MinPt-O-ADP 581.02 314.20 184.33 2.211 22215.07 383725 MinPt-O-SF 614.50 34990 207.68 228 2249282 3826.45 TD OP14-S03(P5)(Def Plan) Warning Alert 55.97 54.74 52.64 N/A 0.00 0.00 Surface 55.97 52.16 50.86 21.15 400.00 400.00 MinPt-CICt 56.03 52.081 50.71 20.08 41979 419.79 MinPt-O-EOU 56.11 52.09 50.69 19.62 429.69 429.69 MinPt-O-ADP 160.22 136.44 125.1 7.05' 1074.07 1065.71 MinPt-O-SF 547.80 437.45 382.76 5.00 7817.19 3229.81 OSF<5.00 Enter Alert 435.57 380.62 4.96 7902.12 3240.69 MinPt-C1Ct 546.6 435.4 380.31 4.95 7932.12 3244.53 MinPt-O-EOU 547.05 435.5 380. 4.94 7957.12 3247.73 MinPt-O-ADP 221 602.24 475.36 412.41 4.781 8423.74 3307,49 MinPt-O-SF 722.58 577.12 504.88 499 8768.42 3351.63 OSF>5.00 Exit Alert 3082.19 2850.59 2745.2;MIME 11778.22 3738.52 MinPt-O-SF 2874.92 2701., =KIM 16.66 12538.36 3831.15 MinPt-O-ADP 2866.4 2699 9, 2817.22 17.31 12636.45 3841.88 MinPt-O-EOU MEM 2709.54 2835.94 19.41 12878.51 3866.69 MinPt-CtCt 2708.87 2835.35 19.42 13017.68 3880.05 MinPt-C1Ct 2859.': 2706 0, 2629.88 18.76 13264.36 3903.69 MinPt-O-EOU 2863.29 2706. =ME 18.38 13425.66 3919.15 MinPt-O-ADP 2879.28 2714.01 2631.8 MEE 13896.11 3926.24 MinPt-O-SF 1134.91 2142.60 2021.93 9.88 17695.63 3909.61 MinPt-CtCt 2387.04\ 2132.4'? 2005.67 9.41 18183.44 3910.35 MinPt-O-EOU 2391.54 2132.38 2003.29 9.26 18363.38 3911.85 MinPt-O-EOU 2398.37 1999.50 9.04 18641.72 3912.09 MinPt-O-EOU I 2404.97 1996.70 8.85 18883.59 3912.20 MinPt-O-EOU 2507.55 2144.69 1963.74 6.931 22492.82 3826.45 MinPts SP30-W 1(P2)(Def Plan) Werning'MIME . '�' '1.1/ 6219.04 400.34 400.34 MinPts 17856.35 17855.13 17823,54 N/A 0.00 0.00 Surface 945.99 752.68 658.45 4.99 20606.83 3868.51 OSF<5.00 Enter Alert 700.26 539.42 460.5.® 20847.14 3867.80 MinPt-O-SF 674.64 519.96 444.01• 2088428 3867.63 MinPt-O-SF 1 587.271 462.39 400.44 4 73 21109.83 3863.74 MinPt-CtCt 587.87 462.11 399.72 4.70 21128.35 3863.45 MinPt-O-EOU 593.41 463.44 398.94 4.59 21164.89 3882.77 MinPt-O-ADP 716.53 539.63 451.68 4.071 2137985 3858.97 M1nPFO-SF 1186.13 947.96 829.36 5.00 22131.20 3840.52 OSF>5.00 Exit Alert 1291.01 1040.08 915.11 5.16 22492.82 3826.45 TD SI29-S2(P2)(Def Plan) Wanting Alen'. 17859.93 17855.46 I1 17827-121+ 'y t 400.37 400.37 MinPt-O-SF 17823 5401.05 436.54 436.54 MinPts 17855.48 17854.28 17822.67 N/A 0.00 0.00 Surface 17855.48 17852.9 17822.671 13452.63 198.80 198.80 MinPts 17855.77 17852.6 17822.96 9396.55 258.80 258.80 MinPt-O-EOU 1243.15 975.46 842.101 4.661 22490.34 3826.55 OSF<5.00 Exit Alert 2638.01 2392.88 2272.61 10.95 22492.82 3826.45 TD I 1289.56 1078.77) 973.871 614] 14384.50 3915.44 MinPts 1291.044 1085.7,0,''y6 983.53 6.31 16335.27 3930.60 MinPt-O-EOU 1291.04 1085.7 983.5 6.31 16340.20 3930.54 MinPt-O-ADP 1291.05 1085.71 983.5 6.34 1636976 3930.35 MinPt-OSF .', 1082.48 978.82 6.22 17415.67 3912.48 MinPt-CtCt MEM 1054.97 937.74 5.50 20381.57 3869.30 MinPt-CtCt 1290.31 1031.40 902.43 5.00 21948.29 3847.63 OSF<5.00 Enter Alert IIIIMIE MEll MLEE M01 22485.40 3826.74 MinPts 1 ■ 0106-05(P9)(Def Plan) _ Pees 32.00 30.78 28.67 N/A 0.00 0.00 Surface Millal 28.97 28.06 17.03 300.00 300.00 MinPt-CtCt . 2829 27.02 12.14 470.27 470.26 MinPt-CtCt 32.06 IMMIllia 26.97 11.94 485.29 485.28 MinPt-O-EOU 32.10 28.26� - 26 961 11.84 495.29 495.28 MinPt-O-ADP 32.29 M30133 26.80 10.92 520.27 520.24 MinPt-O-EOU 32.43 28.25 Mgja 10.55 530.24 530.20 MinPt-O-ADP 41.42 35.18 32.67 limn 663.37 663.06 MinP1-OSF 374.28 351.24 340. - 1268.57 1249.31 MinPt-O-SF 3977.37 3884.94 3839.2 43.49 5645.63 2951,34 MinPt-O-SF 5086€ 3877.95 3832.26 43.44 5841.71 2976.74 MinPt-CtCt Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP09-S1\OP09-S1\OP09-S1(P3b) 3/30/2011 10:08 AM Page 4 of 12 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 3553.?3400.54 3324.66 23.41 9007.32 3382.22 MinPt-CtCt 3567.81 3367.6 3268.07 17.91 11035.81 3642.00 MinPt-O-EOU 3568. 3367.1 3267.08 17.82 11080.13 3647.68 MinPt-O-EOU 3568.54 33672 3267.021 17.81 11085.34 3648.35 MinPt-O-ADP 3597.88 3393.14 3291. 17.651 11256.61 3670.47 Min Pt-O-SF 3687.10 3480.01 3376.96 17.88 11451.66 3695.94 TD 0113-03(P4)(Def Plan) Pass 47.97 46.75 44.65 N/A 0.00 0.00 Surface MIMEO 45.34 44.63 33.08 250.00 250.00 MinPt-CtCt 48.1,m •0i 43.49 20.24 394.95 394.95 MinPt-O-EOU 48.48 Imm Egi 43.19 17.42 424.69 424.69 MinPt-O-EOU 48.74 44.60 NEM 16.31 439.54 439.54 MinPt-O-ADP 94.95 77.92 7002 iei 822.84 821.15 Min Pt-O-SF 196.35 167.73 154.0 P3 1155.54 1143.34 MinPt-OSF 4252.47 4150.06 4099. 5999.48 2997.02 Min Pt-O-SF 8003.90 7805.64 7707 01®i 9711.27 3472.38 MinPt-O-SF 7633.28 7410.12 7299 03 i® 11815.13 3743.28 MinPt-O-SF 7172.17 6988.52 6897.19 39.26 12516.23 3828.88 MinPt-O-ADP 7170.1 6988.11 6897.57 39.59 12538.01 3831.11 MinPt-O-EOU E6990.22 6901.73 40.50 12590.71 3836.92 MinPt-CtCt 6009.38 5878.67 23.99 17981.82 3908.67 MinPt-CtCt 6288.9- 6005.9; 586499 2230 18789.16 391216 MinPt-O-EOU 6289.35 6006.0 586•.86 22.27 18808.69 3912.17 MinPt-O-ADP 664743 6308.86 6140 06 Mal 22492.82 3826.45 Min Pt-O-SF OP17-02(Def Survey) Pees 7999[ 79.00 76.66 N/A 0.00 0.00 MinPts 80.74 IIIIIEEI. 77.41 77.95 223.92 223.92 MinPt-O-EOU 81.41 78.6 MEM 51.53 273.87 273.87 MinPt-O-ADP 83.43 79.2 i1/ 27.71 378.68 378.88 MinPt-O-ADP 107.76 99.64 96.19 imam 655.19 654.91 MinPt-O-SF 261.67 245.29 237.7.Mj1K1 1110.15 1100.21 MinPt-O-SF 309.41 290.12 281 1 r i11131 120055 1185.79 MinPt-O-SF 9616.20 9391.11 9279.06 42.90 11765.75 3736.90 MinPt.OSF 9266.91 9064.7.. 8964.11 46.05 12286.49 3802.07 MinPt-O-ADP 9266.2;. 9064.501 8964.23 46.17 12295.50 380314 MInPt-0-EOU 9266.0 1 9064.86 8964.76 46.28 12304.50 3804.22 MinPt-CtCt 9260.58 9070.161 8975.4 48.88 12477.49 3824.31 MInPt-O-ADP 9260.1 9070..• 8975.53 48.97 12482.64 3824.89 MInPt-0-EOU p259.8 9070.39 8976.17 49.13 12491.67 3825.91 MinPt-CtCt 4_7466.02 7321.57 26.84 19227.31 3911.94 MinPt-CtCt 7757.2:'. 7317.79 26.53 19375.32 3910.39 MinPt-O-EOU 7758.55 7464.2.mu= 26.44 19421.73 3908.50 MinPt-O-ADP 7998.9. 7650.0.. 7476.06 22.99 21559.05 3855.77 MinPt-O-EOU 8000.19 7850.2 22.92 2159903 3855.05 MinPt-O-ADP 8009.95 7654.:. 7477.80 22.62 21798.76 3851.49 MinPt-O-ADP 8125.18 7752.03 7565.95 21.83 22492.82 3826.45 TD 10098.22 9909.08 9815.01 1E1M 9318.25 3422.04 MinPt-O-SF 0P17-02P61(Def Survey) Pass 79 990.1710 76.66 N/A 0.00 0.00 MinPts 90.4-'MUD 77.16 89.46 193.94 193.94 MinPt-O-EOU 80.74 min 77.41 68.30 223.92 223.92 MinPt-O-EOU 81.33 78.47'. / 49.10 268.88 268.88 MinPt-O-ADP 83.43 79.131®I 26.71 378.68 378.68 MinPt-O-ADP 102.82 94.94 91.61®] 627.04 626.86 MinPt-O-SF 110.45 101.99 98.37®' 669.30 668.97 MinPt-O-SF 261.67 245.16 237.5.®' 1110.15 1100.21 MinPt-O-SF 309.41 290.01 280.9' 16.96 1200.55 1185.79 MinPt-O-SF 9669.58 9443.97 9331."MS= 11763.66 3736.63 MinPt-O-SF 9659.86 9434.47 9322.2:man 11770.64 3737.54 MinPt-O-SF 9291.12 9089.2•NM= 46.24 12297.52 3803.38 MinPt-O-ADP 9290 65 9089.1• 8988.87 46.33 12303.94 3804.15 MinPt-O-EOU 9290.38 9089.39 8989.38 46.45 12312.93 3805.22 MinPt-CtCt 7803.39 7519.27 7377.71 27.56 18988.31 3912.12 MinPt-CtCt 7804.85' 7374.64 27.27 19108.24 3912.03 MinPt-O-EOU 7805.77 7517.8:MIEFZIE 27.20 19138.22 3912.01 MinPt-O-ADP 818828 7814.71 7628.43 21.98 22492.82 3826.45 TO 9991.21 980477 9712.0• il, 9199.13 3406.79 MinPt-0-SF • Oliktok Point I-2PB1(Oaf Survey) Pass 64.51 63.39 61.18 N/A 0.00 0.00 Surface Min 63.39 i I8 N/A 40.00 40.00 MinPts 53.78 4634 43.63 8.76 697.00 696.52 MinPt-CtCt 53.84 46.561 43.48 8.55 709.97 709.41 MinPt-O-EOU 53.90 46.57 43.46 8.49 714.93 714.34 MinPt-O-ADP 122.05 103.21 94. 6.821 1052.41 1044.91 MinPt.O-SF 4526.85 4451.47 4414.27 60.84 4449.07 279498 TD Oliktok Point 1-2(Def Survey) Pass 64.51 63.39 61.18 N/A 0.00 0.00 Surface 84.51 83.3.lli !8 N/A 40.00 40.00 MinPts 53.78 48.64 43.63 8.76 697.00 696.52 MinPt-CtCt 53.84 46.561 43.48 8.55 709.97 709.41 MinPt-O-EOU 53.90 46.57 43.48 8.49 714.93 714.34 MInPt-O-ADP 122.05 103.21 94.34 8.821 1052.41 1044.91 MinPt-O-SF 5697.061 5592.70 5541.02 55.10 5828.73 2975.07 MinPt-O-EOU 5699.81 5592.°94 5539 99 53.82 6000.19 2997.12 MinPt-O-ADP 8336.51 8111.47 7999.45 37.24 11761.97 3736.41 MinPt-O-SF 7783 32 7681.4 39.22 12254.70 3798.26 MinPt-O-ADP 7987.761 7783.27 7681.52 39.25 12257.82 3798.64 MinPt-O-EOU Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\0P09-S1\0P09-S1\0P09-S1(P3b) 3/30/2011 10:08 AM Page 5 of 12 Offset Trajectory Se•aration Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 7987.56 7783.49 7681.95 39.33 12265.64 3799.58 MinPt-C1Ct 7987.9• 7793.47 7696.71 41.27 12430.92 3818.99 MinPt-CtCt ~ 6809.9• 6556.' 6430.93 27.0. 17653.82 3910.04 MinPts Oliktok Point I.2PB2(Def Survey) Pass 64.51 63.53 61.18 N/A 0.00 0.00 Surface IC 64.� 63.3.iE•'1 N/A 40.00 40.00 MinPts IL 53.76 46.66 43.67 8.80 697.00 696.52 MinPt-CtCt 53. 46.581 43.51 8.59 709.97 709.41 MinPt-O-EOU 53.90 48.59 43.50 8.52 714.93 714.34 MinPt-O-ADP 123.90 104.80 95.80 6.821 1057.00 1049.33 MinPt-O-SF 5697 061 5592.7 5541.02 55.10 5828.73 2975.07 MinPt-O-EOU 5699.81 5592.94 5539.991 53,82 6000.19 2997.12 MinPt-O-ADP 7756.191 7567.01 747291 4121 14844.20 3914.83 MinPts OP05-06PB2(Def Survey) Pass 39.76 37.88 36.43 58.32 153.94 153.94 MinPts 39.82 37.83 36 50 49.86 173.94 173.94 MinPt-0-EOU 136.20 120.17 112.76 9.11 967.52 962.83 MinPt-O-SF 157.91 139.65 131.13® 1022.35 1015.95 MinPt-O-SF 5158.46 5076.94 503667 64.04 5601.81 2945.64 MinPt-O-SF wpm 5058.66 5018.37 63.78 5814.91 2973.28 MinPt-CtCt 5140. . 5058.661®a.N,; 63.78 5817.53 2973.62 MinPts 40 4690.89 4614.99 31.90 9685.52 3469.08 MinPt-CtCt 4844.2 4690.2,' 4613.72 31.65 9750.29 3477.37 MinPt-O-EOU 4844.77 4690.3'IMMICE 31.57 9770.20 3479.92 MinPt-0-ADP 4691.68 4611.57 30.28 10103.44 3522.60 MinPt-CtCt '°�s 4888.19 4606.62 29.74 10257.86 3542.37 MinPt•CtCt 4852.. Ems- ' 4605.05 29.48 10337.64 3552.59 MinPt-O-EOU 4853.67 4887.4'x,Ltri 29.38 10372.53 3557.06 MinPt-O-ADP 4892.r•MEM MIME 27.35 11079.63 3647.62 MinPts 4893.2'MEM 4622.28 27.18 11131.70 3654.30 MinPt-O-EOU 4893.31 4712.2' 27.17 11134.67 3654.68 MinPt-0-ADP 4893.85 4712.60 4622.46 lar 11149.59 3656.61 MinPt-O-SF OP05-06PB1(Def Survey) - Pass 39.76 37,88 36.43 58.32 153.94 153.94 MinPts 39.82 37.83 36.50 49.86 173.94 173.94 MinPt-O-EOU 136.20 120.17 112.76 IIIIIIIIIIIIIIIII:NE 967.52 962.83 MinPt-O-SF 157.91 139.65 131.1 MIND 1022.35 1015.95 MinPt-O-SF 5008.33 4958.32 4933.81 10214 3397.98 2657.59 TO OP05-06(Def Survey) Pass , /u3v 39.76 37.88 36.43 58.32 153.94 153.94 MlnPls 39.82 37.83 36.50 49.86 173.94 173.94 MinPt-O-EO1J 136.20 120.17 112.76 IIIIMEXII 967.52 962.83 MinPt-O-SF 157.91 139.65 131.1 .', 1022.35 1015.95 MinPt-O-SF 5158.46 5076.94 5036.6 MME 5601.81 2945.64 MinPt-O-SF wpm 5058.66 5018.38 63.78 5814.91 2973.28 MinPt-C1Ct 5140..•. 5058.66 NI= 63.78 5817.53 2973.62 MinPts IIIIIMEE 4690.88 4814.98 31.90 9685.52 3469.08 MinPt-CtCt 4844.2 4690.2 4813.71 31.64 9750.29 3477.37 MinPt-O•EOU 4844.77 4690.4690. •�"• 31.57 9770.20 3479.92 MinPt-O-ADP E4852. 4691.67 4811.56 30.28 10103.44 3522.60 MinPt-CtCt 4852. 4688.18 4806.61 29.74 10257.86 3542.37 MinPt-CtCt 4852. 4687. 4605.03 29.48 10337.64 3552.59 MinPt-0-EOU 4853.67 4687. 4604.881 29,37 10372.53 3557.06 MinPt-O-ADP OZIZEg 4674.47 4585.07 27,14 11082.68 3648.01 MinPt-CtCt 4854.2811 4674 44 1 4585.02 27.14 11065.51 3648.37 MinPt-O-EOU 4854.31 4674.45 4585.01 27.13 11088.92 3648.55 MinPt-O-ADP 4877.09 4695.55 4605 2s11111111111211311 11209.39 3664.34 MinPt-O-SF 4885.24 4703.37 4612.93 11231.73 3667.24 MinPt-O-SF 5149.17 4963.23 4870.74 27.83 11582.92 3713.11 TD 0120-07(P10)(Def Plan) Pass 109.40 108.69 78.43 250.00 250.00 MinPt-CtCt 112.52=12312 107.45 43.47 429.22 429.22 MinPt-D-EOU 112.95 108.81 38.38 453.56 453.56 MinPt-O-ADP 150.02 141.15 137.33 708.85 708.30 MinPt-O-SF I 10787.12 10718.13 10684.13 158.601 3798.40 2709.93 MinPt-O-SF 12304.64 12229.42 12192.30 4308.49 2776.61 MinPt-O-SF 12917.28 12702.35 12595.3 NornigE 12257.14 3798.56 MinPt-O-SF 12140.58 11803.62 1163583 36.13 22492.82 3826.45 TD 16878.04 16718 12 16638.6 mon, 8663.90 3338.24 MinPt-O-SF OP16-03 working(Non-Def Survey) t''''''';:' Pass 1,��11111111®• 686 N/A 0.00 0.00 MinPts Millal 68.24 67.13 31.61 394.11 394.11 MinPt-Ctet 71.761 86.95 29.50 423.79 423.79 MinPt-0-EOU 71.87 68.17111111111 28.52 438.59 438.59 MinPt-O-ADP 180.46 164.02 156.4 MBE 982.47 977.35 MinPt-O-SF 205.65 187.02 178.31 IIIIIIIIIIIIIIIEE 1035.11 1028.26 MinPt-O-SF 10973.50 10875.12 10826 42® 5437.78 2924.22 MinPt-O-SF 11926.34 11710.64 11603 28® 12049.97 3773.13 MinPt-O-SF 11801.04 11404.3'Emig 5928 12398.44 3815.24 MinPt-0•ADP 11600.8 11306.58 59,32 12400.39 3815.47 MinPt-O-EOU 11600.74 11404.45 11306.79 59.39 12404.29 3815.92 MinPl-0tCl 10709.28 10446.05 10314.93 40.83 18012.37 3908.92 MinPt-CtCt 10709.95 10444.9 '. 10312.95 40.56 18082,36 3909.51 MinPt-O-EOU 10710.74 10445.11 Ma= 40.47 18107,34 3909.71 MinPt-O-ADP 10910.23 10619.56 10474.71 37.86 19094.16 3912.04 TD Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP09-S1\OP09-S1\OP09-S1 (P3b) 3/30/2011 10:08 AM Page 6 of 12 Offset Trajectory Separation Allow Sep. Reference Trajectoryi Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft)I Alert I Minor I Major 11032.25 10915.00 10856 871 54.88 6409.33 3049.51 MinPt-0-SF 0115-SO4(P3)(Def Plan) Pass 64.01 62.79 60.69 N/A 0.00 0.00 Surface 64.01 60.79 59.79 31.39 325.00 325.00 MinPt-CtCt 64.17 mom 59.39 26.54 385.00 385.00 MinPt-0-EOU 64.26 60.59 mmE0 25.79 400.00 400.00 MinPt-0-ADP 119.66 103.60 96.1,■ 887.47 884.69 MinPt-0SF 220.99 191.75 177.7.IMO 1198.16 1183.55 MinPt-0SF 3251.05 3061.93 2967.8 8903.83 3368.97 MinPt-0SF 4457.06 4224.80 4109.1: ECISE 11814.47 3743.20 MinPt-0SF 4218.33 4016.11 IIIEMM 20.96 12401.61 3815.61 MinPt-0-ADP 4216 33'MDZIE 3915.87 21.11 12426.39 3818.47 MinPt-0-EOU 74214.89 4017.28 3918.97 21.43 12471.96 3823.68 MinPt-CtCt 3334.19 3195.16 12.99 18570.38 3912.05 MinPt-CtCt 3628.30 MEM 3184.26 12.28 19284.27 3911.89 MinPt-0-EOU 3658.91=M1 3157.75 10 97 20835.85 3867.83 MinPt-0-EOU 3659.76 3324.6.®I 10.95 20865.83 3867.75 MinPt-0-ADP 3709.73 3333.6'. 3146.0•'; 9.89 22492.82 3826.45 MinPts OP22-W W01(P2)(Def Plan) . Pass 127.941 124.12 122.83 48.91 400.00 400.00 MinPl-CICI 128.12 123.95 12247 42.95 443.94 443.94 MinPt-O-EOU 128.17 123.95 122.45 42.37 448.82 448.82 MinPt-0-ADP 210.29 198.31 192.94 19.44 938.26 934.35 MinPt-0-SF 221.54 209.00 203. imprE 962.98 958.42 MinPt-0-SF 4093.30 4042.49 4017.5.. 5318.23 2908.33 MinPt-O-SF 4214.77 4162.47 4136.811 82.11 5504.26 2932.91 MinPt-OSF 6760.37 6691.89 6658.14 100.14 7531.15 3193.18 TD OP23-W W 02(Def Survey) P 132.51 Mg= 112.86 267.98 267.98 MinPts 01112M 132,21 131.46 89.17 329.00 329.00 MinPt-CtCt r 135.01 131.29 80.58 364.00 364.00 MinPt-0-EOU LS^1, 131.88 130.93 70.32 408.78 408.77 MinPt-CtCt 135.03 MEM 130.87 88.33 418.53 418.53 MinPt-O-EOU 135.06 131.85 130.86 67.38 423.41 423.41 MinPt-0-ADP 135.44 132.01 130.89 60.41 462.42 462.41 MinPt-0-ADP 236.12 219.26 211 44 Man 1202.16 1187.31 MinPt-0.S6 525.44 502.83 492.07 WEE21 2648.88 2383.26 MinPt-0-SF 6206.84 6147.56 6118.42 106.47 9094.42 3393.38 TD Oliktok Point I.1A-106(P5)(Def ,,,,:1,44-.:4., Plan) Pass °> " 72,55 70.63 69.22 N/A 0.00 0.00 Surface 72.55 70.63 69.22 198428.11 40.10 40.10 MinPts 72.65 70.53 69.32 342.39 84.20 84.20 MinPt-O-EOU 275.79 246.49 232.:1 10.00 1201.45 1186.64 MinPt-0SF won 6066.47 602097 67.67 5977.76 2994.24 MinPt-CtCt 6149.- 5966.55 5875.39 33.73 9662.42 3466.12 MinPt-CtCt 6152. 1 5931 581 5821.72 27,99 11080.35 3647.71 MinPts 6152.54 5931.79 582191 2799 11088.70 3648.78 MinPt-0SF 6307.10 6075.19 5959 72 27 31) 11439.64 3694.36 MinPt-0SF 6444.70 6208.88 6091.47 27 44 11574.36 3711.99 TD Oliktok Point 1-1(Def Survey) Pe' OW,s, 72.55 70.63 69.22 MA 0.00 0.00 Surface 72.55 70.63 69.22 198426.11 40.10 40.10 MinPts 72.65 70.53 6932 342.39 84.20 84.20 MinPt-0-E0U 275.79 246.49 232.80 10.00 1201.45 1188.64 MinPt-0SF 5937.60 5850.51 5807. 69 57 5524.95 2935.61 MinPt-0SF 5949.011 5842.65 5790.35 56.86 5582.41 2943.11 MinPts �.. 0119-08(P6)(Def Plan) ''.. Pose .+,,"2h/ / 104 01 102.78 100.68 N/A 0.00 0.00 Surface 104.01 100.19 98.90 39.69 400.00 400.00 MinPt-C1Ct 104.05®" 98.79 38.27 414.71 414.71 MinPt-O-EOU 104.12 100.15 98 78 37.43 424.52 424.52 MinPt-0-ADP 176.49 164.23 158 711MBEE 882.05 879.37 MinPt-0SF 338.98 313.69 301.65 1197.56 1182.98 MinPt-0-SF 10777.37 10550.19 10437 10 mall 11819.82 3743.88 MinPt-0-SF 10427.62 10223 45. 10121.86 51.32 12324.40 3806.57 MinPt-0-ADP 10426.71 MIME 10122.08 51,50 12337.78 3808.15 MinPt-0-EOU Noma 10223.96 10123.38 51.82 12360.07 3810.77 MinPt-CtCt ECM 8636.50 8488.36 30.15 19260.08 3911.91 MinPt-CtCt , 8934.61 MIME 8486.75 29,99 19333.43 3911.44 MinPt-O-EOU 8935.56 8635.8,jjjjm 29.91 19369.57 3910.57 MinPt-0-ADP 9231.06 8869.72 8689.54 25.61 21794.73 3851.56 TO 10899,67 10730.87 10646 96 0MMn 8435.06 3308.94 MinPt-0-SF OP18-08(P10)(Del Plan) Pass 87.99 86.77 84.67 N/A 0.00 0.00 Surface I 87 99 85.36 84.65 61.43 250.00 250.00 M1nPt-CICI 88.10 85.231 84.40 52.69 290.00 290.00 MinPt-O-EOU 88.19 85.25 84.39 50.54 305.00 305.00 MinPt-O-ADP 151.19 138.80 133.21 13.4. 785.27 784.06 MinPt-0SF 351.81 322.70 308.76® 1200.84 1186.07 MinPt-0SF 10750.04 10527.80 10417.1 48.5. 12166.37 3787,54 MinPt-0SF 10181.85 9790.73 9595.67 26.10 22492.82 3826.45 TD 10162.39 10030.38 9964.86 impEg 6719.24 3089.20 MinPt-0SF 15648.86 15427.25 15316.9•MIME 10263.46 3543.09 MinPt-0SF OP26-DSPO2(Def Survey) Pass Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP09-S1\0P09-S1\0P09-S1(P3b) 3/30/2011 10:08 AM Page 7 of 12 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft L EOU(ft Dev.(ft) Fact. MD(ft) I TVD(R) Alert Mirror Major 3513 349.44 347.99 N/A 3.99 3.99 MlnPts 336.02 325.38 321.02 38.32 909.27 906.04 MinPt-CtCt 336.6 324.81 319.85 33.75 957.42 953.01 MinPt-O-EOU 340.57 325.82 . 319 4 26.39 1053.74 1046.19 MinPt-O-ADP 348.47 328.22 319.05 18.90 1184.80 1170.97 MinPt-O-ADP 361.21 336.88 325.68 16 03 1337.97 1313.27 MinPt-O-SF 492.29 457.51 441.08 14.92 2294.41 2144.99 MinPt-O-SF 3837.26 3787.14 3762.96 79.31 6336.57 3040.19 MinPt-O-SF SI32-W2(P2)(Def Plan) Pass I17851.471 17847.361 17818.66 6197.22 400.37 400.37 MinPts 2887.83 2700.60 2608.81 15.7111 19470.84 3905.69 MinPt-O-SF 17858.88 17857.64 17826.05 N/A 0.00 0.00 Surface 1167.30 1026.55 956.9 MIME 19721.45 3888.69 MinPt-O-SF 1 1007.341 889.11 830.48 8.58 20072.13 3874.33 MinPt-CtCt 1008.09 888.501 829.20 8.49 20101.29 387585 MinPt-O-EOU 1009.86 888.87 828.87 8.41 20124.61 387547 MinPt-O-ADP 1228.59 1053.89 968.03 7.14 20562.41 3868.65 MinPt-O-SF 2566.52 2307.22 21780 993 22492.82 3826.45 MinPt-O-SF SP24-SE1(P2)(Del Plan) Pass 17855.35 17850 83 17822 5 5417 31 400.37 400.37 MinPt-O-SF L17850.861 17846.321 17818.06 5381.49 437.77 437.77 MinPts 17849.83 1784061 17817.02 N/A 0.00 0.00 Surface INEUE 17847.2,MIMI 13439.95 198.80 198.80 MinPts 17850.11 , 17817.30 9585.16 253.80 253.80 MinPt-O-EOU 2856.29 2596.57 2469.46 11.21 11.21 22339.60 3832.41 TD 1312.79 1100.94 997.1 6.321 12545.72 3831.96 MinPt-O-SF I 1271.15 1069.961 972. 6.48 12773.31 3856.21 MinPt-0-ADP 1269.161 1069.53 972.76 6.53 12803.20 3859.24 MinPt-O-EOU 1 1267.57 1071.20 976.20 6.64 12863.07 3865.18 MinPt-CtCt 1338.62 115031 MEW 7.89 14381.00 3915.44 MinPt-O-ADP 1339.04 1158.62 1071.9 NMI 14387.49 3915.43 MinPt-O-SF 1631.72 1435.83 1341.31 II1M1E 17901.80 3908.00 MinPt-O-SF 1670.49 1469.10 1371.8,11111111111 18370.02 3911.90 MinPt-O-SF 1763.02 1546.68 1441.9'IMZ1E 19467.78 3905.89 MinPt-O-SF 1833.38 1606.28 1496.11 MIKE 20170.31 3872.72 MinPt-O-SF SP33-W3(P2)(Def Plan) Pass r, n . ' alEM I 17848.781 17820.07 6212.22 400.36 400.36 MinPts 17859.73 17858.51 17826.92 N/A 0.00 0.00 Surface 1330.02 1173.95 1097.21 MEM 19895.25 3878.01 MinPt-O-SF 1 1098 941 979.59 920.40 9.28 20240.25 3871.58 MinPt-CtCt 1099 01 979.531 920.28 9,27 20246.96 3871.47 MinPt-O-EOU 1099.15 979.561 920.261 9.26 20251.43 3871.40 MinPt-O-ADP 1335.63 1189.93 1087.57 8.101 20605.08 3868.52 MinP1-0-SF 1 3693 32 3435.85 3307.61 14.40 22492.82 3826.45 TD SP23-N3(P2)(Def Plan) Pass MIME I 17839 491 17810 78j 6204.36 400.34 400.34 MinPts 17849.03 17847.81 17816.22 N/A 0.00 0.00 Surface 1 1487.431 1237.21 1115.54 6.08 21659.34 3853.98 MinPt-CtCt 1487.8'3311 1236.831 1114.76 6.07 2170010 3853.09 MinPt-O-EOU 1488.33 1236.94 1114.67 6.06 21733.98 3852.64 MinPt-O-ADP 1496.33 1242.46 1118.95 6.031 21892.02 3849.66 MinPt-O-SF 1 ■ 1501.53 1246.80 1122.8 6.0 21950.36 3847.55 MinPt-O-SF 1602.60 1338.27 1209.50 6.20 22492.82 3826.45 TD 5135-W4(P2)(Def Plan) w,F- -.-0 :-N n ' 17854.681 17850.771 17822 071 6197.75 400.37 400.37 MinPts 17881.48 17860.25 17828.67 N/A 0.00 0.00 Surface 1572.24 1425.71 1353.47 IMEEE 20047.25 3874.73 MinPt-O-SF 1 1347.461 1227.55 1168.08 11.32 20404.32 3869.12 MinPt-CtCt 1347.65 1227.381 1167.71 11.29 20413.30 3869.09 MinPt-O-EOU 1348.08 1227.4511 1167.63 11.26 20421.77 3869.06 MinPt-O-ADP ■ 1649.31 1476.96 1391.28 9.621 20847.63 3867.80 MinPt-O-SF 4372.01 4113.60 3984.89 16.98 22492.82 3826.45 TD SP36-W5(P2)(Def Plan) Pass 17856031.11MfMEMEK 6188.95 400.37 400.37 MinPts 17862.30 17861.08 17829.50 N/A 0.00 0.00 Surface I 1694.31 1543.92 1469.811 20094.75 3873.96 MinPt-O-SF 1 1447.191 1327.70 1268.44 12.20 20396.30 3869.16 MinPt-CtCt 1447.25 1327.631 1288.32 12.19 20399.70 3869.14 MinPt-O-EOU 1447,45 1327.68 1268.28 12.18 20403.11 3889.12 MinP1-0-ADP 1768.20 1600.49 1517.13 10.801 20758.22 3868.06 MinPt-O-SF 5314.76 5056.76 4928.25 20.67 22492.82 3826.45 TD SI17-SE2(P2)(Def Plan) Pass l�17849.39 17844.84 17816.581 5365.121 400.37 400.37 MinPt-O-SF U '7844.481 17839,931 1781167 5364.32 438.99 438.99 MinPts 17843.42 17842.19 17810.61 N/A 0.00 0.00 Surface 17843.4 17840.88 111=131 13425.45 198.80 198.80 MinPts 17843.67 17810.86 9797.49 248.80 248.80 MinPt-O-EOU 3374.74 3120.84 2996.57 13.56 21961.36 3847.12 TD 2605.72 2387.65 2280.27® 12395.60 3814.91 MinPt-O-SF 2479.05 2281.05=am 12.83 12775.01 3856.39 MinPt-O-ADP 2476.99 2280.62 2185.09 12.94 12801.03 3859.02 MinPt-O-EOU 2282.35 2188.62 13.18 12853.14 3864.21 MinPt-CtCt 2557.0/ 2382.08 MEM 1 15.12 14379.68 3915.44 MinPts ■ 2557.51 2382.34 2297.87. 14388.69 3915.43 MinPt-O-SF 2725.37 2546.26 2459.7 iiiiiiiiiiiiiiiEE 16336.00 393059 MinPt-O-SF 3176.63 2924.54 2801.,•iiiiiiiiiiiiiiEE 21686.48 3853.49 MinPt-O-SF Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\0P09-S1\0P09-S1\0P09-S1(P3b) 3/30/2011 10:08 AM Page 8 of 12 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 SD37-WD1(P2)(Def Plan) Pass maw- 17859 831 1783134J81666 400.31 400.31 11 Pte 2957.09 2734.89 2626.74 13.64 20229.98 3871.75 MinPt-CICt 2957.18 SEEME 2626.54 13.63 20230.39 3871.74 MinPt-O-EOU 2957.27 2734.8•MEEM 13.63 20230.55 3871.74 MinPt-O-ADP 2962.43 2739.12 2630.42®'' 20232.91 3871.70 MinPt-O-SF 4872.38 4693.63 4605.57 27.65 20293.18 3870.72 TD 17864.14 17863.03 17831.34 N/A 0.00 0.00 Surface I17864.14 17859.84 17831.34 5602.24 398.80 398.80 MinPts SP18-N5(P2)(Def Plan) Pass r 17838.24 17834.1 17805.45 6163.64 400.34 400.34 MinPts 3037.29 2832.87 2733.391 15.24 19311.65 3911.74 MinPt-O-ADP 3037.231 2832.86 2733.40 15.24 19311.86 3911.74 MinPt-O-EOU I 3037.1','11 2832.89 2733.47 15.25 19312.32 3911.74 MinPt-CtCt 17844.20 17842.98 17811.39 N/A 0.00 0.00 Surface ' 3047.12 2841.49 2741. =ME 19312.86 3911.73 MinPt-O-SF 4264.56 4039.95 3930.,•MIK 20385.59 3869.26 MinPt-O-SF • 4271.30 4046.36 3936.3 MOE 20405.51 3869.11 MinPt-O-SF 1 4432.32 4198.53 4084.0 MOE 20866.81 3867.74 MinPt-O-SF 4799.00 4531.25 4399.6 I 22492.82 3826.45 MinPt-O-SF SI14-N6(P2)(Def Plan) Pass a . 6180.58 400.34 400.34 MinPts EMU 2948 25 2847.47 15.63 19445.50 3907.25 MinPt-CtCt 3154.99 2948.21 2847.38 15.62 19451.60 3906.89 MinPt-O-EOU 3155.05 2948.23 MIMI 15.62 19454.69 3906.71 MinPt-O-ADP 3156.12 2948.96 2847.,.mum 19476.92 3905.29 MinPt-O-SF ! 17841.04 17839.81 17808.23 N/A 0.00 0.00 Surface 5922.49 5658.77 5528.8.MEE 22492.82 3826.45 MinPt-O-SF SP22-FN1(P2)(Def Plan) 'Peas 17853.29 17848.77 17820. 5410.47 400.36 400.36 MinPt-O-SF 17849. 17844.7 17816. 5378.20 437.76 437.76 MinPts 17849. 17844.7 17816A5 5372.41 439.05 439.05 MinPt-O-EOU 17848.22 17846.99 17815.41 N/A 0.00 0.00 Surface 17848.2 17845.6 17815.41 13436.301 198.80 198.80 MinPts 1784846 17845.42 17815.65 9830.79 248.80 248.80 MinPt-O-EOU 1 3235.43 2978.77 2852.90 12.83 7 22492.82 3826.45 MinPis SP11-N7(P2)(Def Plan) """��/ Pass AW 17831.711 17827.57 17798.9 6118.65 400.34 400.34 MinPts 3323.81 3126.01 3029.711 17.231 19074.09 3912.05 MinPt-O-SF 3322.45 3124.841 3028.61 17.24 19095.88 3912.04 MinPts 1 3322. 3124.85 3028.63 17.24 19098.08 3912.04 MinPt-CtCt 3449.27 3248.78 3150.7'1M1 19477.24 3905.27 MinPt-O-SF 17837.30 17836.08 1780449 N/A 0.00 0.00 Surface 7127.26 6862.16 6731.25 MBER, 22492.82 3826.45 MinP1A-SF S119-FN2(P2)(Def Plan) Pass 17851 04 17846.50 17818 23 5383 78fi 400.36 400.36 MinPt-O-SF 0 17846.74 17842.191 17813 93 5367.45 439.02 439.02 MinPts ' 17845.68 17844 46 17812 88 N/A 0.00 0.00 Surface ' 17845.6 I 17843 13 17812 88 13430.78 198.80 198.80 MinPts 17845.9 17842.89 17813.13 9808.74 248.80 248.80 MinPt-O-EOU 1 3429 64 3171.15 3044 391 13.511 22492.82 3826.45 MinPts S120-N4(P2)(Def Plan) Pass MEM Mana®1 6181.00 400.34 400.34 MinPts 17846.56 17845.34 17813.75 N/A 0.00 0.00 Surface I 1 2872.981 2660.96 2557.70 13.88 19573.80 3898.71 MinPt-CtCt 2873.02 2660.901 2557.59 13.88 19576.03 3898.56 MinPt-O-EOU I 2873.15 2860.92 2557.57 13.87 19578.30 3898.41 MinPt-O-ADP 2884.61 2670.88 2566.8 13.8 19620.59 3895.54 MinPt-O-SF 3459.77 3195.42 3065.98 13.34 22492.82 382645 MinPt-O-SF Tuvaaq ST 1(Def Survey) Pass ®1 17136 78 17106.69 21445.81 162.14 162.14 MinPts 17139.66 17136.66 17106.84 16087.35 197.17 197.17 MinPt-D-EOU NEM=DM NOM 5554.33 462.86 462.85 MinPts 17141.17 MIME 17108 36 5532.06 464.63 464.62 MinPt-O-EOU 22492.82 3826.45 MinPts Kigun 1(Def Survey) Pass OISMI: 17136 78 17106 69 21445.81 162.14 162.14 MinPts 17139.65 17136.66 17106.84 16087.34 197.17 197.17 MinPt-O-EOU I IIBLIIE EWE MEOW 5554.33 482.86 482.85 MinPts 17141.1 1710836 5532.06 464.63 464.62 MinPt-O-EOU MillIal MECUM®r '-=EU 22492.82 3826.45 MinPts Kigun 1 P87(Def Survey) Pass 013Ellg 17136.78, 17106.6• 21445.81 162.14 162.14 MinPts 17139.65' 17136.66 17106.84 16087.34 197.17 197.17 MinPt-O-EOU 01111EIDENEMINSIIM 5554.33 462.86 482.85 MinPts 17141.1 IaaJ 17108.36 5532.06 464.63 484.62 MinPt-O-EOU 3303.86 NEM=En 22492.82 3826.45 MinPts SP16-FN3(P2)(Def Plan) Pass 17848.39 17843.82 17815.56 5344.67 400.36 400.36 MinPt-O-SF .115= 17839 151 17810.90 5360.48 438.99 438.98 MinPts 17843 711 17839.1 17810.90 5355.24 440.27 44027 MinPt-O-EOU 17842 63 17841.40 17809.82 N/A 0.00 0.00 Surface Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\0P09-S1\OP09-S1\OP09-S1(P3b) 3/30/2011 10:08 AM Page 9 of 12 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct•Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor .1 Major 17842.63 17840.08 17809.82 13423.67 198.80 198.80 MinPts 17842.85 17839.85 17810.04 10051.87 243.80 243.80 MinPt-O-EOU I 3680.73 3437.76 3318.71 15.44 21738.05 3852.57 MinPt-CtCt 3690.76 3433.6 3307.49 14.61 22348.95 3832.05 MinPt-O-EOU 3694.20 3433. 3306.09 14.441 22492.82 3828.45 MinPts SP12-SE3(P2)(Def Plan) Pass 17844.83 17840.24 17812.02 5292.201 400.37 400.37 MinPt-O-SF [117839.311 17834.751 17806.5 5346.68 440.22 440.22 MinPts 17838.21 17836.98 17805.40 N/A 0.00 0.00 Surface 17838.21 17835. 17805. 13413.32 198.80 198.80 MinPts 17838. 17835. 17805.64 10012.01 243.80 243.80 MinPt-O-EOU 3920.53 3698.00 3587.7 17.7 12307.53 3804.57 MinPt-O-SF 3681.44 3487.411 _3392.62 19.40 12786.81 3857.59 MinPt-O-ADP 3679.27 3486.95 3393.07 19.57 12810.62 3859.99 MinPt-O-EOU 3677.59 3488.65 3396.56 19.94 12856.58 3864.55 MinPt-CtCt 3818.9 3569.25 3447.07 15.81 21715.52 3852.97 MinPt-CtC1 3818.96 3569.18 3446.96 15.60 21715.61 3852.97 TO 3763.11''MM Ijjjjj)MI:1 8'.tj 14399.39 3915.42 MinPts 3885.34 3712.73 3629.11 MEE 15836.06 3936.27 Min Pt-O-SF 3890.89 3718.05 3634.31.' 15898.53 3936.38 MinPt-O-SF 3821.92 3571.55 3449.05=RE 21709.63 3853.08 MinPt-O-SF 3819.07 3569. r 15.60 21715.51 3852.97 MinPt-O-ADP MEM=ME illllllllrZ..MIE"=l 8 14383.96 3915.44 MinPts 8113-FN4(P2)(Oaf Plan) Pass 1 1784628 17841.71 17813.4 5319.78 400.36 400.36 MinPt-0-SF 17841.3 17836.81 17808. 5355.72 438.96 438.96 MinPts 178413 17836.81 17808.56 5350.83 440.25 440.25 MinPt-O-EOU 17840.28 17839.05 17807.47 N/A 0.00 0.00 Surface 17840.28 17837.7 17807.4 13418.32 198.80 198.80 MinPts 17840,51 17837.5 17807.70 10031.28 243.80 243.80 MinPt-O-EOU I 3799.83 3563.63 3447.92 16.40 21414.23 3858.35 MinPt-CtCt • 380057 3562.901 3446.56 16.31 21467.00 3857.41 MinPt-O-EOU I 3801.29 3563.1•°J' 344642 16.27 21489.23 3857.01 MinPt-O-ADP 3931.59 3669.86 3541.48 15.291 2249282 3826 45 MinPf-O-SF • • SP10-F1115(P2)(Def Plan) pp Pass 17843.11 17838.50 17810.30 5271.04 400.36 400.36 MInP1-0-SF 11 7837.731 17833.17 17804.92 534268 440.20 440.20 MinPts 17836.62 17835.40 17803.81 N/A 0.00 0.00 Surface 7836.62 17834.0 17803.81 13409.74 198.80 198.80 MinPts • 17836.82 17833. 1780401 10284.27 238.80 238.80 MinPt-O-EOU • L 3987.53 3758.41 3646.19 17.75 21104.28 3863.84 MinPt-CtCt 3988.12 3757.801 3645.00 17.66 21142.53 3863.16 MinPt-O-EOU 3989.00 3757.98 3644.82 17.61 21165.86 3862.75 MinPt-0-ADP • 4303.10 4040.07 3911.021 16.651 22492.82 3826 45 Min Pt-O-SF 5108-FN6(P2)(Def Plan) Peas 17836.31 17831,69 17803 50 � 400.31 400.31 MinPt-O-SF 17835.3 17830.7 1780253 5340.72 419.60 419.60 MinPt-O-EOU 17835. 17830.7 1780253/ 5342.75 420.89 420.89 MinPts 17835.06 17833.83 17802.25 N/A 0.00 0.00 Surface 17831.4 'i 7552.19 298.80 298.80 MinPts ' 17835. c IKE= 17802.45 6444.46 338.80 338.80 MinPt-O-EOU 4002.48 3779.03 3669.67 18.28 20840.86 3867.82 MinPt-CtCt 4003.40 MEM 3666.87 18.08 20907.28 3887.33 MinPt-O-EOU 4003.71 3777.53 3666.79 18.06 2091478 3867.19 MinPt-O-ADP i 4138.76 3898.16 3780.3.M '0 21446.11 3857.78 MinPt-O-SF 4335.44 4083.56 3960.09 MUM 21922.74 3848.62 MinPt-O-SF 4597.00 4332.42 4202.59 17.69 22492.82 3826.45 TD SPO5-FN7(P2)(Def Plen) Pass 17839.00 17834.36 17806 17806.191Mffliel 400.36 400.36 MinPt-O-SF 17833.21 17828.6' 1780040, 5333.29 440.15 440.15 MinPts • 17833.21 17828.8' 1780040 5329.39 441.43 441.43 MinPt-O-EOU 17832.09 17830.86 17799.28 N/A 0.00 0.00 Surface 17832.0 17829.5 17799.2 13399.27 198.80 198.80 MinPts 178322 17829.33 17799.49 10241.20 238.80 238.80 MinPt-O-EOU 1 420180 3986.14 3879.57 19.70 20666.91 3868.34 MinPt-CtCt 4204.97 3984.951 3877.23 19.50 20727.47 3868.16 MinPt-O-EOU 4205.64 3985.06 3877.08 19.45 20742.01 3868.11 MinPt-O-ADP 4334.12 4098.83 3983.59 18.78 21201.18 3862.13 MinPt-O-SF 4431.52 4191.69 4074.20 18 84 21391.22 3858.76 MinPt-O-SF 4721.87 4469.64 4345.93 19.07 21922.31 3841364 MinPt-O-SF 5066.93 4802.15 4672.16 19.47 22492.82 3826.45 TD 5107-SE4(P2)(Def Plan) Pass 17841 58 17836 95 17808.7:MIME 400.36 400.36 MinPt-O-SF 17835 46 17830.8• 17802.6' 5336.68 440.18 440.18 MinPts 17835.46 17830.81 17802.65 5332.58 441.46 441.46 MinPt-O-EOU 17834.34 17833.11 17801.53 N/A 0.00 0.00 Surface 17834.34 17831.7 17801.53 13404.50 198.80 198.80 MinPts 17834.54 17831.58 17801.73 10254.58 238.80 238.80 MinPt-O-EOU 5273.44 5044.14 4929.98.1M212 12229.77 3795.26 MinPt-O-SF • • 4883.51 4692.00® 25 99 12795.66 3858.48 MinPt.O-ADP 4881.37 4691.5 26.23 12816.62 3860.59 MinPt-O-EOU illllllllw�i 4693.32 4602.22 26.76 12859.99 3864.88 MinPt-CtCt MEM 4010.68 3905.28 20.03 20701.91 3868.23 MinPt-CtCt 4227.31 4009.19 3902.34 19.76 20786.14 3867.98 MinPt-O-EOU 4229.07 4009. •illlllllla: 19.64 20826.83 3867.86 MinPt-O-ADP 4232.1' 4009.6. 3900.56 19.38 20908.70 3867,30 MinPts 4362.08 4117.38 3997.50 MEM 21577.30 3855.44 MinPt-O-SF Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP09-S1\0P09-S1\OP09-S1(P3b) 3/30/2011 10:08 AM Page 10 of 12 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 [ Major 4524.17 4274.97 4152.89 1851 21668.09 3853.82 7D 4969.0 4802.0. 4720861 30.581 14420.58 3915.39 MinPts 504580 4877.69 4795 961 30.841 15339.86 3929.46 MinPt-O-SF 4966.11 4799.1 4717.98®1 14382.30 3915.44 MinPts SP04-SE5(P2)(Del Plan) Pass 17832 70 17828.07 17799 8901E1:11g 400.31 400.31 MinPt-O-SF 17831 68 1782711 17798.87 533240 419.58 419.58 MinPt-O-EOU 17831 68 17827.11 17798.871 5335.43 420.87 420.87 MinPts 17831 39 17830.17 17798.58 N/A 0.00 0.00 Surface IMIIIIEE 17827.80 17798.58 7547.33 298.80 298.80 MinPts 17831 60 17827.60 17798.79 6426.29 338.80 338.80 MinPt-O-EOU 5131.99 4886.22 4765.73 21.28 21490.32 3856.99 TD 8207.2.MIME 5963.93 11 14441.98 3915.36 MinPts 6288.55 6123.43 6042.8. 38 98 15340.36 3929.48 MinPt-O-SF 6100.34 5910 36MME 32.61 12784.62 3857.36 MinPt-O-ADP 6098.10. 5909.91 5817.36 32.93 12804.78 3859.40 MinPt-O-EOU 6086. • 5911.79 5821.16 33.81 12845.14 3863.42 MinPt-CtCt =gm 3887.04 20.06 20466.58 3868.93 MinPt-CtCt 4206.47 3990.97 3885.49 19.92 20503.54 3868.82 MinPt-O-EOU 4207.51 3991.17 3885.29 19.85 20522.13 3868.77 MinPt-O-ADP 4312.88 4085.87 3974.781 20810.41 3867.91 MinPt-O-SF 4359.34 4129.14 4016.45, 20910.09 3867.28 MinPt-O-SF IIIIMEAMIEM 5959D8 t�. 14381.71 3915.44 MinPts SP01-SE7(P2)(Def Plan) Pass 17830 41 17825 75 17797.60 5244 40 400.31 400.31 MinPt-O-SF 17829.53 17824.97 17796.73 5330.86 419.57 419.57 MinPts 17829.26 17828.03 17796 45 N/A 0.00 0.00 Surface 17825.67 17796 .5 7544.44 298.80 298.80 MinPts 17829.4 17796.68 6309.88 343.80 343.80 MinPt-O-EOU MEE 4120.61 4021.37 21.76 20118.75 3873.56 MinPt-CtCt 4323.73, 4020.38 21.65 20128.92 3873.40 MinPt-O-EOU 4324.44 4120.26 4020 2, 21.60 20134.50 3873.31 MinPt-O-ADP 4416.77 4201.25 4095.81 IIIIIIIECIE 20267.29 3871.14 MinPt-O-SF 7488.14 7246.83 7127.99 31.49 21325.84 3859.92 TD 8488.70 8300.6•. 0 45.55 12791.32 3858.04 MinPt-O-ADP 8486 06 8300.11 8208.05 46.08 12810.54 3859.98 MinPt-O-EOU 8483 96 8302.29 8212.45 47.21 12848.98 3863.80 MinPt-CtCt 8601.87 O MEM mom 14488.67 3915.30 MinPts 8635.35 8475.66 8397.11 14867.16 3914.80 MinPt-O-SF 7492 681.1121M, ® 21325.82 3859.92 MinPts 5102-SE6(P2)(Def Plan) Pass 1' 17836.60 17831 95 17803 79®J 400.36 400.36 MinPt-O-SF mom �l 17798.29 5329.17 440.12 440.12 MinPts 17829.98 17828.76 17797.18 N/A 0.00 0.00 Surface Emma 17827.' MUTZEI 1339420 19880 19880 MinPts 17830.1:MEM 17797.37 10222.31 238.80 238.80 MinPt-O-EOU MEM 4154.43 4054.79 21.85 20197.05 3872.29 MinPt-CtCt 4357.96 MIME 4054.26 21.79 20204.42 3872.17 MinPt-O-EOU 4358.33 4154.21 "®' 21.76 20208.90 3872.09 MinPt-O-ADP 4439.63 4224.24 4118.82MOM 20390.67 3869.21 MinPt-O-SF 4491.21 4273.07 4166.33=En 20446.83 3868.99 MinPt-O-SF 6407.69 6161.67 6040.78 26.48 21531.02 3856.27 TD 7288.24 7098.4r 7004 38.89 12791.81 3858.07 MinPt-O-ADP 1 , 7285.81• 7097.9. 7005.26 39.30 12811.24 3880.05 MinPt-O-EOU 7099.86 7009.21 40.16 12849.50 3863.85 MinPt-CtCt 7394 03 MaIM=Mk 46.4• 14467.59 3915.33 MinPts 7428 61 7265.50 7185.6 46,49 14861.07 391481 MinPt-O-SF 411.83 6165.81 6044.9., 21531.01 3856.27 MinPts Nikaitchuq 3PB2(Def Survey) ,1:1--x:_ -a,,/3 Paa °I '• 18477 6511 8446 81 379189.17 51.00 51.00 MinPts 18480.4.. 18476.681 18447.61 10130.73 250.80 250.80 MinPt-O-EOU EMIR 18475.91'Manta 5563.73 432.14 432.14 MinPts 18481.1 I 8475.91 18448.34 5557.68 433.21 433.21 MinPt-O-EOU 8005.47 7948.10 70.77 14067.59 3916.17 MinPt-CtCt 8126.72 MIIMI 7948.07 70.75 14067.72 3916.17 MinPt-O-EOU 8126.73 8005.46 IIMIZEZI 70.74 14067.77 3916.17 MinPt-O-ADP 8159.10 8036.65 7978.65, 14073.78 3918.00 MinPt-O-SF 8987.67 8866.78 880899 77.71 1408814 3915.64 TD Nikaitchuq 3P83(Def Survey) Pass 18479.62 18477.6 18446.81 379189.17 51.00 51.00 MinPts 18480.42 18476.68 18447.61 10130.73 250.80 250.80 MInP1-0-EOU Ir V 18481 15 18475.91 18448.341 5563.73 432.14 432.14 MinPts 18481 15 18475.91 18448.34 5557.68 43321 43321 MinPt-O-EOU 9857.09 9750.24 9697.6. 13618.86 3933.31 MinPt-O-SF ■ 1 8126.701 8005.47 7948.10 70 77 14067.59 3916.17 MinPt-CtCt 8126.72 8005.461 7948.07 70.75 14067.72 3916.17 MinPt-O-EOU 8126.73 800546 7948.07 70.74 14067.77 3916.17 MinPt-O-ADP 8159.10 8036.65 7978.65 70.281 14073.78 3916.00 MinPt-O-SF 8987.67 8866.78 8808.99 77.71 14088.14 3915.64 TD Nikaitchuq 3PB1(Def Survey) Pass 18479 62_1847765_15446811 379189.17 51.00 51.00 MinPts 1848042 1847668 1844761 10130.73 250.80 250.80 MinPt-O-EOU 1848115 1847591, 184483 I 5563.73 432.14 432.14 MinPts 18481 15 18475.91 18448.34 5557.68 433.21 433.21 MinPt-O-EOU 8126.70 8005.47 7948.10 70.77 14067.59 3916.17 MinPt-CtCt 8126.72 8005.46 7948.07 70.75 14067.72 3916.17 MinPt-O-EOU 8126.73 8005.48 M3= 70.74 14067.77 391617 MinPt-O-ADP Drilling Office 2.0.930.0 Njkaitchuq\Oliktok Point\OP09-S1\OP09-S1\OP09-S1(P3b) 3/30/2011 10:08 AM Page 11 of 12 I 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 8159.10 8036.65 7978.65 70.28 14073.78 3916.00 Min Pt-O-SF 8987.67 8866.78 8808.99 77.71 14088.14 391564 TD Nikaitchuq 41981(Def Survey) Pass IICESSI 18517 25 18486.41 380621.93 51.00 51.00 MinPts 18519 75 18516.90 18486 94 19811.71 165.92 165.92 MinPt-O-EOU 8521.4. 18516.18 18488.61 5568.28 441.69 441.68 MinPts 18521.4 EI55LES 18488.62 5545.55 443.83 443.83 MinPt-O-EOU 8283.18 8159.14 8100.30 70.33 13971.90 3920.55 MinPt-CtCt 8283 19 4 8100.27 70.32 13972.26 3920.53 MinPt-O-EOU 8283.21 8159.13®" 70.31 13972.38 3920.52 MinPt-O-ADP 8313.21 8188,02 8128.58 69.88 13988.67 3919.56 MinPt-O-SF 9108.90 8986.09 8927.31 77.43 14041.21 3917,07 TD Nrkartchuq 1(Def Survey) Pass 12449.80 12303.12 12230.5•®J 16376.03 3930.35 MinPt-O-SF 13842.64 13684.04 13605.54 88.16 16808.40 393048 TD 8746.38 8623.57 8565.04 MEM 14076.78 3915.92 Min Pt-O-SF 8618.90 8560.44 74.72 14082.05 3915.78 MinPts 9138.1. 9010.3 M:=11_ 7495 14499.92 3915.29 MinPts 9210.48 9081.69 9020.2 MIZE 14571.88 3915.19 Min Pt-O-SF 9224.68 9095.70 9034.1:I- 14585.25 3915.17 MinPt-O-SF 12446.62 12299.96 12227 43,IMarj 16374.60 3930.35 MinPt-O-SF Nikaitchuq 4(Def Survey) _ - , $i � 18517.2 18486.411 380621.93 51.00 51.00 - MinPts 18519.7511MM 18486.94 19811.70 165.92 165.92 MinPt-O-EOU Wan EMIR 1848861 5568.28 441.69 441.68 MinPts 18521.4 MI 18488.62 5545.55 443.83 443.83 MinPt-O-EOU 8325.24 8199.96 8140.46' 69.91 13991.99 3919.37 MinPt-O-SF 8312.33 8187.58 mom 70.14 13996.15 3919.15 MinPt-O-ADP 8312.29 MIMI 8128.37 70.16 13996.61 3919.12 MinPt-O-E00 mom 8187.59 8128.41 70.18 13997.09 3919.10 MinPt-CtCt 8189.53 8130.79 70.71 14013.33 3918.27 MinPt-CtCt =ME INIMEIMMETE 69.79 14485.40 3915.31 MinPts 9813.24 9633.23 9546 00=MS 17310.61 3915.44 MinPt-0-SF Nikaitchuq 3(Def Survey) Pass 18479.62 18477.65 18446 81 379189.17 51.00 51.00 MinPts 18480.42 18476.68 18447.61 10130.73 250.80 250.80 MinPt-O-EOU I 18481.15 18475.91 18448.34 5563.73 432.14 432.14 MinPts 18481.15 18475.91 18448.34 5557.68 433.21 433.21 MinPt-O-EOU 10048.65 9938.54 9884.2.Illllllll 6 13478.27 3924.20 MinPt-O-SF 9857.09 9750.24 9697.6. 93.64 13616.86 3933.31 MinPt-O-SF I 8126.701 8005.47 7948.10 70.77 14067.59 3916.17 MinPt-CtCt 8126.72 8005.461 7948.07 70.75 14067.72 3916.17 MinPt-O-EOU 8126.73 8005.46 7948.07 70.74 14067.77 3916.17 MinPt-O-ADP 8159.10 8036.65 7978.65 70.281 14073.78 3916.00 MinPt-O-SF 8987.67 8866.78 8808.99 77.71 1408514 3915.64 TD Nikaitchuq 2(Def Survey) Pass I 12399.951 12244.541 12168.88 81.92 11957.28 3761.46 MinPts 12400.42 12244.98 12169.32 81.92 11961 06 3761.94 MinPt-O-SF 16253.30 16109.99 16039 221 114.811 12540.18 3831.35 MinPt-O-SF Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP09-S1\0P09-S1\0P09-S1(P3b) 3/30/2011 10:08 AM Page 12 of 12 Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on Well: 0P09-Sl Oriented EOU Dimension Field: Nikaitchuq N NoGo Region Anti-Collision rule used: Structure: Oliktok Point Minor Risk-Separation Factor • = Date: March 30,2011 ir, ■.. 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A 1.11 -;,..A1 imati,....., 140 :61 : 1 iliiii1111g11101110m,../-- 416.... .---"•-4*-,*4 4 Nk ....74.;■4111,40":44,4*k. 200 •-• e.'•00,1%.' =-- .....,•WAIA: 160 190 170 1 Rn Well Ticks Type: MD on OP09-S 1(P3b) I Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=100.00 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 8-3/4" 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 2/25/2011 11:02:00 AM | §/| r// | ! 221 x / ., V " , / \ / _ // / 2 | k§| ■ y\ b3 y@12 ®7¢ @@ b II7)/ | ©®°\§ /3%/ \)\\ /\\\ */\5 �2/5 %\/5 �5k� 1 .i ?\\/& ?9~% /»/® \Z N1— I »\b/ 2\2� 5/g\ »®Lu I 4 \%^4.\ /»\j ��~% %\-\ \ / 2 // \ / -\ 7 7 \ ƒ _ ( | . g & ) ; I «, »/ „H iL ±J �. ■ 7 \ \ k{gƒ \\ � � �\� E j / bCD %f In G) .1 I / I ; . . \ - � - �� — Z la � . $ O � / ® ��y « __ I u I no g I E- 0 CC 4) - 4) + ƒ g 2 in Z r ■■ — e © 0 ._ / 1/ « © 0 • . . �_ « 1- 0 I I- I - - I - CC I- O en - - 1 - 4 . e Lu $3 \ ik 0\ Li' ±E9 \� \ a&\ ` 3 ° ^3@ 1 \(» °° »3 p R a = U N J CC a IIIUII W 0 3 m a IC 45 1111 : .. In d !_ II W d _C.i V Y 1i " i� O, N I III I ®III trill O!I I -I I ?�g W 111 le eznill . F5 FS II ® W—° _ ElZW 4 it ....r 0 ,c. I I n 3� O � Za 1 1.---1- ry %. ='a �7 I— �- ■ a �- N V a Z J _ x O T v Z ANK HilI _ _ . _ _-- Z--- R III I ,� ;►- N U'Oli w Y_ ° U II,A Tr I u_ iY cn cn I IS U n 1. IN .1/i t-,B k O 00 O NiP a I • fliti o: ___ _ -.arc f (0? ., 11, „ el,*\.:it '\ , 1- - ....__ , 0 _ s re'111■ ' •., 4 9 i .&\ f. 1 „Ir e . „vim- m 1� 4 is as rz Y •r nil 2 CI)O O O O J hfl 0 0 0 v) ' 73 d c 5 o 0 0 0 as a a) > c (71 a�y T C 0 4 N V M 0 m t O O- > O r F c0 - U c as >, c >. > Z cc . .C) E E En ili , .: , o z C cc z co r i U a ,CID (13 i s_ Schlumberger CemCAD E* well cementing recommendation for 13.375" Surface Casing Operator : Eni Petroleum Well : OP09-S1 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Jason Brink Location : North Slope-Alaska Proposal No. : Draft v1 (P3b) Service Point : Prudhoe Bay,Alaska Date Prepared : 04/12/2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0093 E-Mail Address : JLong1 @slb.com a 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 : OP09-S1 Schlumbergcr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2331.0 ft BHST : 38 degF Bit Size : 16 in ft (x 1000) psi OD 20.in Q– Gm160ft 1 .< > — — 0 11 5 1.0 1.5 — — — —Pe — — — — `-- Pore• _—Siltstone •� j I I ' • • •Sandstone• • . o_ OD13.4in " " " " " " ' @ 2330ft =Slltstone - •'•':Sandstone• • —_ , o Shale o_ �c Q2250ft Coal , , ,_ Cv1 REM 0 0 co_ Well Lithology Formation Press. Page 2 ap08-slcade v1 4-12-11.cfw;04-13-2011; LoadCase Surface Casing;Version wcscem461_08 Client : Eni Petroleum Well : OP09-S1 Sillier!" String : 11375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 178.9 18.250 Landing Collar MD : 2250.0 ft Casing/liner Shoe MD : 2330.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2330.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 187.4% Mean OH Equivalent Diameter:20.010 in Total OH Volume : 844.4 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 1900.0 16.000 225.0 20.724 2330.0 16.000 35.0 16.822 2331.0 16.000 0.0 16.001 Page 3 op09-sl cade v1 4-12-11 cfw;04-13-2011; LoadCase Surface Casing.Version wcs-cem481_08 Client : Eni Petroleum Well : OPO9-S1 Schim fierier String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 42 deg Max. DLS : 3.756 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 10.0 0.000 400.0 400.0 0.0 10.0 0.000 500.0 500.0 1.8 10.0 1.750 600.0 599.9 3.5 10.0 1.750 700.0 699.5 6.3 10.0 2.750 708.0 707.5 6.5 10.0 2.733 800.0 798.6 9.0 10.0 2.751 900.0 897.0 11.8 10.0 2.750 966.6 961.9 13.6 10.0 2.749 1000.0 994.3 14.5 10.0 2.751 1100.0 1090.5 17.3 10.0 2.750 1200.0 1185.3 20.0 10.0 2.750 1244.9 1227.3 21.2 10.0 2.739 1300.0 1278.4 22.8 10.0 2.759 1380.7 1352.2 25.0 10.0 2.751 1400.0 1369.7 25.1 10.0 0.518 1500.0 1460.1 25.6 10.0 0.500 1600.0 1550.1 26.1 10.0 0.500 1700.0 1639.7 26.6 10.0 0.500 1763.2 1696.2 26.9 10.0 0.490 1800.0 1729.0 27.1 10.0 0.517 1900.0 1817.8 27.6 10.0 0.500 1938.8 1852.2 27.8 10.0 0.489 2000.0 1905.7 30.0 9.4 3.753 2100.0 1990.6 33.8 8.7 3.753 2147.5 2029.7 35.5 8.4 3.746 2200.0 2071.9 37.5 8.0 3.749 2300.0 2149.2 41.2 7.5 3.746 2331.0 2172.3 42.4 7.3 3.756 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 708.0 11.10 8.43 SV-4 Siltstone 967.0 11.20 8.43 SV-3 Sandstone 1245.0 11.50 8.43 SV-2 Siltstone 1763.0 11.80 8.43 SV-1 Sandstone 1900.0 12.00 8.43 Permafrost Base Shale 2147.0 12.30 8.43 Ugnu Top(UG4) Coal 2331.0 12.50 8.43 TD Shale Page 4 1 op09-s1cade v14-12-11.cfw;04-13-2011; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 ScIokerger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 60 0.0 1900.0 1817.8 32 -1.5 2321.2 2165.0 38 -1.0 2321.3 2165.1 38 -1.0 2331.0 2172.3 38 -1.0 ft degF O 30 35 40 45 50 55 60 65 70 75 80 85 - Geoth.Profile - Tubular Fluids - Annulus O O- u 8_ O O u7— S_ N 8 U) N- Temp. Profile At 179 min Page 5 op09-slcade v1 4-12-11.cfw;04-13-2011; LoadCase Surface Casing;Version wcs-cem461_06 Client : Eni Petroleum Well : OP09-S1 ScIiderger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost and a competent shoe for drilling ahead. Original fluid Mud 9.50 lb/gal k:8.28E-2 Ibf.s^n/ft2 n :0.262 Ty: 0.48 Ibf/100ft2 Displacement Volume 336.9 bbl Total Volume 939.9 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann.Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 Ibf/100ft2 Lead Slurry 430.5 1830.0 0.0 10.70 k:1.07E-1 Ibf.s^n/ft2 n:0.226 Ty:1.09 Ibf/100ft2 12.5 DeepCRETE 72.5 500.0 1830.0 12.50 k:5.75E-3 lbf.s^n/ft2 n:0.890 Ty:14.35 Ibf/100ft2 Mud 336.9 0.0 9.50 k:8.28E-2 lbf.s^n/ft2 n:0.262 Ty:0.48 lbf/100ft2 Static Security Checks Frac 3 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2030 psi at 2250.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 52 ton Page 6 op09-s1cade v1 4-12-11.cfw;04-13-2011; LoadCase Surface Casing,Version wcscenr461_08 Client : Eni Petroleum Well : 0P09-S1 ScMumberger 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 Volume Stage Time Cum.Vol Inj. Comments Rate (bbl) (min) (bbl). Temp. (bbl/min) (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 7-Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4-Drop Bottom Plug Lead Slurry 5.0 430.5 86.1 430.5 80 13-Start Mixing Lead Slurry 12.5 DeepCRETE 4.0 72.5 18.1 72.5 80 16-Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.5 336.9 39.6 336.9 80 49-Rig Pumps To Displace Shut-In 0.0 0.0 5.0 0.0 80 Static period after Placement Total 02:53 hr:mn 939.9 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 0 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2030 psi at 2250.0 ft Burst 4806 psi at 0.0 ft Temperature Results BHCT 59 degF Simulated Max HCT 73 degF Simulated BHCT 73 degF Max HCT Depth 2330.0 ft CT at TOC 66 degF Max HCT Time 02:53:51 hr:mn:sc Static temperatures: At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 66 degF 60 degF Bottom Hole (degF) 73 degF 38 degF Page 7 op09-s1 cade v1 4-12-11 cfw,04-13-2011, LoadCase Surface Casing,Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 Still/eller String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing * CemCADE Client : Eni Petroleum Well :0P09-S1 String : 13.375"Surface Casing District :Prudhoe Bay,Alaska Country :USA ft lb/gal o < 8 9 10 1I1 1I2 1I3 — Hydrostatic -Mn.Hydrostatic 1 -Max.Dynamic -Mn.Dynanic -Frac O — Pore O- u) - Si 0 _ 0_ u O 3 i0 0 c O in U ie t N _ 0 3 8- N R 0• 0 N CV— 4 3 Fluid Sequence Dynamic Well Security 8. ■MUDPUSH II 100.0 bbl 10.10 lb/gal Herschel:k=2.54E-2 Ibf.s^n/ft2 n=0.420 Ty=13.04 lbf/100ft2 0 3 Lead Slurry 430.5 bbl 10.70 lb/gal Herschel:k=1.07E-1 Ibf.s^n/ft2 n=0.226 Ty=1.09 lbf/100ft2 ■12.5 DeepCRETE 72.5 bbl 12.50 lb/gal Herschel:k=5.75E-3 Ibf.s^n/ft2 n=0.890 Ty=14.35 Ibf/100ft2 ■Mud 336.9 bbl 9.50 lb/gal Herschel:k=8.28E-2 Ibf.s^n/ft2 n=0.262 Ty=0.48 Ibf/100ft2 Total Depth = 2331.0 ft Top of Cement= 0.0 ft *Mark of Schlumberger SchI.ntetiger Page 8 op09-sl cade v1 4-12-11 cfw,04-13-2011: LoadCase Surface Casing,Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 Sihmkerier String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing ECD Profile at the shoe: o Depth= 2330 ft c4 N ' O Hydrostatic N- Dynamic Frac Pore u7 O i I of to � I 06- W 0 20 40 60 80 100 120 140 160 180 200 Time(min) ECD Profile at the previous shoe: Depth= 160 ft Fluids at 2330 ft CO d- I ✓ ' d- I Hydrostatic oj- -Dynamic -Frac •Pore CO od- odd 0 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 9 op09-slcade v1 4-12-11.cfw,04-13-2011 LoadCase Surface Casing,Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 Scilekerger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Temperature model: o -First Sack Depth -First Sack Temp. _N Last Sack Temp. O -Last Sack Depth O - r:0 O co N mi co O N --T -- N 0 20 40 60 80 100 120 140 160 180 200 Time(min) Surface pressure model: Cale.Pump Press. Cale.WI-P P 8-� 8-jam\ 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 10 op09-sicadevl 4-12-11 cfw,04-13-2011, LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OPO9-S1 Scilimierger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Anticipated rate of returns: Fluids at 2330 ft -0 Out — -- -QIn CO- ao c m gv ch- N- T T —T- 0 20 40 60 80 100 120 140 160 180 200 Time (min) Anullar velocity: Depth= 2330 ft_ -- ----_ Annular Velocity s- 8- 18 0 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 11 op09-s1cade v1 4-12-11.cfw;04-13-2011; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 Schloberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo. Model : HERSCHEL_B. k :8.28E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.262 Ty :0.48 lbf/100ft2 Gel Strength :6.40 lbf/100ft2 MUD Mud Type :WBM Job volume :336.9 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :0.0% Water :96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.420 Ty : 13.04 lbf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No:3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k : 1.07E-1 lbf.s^n/ft2 At temp. : 74 degF n :0.226 Ty : 1.09 lbf/100ft2 Gel Strength : 14.25 Ibf/100ft2 DESIGN BLEND SLURRY Name : B809(100 lb Mix Fluid : 10.367 gal/sk Job volume :430.5 bbl Dry Density : 106.26 lb/ft3 Yield :2.33 ft3/sk Quantity : 1038.74 sk Sack Weight : 100 lbs Solid Fraction :40.4% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 10.367 gal/sk Page 12 op09-s1cade v14-12-11.cfw;04-13-2011 LoadCase Surface Casing;Version wcs-cem481_08 Client : Eni Petroleum Well : OP09-S1 Schlobergcr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing 12.5 DeepCRETE DESIGN Fluid No:6 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k :5.75E-3 Ibf.s^n/ft2 At temp. : 74 degF n :0.890 Ty : 14.351bf/100ft2 Gel Strength :49.10 lbf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid :5.175 gal/sk Job volume :72.5 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity :264.73 sk Sack Weight : 100 lbs Solid Fraction :55:0% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.175 gal/sk Additives Code Conc. Function D046 0.129%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling Fluids rheological profile comparison: Annulus ID: 13.375 in Flow Rate : 8.5 bbl/min U, 12.5 DeepCRETE Lead Slurry O_- MUDPUSHII - Mud u, co 0 O 0 1 L— N 8 u, c vT •c M O M I I I I I I I i I I I 15.9 16.0 16.1 16.2 16.3 16.4 16.5 16.6 16.7 16.8 16.9 17.0 17.1 Annulus OD (in) Page 13 op09-s1 cade v1 4-12-11 cfw;04-13-2011; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 Sithlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2310.0 ft Casing Shoe :2330.0 ft NB of Cent. Used :33 NB of Floating Cent. :33 Centralizer Placement Bottom MD Nbr. Cent.I Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 1970.0 24 1/2 NW-TR-13 3/8-8-TR 3 W304 2.0 1910.0 2330.0 9 1/1 NW-TR-13 3/8-8-TR 3 W304 74.0 2330.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (Ibf) NW-TR-13 3/8-8-TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 ft 0 20_ 40 60 8 0 100 O- F .> h I - l T Between Cent. J ` + +At Cent. -I H -1 Fr O ++ a 1+ 1+ ++ 1 1-+ o 1 ++ O -H-ON— I ++ L_- I +1 + 4 O 1r + + + I + + O +i a_ N O O 1,11 N- Well Pipe Standoff Page 14 op09-s1cade v1 4-12-11.cfw,04-13-2011; LoadCase Surface Casing;Version wcscem461_08 Client : Eni Petroleum Well : OP09-S1 Schlumhcrgcr String : 13.375 • District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 6: WELLCLEAN II Simulator ft 60 8 0 o — i i i � � I [ 0 100 Std Betw.Cent. Mud Contarrination - Cement Coverage - Uncontaminated Slurry .- - -� iii- 8 ilS Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall z 1 1 x° 0 0 0 0 200- 200 200- -200 400- '_ 400 400 _ -400 _ 600- 600 600- -600 800- 800 C 800_ _ -800 r-. 1000- 1000 E. 1000- -1000 IL 1200_ 1246 a o 1200_ 1200 a o� 1400- 1400 0 0 1d00- -1400 0 1600- 1600 1600- -1600 1800- 1800 1800- 1_r -1800 2000-1 2000 2000- -2000 2200 r . 2200 2200- -2200 a m e° o a e 0 C 3 0 3 3 0 3 z z = Mud I I Lead Slurry = High r;; Low r--1 12.5 DeepCRETE Iliir..; MUDPUSH II ET Medium 0 None Page 15 op09-slcade v1 4-12-11 cfw,04-13-2011; LoadCase Surface Casing;Version wcs-cem461_08 S Schiumberger CemCAD E* well cementing recommendation for 9-5/8" Intermediate Casing Operator : Eni Petroleum Well : OP09-S1 Country : USA Field : Oliktok Point State : Alaska Prepared for : Mr.Joe Longo Location : Nabors 245E Proposal No. : Draftvl (P3b) Service Point : Prudhoe Bay,Alaska Date Prepared : 04/13/2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0023 E-Mail Address : JLong1©slb.com Q n c ZuATE Disclaimer Notice: This information is presented in good faith,but no warranty is given by and Schiumberger 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 Schiumberger or others is not to be inferred. Mark of Schiumberger Client : Eni Petroleum Well : OP09-S1 S hlumherger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 13459.0 ft BHST : 68 degF Bit Size : 12 1/4 in ft (x 1000) psi OD 20.in 0 2 3 °- @ 160ft -= —Frac - —Siltstone-- r■ —Pore .1 =1111■11111111MIIIMMINI■ °— 0 D 13.4 in :' °o - @ 2330ft :•:•.•:•.•.•:•.•:•:•:•: • -4- - ° - • •Sandstone ° °- ° - _ - 00 9.62 in - - _ _ @13468ft • • • • • • • • • • • • ao - _ ii ,____, _____ o Shale — O-. ° - LC X13378 ft - _ M=EZ —}- - N = 0- -O- O Well Lithology Formation Press. Page 2 op09-s1cade v1 4-12-11.cfw,04-13-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 ScIlillerger 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) 2330.0 13 3/8 68.0 12.415 Landing Collar MD : 13378.4 ft Casing/liner Shoe MD : 13458.4 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread . (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 13458.4 9 5/8 40.0 47.0 8.681 L-80 4760 6870 HYD 523 Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0% Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 1932.7 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 13458.4 12.250 50.0 13.371 13459.0 12.250 0.0 12.250 Max. Deviation Angle : 85 deg Max. DLS : 3.774 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 10.0 0.000 400.0 400.0 0.0 10.0 0.000 1 500.0 500.0 1.8 10.0 1.750 600.0 599.9 3.5 10.0 1.750 700.0 699.5 6.3 10.0 2.750 708.0 707.5 6.5 10.0 2.733 12100.0 3779.5 82.9 328.4 2.999 12200.0 3791.8 83.0 325.3 3.000 12300.0 3803.8 83.2 322.3 3.002 12400.0 3815.6 83.3 319.3 3.004 12403.2 3815.9 83.3 319.2 2.784 12500.0 3827.0 83.5 316.3 3.004 12600.0 3838.0 83.8 313.3 2.999 12700.0 3848.7 84.0 310.3 3.001 12722.7 3851.1 84.0 309.6 2.994 12800.0 3859.0 84.2 307.3 2.995 12900.0 3868.9 84.5 304.3 3.007 12908.4 3869.7 84.5 304.0 2.972 13311.4 3908.3 84.5 304.0 0.000 13334.3 3910.5 84.5 304.0 0.000 13370.8 3914.0 84.5 304.0 0.000 13408.4 3917.6 84.5 304.0 0.000 13411.5 3917.9 84.5 304.0 0.000 13459.0 3922.5 84.5 304.0 0.000 Page 3 op09-slcade v1 4-12-11 cfw;04-13-2011; LoadCase 9-5/8 Intermediate Casing(al:Version wcs-cem481_08 Client : Eni Petroleum Well : 0P09-S1 Srhlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA l.oadcase : 9-5/8 Intermediate Casing(a) Formation Data MD Frac. Pore Name Lithology ___(ft) jib/gal) (lb/gal) _ 708.0 11.00 8.43 SV-4 Siltstone 967.0 11.20 8.43 SV-3 Sandstone 1245.0 11.50 8.43 SV-2 Siltstone 1763.0 11.80 8.43 SV-1 Sandstone 1900.0 12.00 8.43 Permafrost Base Shale 2148.0 12.30 8.43 Ugnu Top(UG4) Coal 2330.0 12.50 8.43 Surf. Csg Shoe Shale 8495.0 12.50 8.43 L Ugnu Sandstone 10825.0 12.50 8.43 Schrader Bluff Shale 11406.0 12.50 8.43 N Seq Top Sandstone 11998.0 12.50 8.43 N Sand Top Sandstone 12402.0 12.50 8.43 N Sand Bottom Sandstone 12722.0 12.50 8.43 N Seq Base Sandstone 13310.0 12.50 8.43 OA Sand Top Shale 13410.0 12.50 8.43 OA Sbl 2 Sandstone 13459.0 12.50 8.43 TD Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 60 0.0 1900.0 1817.8 32 -1.5 2330.0 2171.6 38 -1.0 10340.0 3553.0 61 0.0 13459.0 3922.5 68 0.2 ft degF 0 30 35 40 45 510 55 60 6}5 70 75 80 85 eoth.Profile - Tubular Fluids -Annulus I g 1 1 ii Temp. Profile At 201 min Page 4 op09-slcade v1 4-12-11.cfw;04-13-2011, LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 2: fluid sequence Job Objectives: Zonal Isolation, TOC @ 10,998'(1,000'above the"N"Top) Original fluid Mud 9.30 lb/gal k : 5.97E-3 Ibf.s^n/ft2 n : 0.616 Ty: 8.86 Ibf/100ft2 Displacement Volume 979.4 bbl Total Volume 1261.1 bbl TOC 10998.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 836.6 10161.4 10.50 k:5.23E-2 lbf.s^n/ft2 n:0.324 Ty:12.92 Ibf/100ft2 DeepCRETE 211.7 2460.4 10998.0 12.50 k:1.45E-2 lbf.s^n/ft2 n:0.792 Ty:2.31 lbf/100ft2 Mud 979.4 0.0 9.30 k:5.97E-3 lbf.s^n/ft2 n:0.616 Ty:8.86 lbf/100ft2 Static Security Checks: Frac 361 psi at 2330.0 ft Pore 98 psi at 2330.0 ft Collapse 4522 psi at 13378.4 ft Burst 6870 psi at 0.0 ft Csg.Pump out 77 ton Page 5 op09-s1cade v1 4-12-11 ctw,04-13-2011, LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem481_08 Client : Eni Petroleum Well : OP09-S1 Sd111011Pier String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) CemCADE Client :Eni Petroleum Well :OP09-S1 String :9-5/8"Intermediate Casing District :Prudhoe Bay,Alaska Country :USA ft lb/gal 0 8 9 10 11 12 13 - —Hydrostatic —Mn.Hydrostatic —Max.Dynanic 0 - —Min.Dynamic 0- -Frac N -Fbre 0 - • 8- 8 g 0- 888, f0 • S _ O z 0 _ O- 0 a, 58' 0 _ O- N O it 3 Fluid Sequence Dynamic Well Security s R ■MUDFUSH II 70.0 bbl 10.50 lb/gal Herschel:k=5.23E-2 Ibf.s^n/ft2 n=0.324 Ty=12.92 Ibf/100ft2 a .DeepCRErE 211.7 bbl 12.50 lb/gal Herschel:k=1.45E-2 Ibf.s^n/ft2 n=0.792 Ty=2.31 Ibf/100ft2 ■Mud 979.4 bbl 9.30 lb/gal Herschel:k=5.97E-3 Ibf.s^n/ft2 n=0.616 Ty=8.86 Ibf/100ft2 Total Depth =13459.0 ft Top of Cement=10998.0 ft *Mark of Schlumberger 4ChIipP Page 6 op09-slcade at 4-12-11.clw;04-13-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 70.0 14.0 70.0 80 Spacer Ahead Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 3.0 0.0 80 Begin Mixing Slurry DeepCRETE 5.0 211.7 42.3 211.7 80 Mix&Pump Cement Slurry(3 to 7 BPM) Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.0 979.4 122.4 979.4 80 Kick-Out Plug Pause 0.0 0.0 5.0 0.0 80 Swap to Rig Pumps Pause 0.0 0.0 5.0 0.0 80 Pressure Test Casing Shut-In 0.0 0.0 1.0 0.0 80 Bleed off/Check Floats Total 03:19 hr:mn 1261.1 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 267 psi at 13459.0 ft Pore 98 psi at 2330.0 ft Collapse 4385 psi at 184.5 ft Burst 6410 psi at 0.0 ft Temperature Results BHCT 74 degF Simulated Max HCT 71 degF Simulated BHCT 61 degF Max HCT Depth 0.0 ft CT at TOC 60 degF Max HCT Time 03:09:46 hr:mn:sc Static temperatures : At Time (hr:mn) 00:01 hr:mn Geo.Temp. Top of Cement (degF) 60 degF 63 degF Bottom Hole (degF) 61 degF 68 degF Page 7 op09-sl cade v1 4-12-11.cfw.04-13-2011: LoadCase 9-5/8 Intermediate Casing lal:Version wcs-cem481_08 Client : Eni Petroleum Well : OP09-S1 Sinner String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) ECD Simulation at casing shoe: O _Depth= 13458 ft to N- O Hydrostatic I' N Dynamic -Frac -Pore O e of- O OS- cd- o 0 30 60 90 120 150 180 210 Time(min) ECD Simulation at previous casing shoe: O Depth= 2331 ft Fluids at 13458 ft to { Hydrostatic V- Dynarric -Frac In -Fore O d- of- I— O or O 0 30 60 90 120 150 180 210 Time(min) Page 8 op09-s1cade v14-12-11.ctw;04-13-2011; LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem481_08 Client : Eni Petroleum Well : OP09-S1 Schlmierier String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Temperature Model: 0 First Sack Depth •First Sack Temp. N -Last Sack Temp. r f�pp I Last Sack Depth Imo- 1 liooio. ry cp— if Iffi cO t x $- . 0 NN _N T--T-- r O 20 40 60 80 100 120 140 160 180 200 220 Time (min) Estimated surface pressures: Cale.Pump Press. Calc.WHP 7 Q p__. , 7 — 17 _\ 8- 0 O 30 60 90 120 150 180 210 Time(min) Page 9 op09-sl cade v1 4-12-11.cfw,04-13-2011- LoadCase 9-5/8 Intermediate Casing lal:Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 Siloberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Returns rate: Fluids at 13458 ft Q Out CO r- co- - N- - O O 30 60 90 120 150 180 210 Time (min) Anullar velocity: Depth= 13458 ft Annular Velocity s- O 0 30 60 90 120 150 180 210 Time(min) Page 10 op09-sl cade v1 4-12-11.cfw,04-13-2011, LoadCase 9-5/8 Intermediate Casing(al:Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 Sinner String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.30 lb/gal Rheo.Model : HERSCHEL_B. k :5.97E-3 Ibf.s^n/ft2 At temp. :80 degF n :0.616 Ty :8.861bf/100ft2 Gel Strength :32.02 Ibf/100ft2 MUD Mud Type :WBM Job volume :979.4 bbl Water Type : Fresh VOLUME FRACTION Solids :6.0% Oil : 1.0% Water :93.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k :5.23E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.324 Ty : 12.921bf/100ft2 Gel Strength :40.56 Ibf/100ft2 Job volume :70.0 bbl DeepCRETE DESIGN Fluid No:7 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 1.45E-2 lbf.s^n/ft2 At temp. :68 degF n :0.792 Ty :2.31 lbf/100ft2 Gel Strength :21.02 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid :5.180 gal/sk Job volume :211.7 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity :772.74 sk Sack Weight : 100 lbs Solid Fraction :55.0% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.160 gal/sk Additives Code Conc. Function D167 0.250%BWOB Fluid loss D046 0.129%BWOB Antifoam D065 0.250%BWOB Dispersant D153 0.100%BWOB Antisettling D110 0.020 gal/sk blend Retarder Page 11 op09-slcade vt 4-12-11.cfw,04-13-2011, LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 ScIleherger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Annulus ID: 9.625 in Flow Rate: 10.0 bbl/min O N — DeepCRETE — MUDPUSH II —Mud 8- 0 u_ O N— I 1 I I 12.2 12.3 12.4 12.5 12.6 12.7 12.8 12.9 13.0 13.1 13.2 13.3 Annulus OD (in) Fluid rheological Modeling: Annulus ID: 9.625 in-OD: 12.250 in DeepCREfE - MUDPUSH N - Mud 8- W- g 6 8- - 3.9 4.2 4.5 4.8 5.1 5.4 5.7 6.0 6.3 6.6 6.9 7.2 7.5 7.8 8.1 Flow Rate (bbVmin) Page 12 op09-slcade v1 4-12-11.cfw;04-13-2011; LoadCase 9-5/8 Intermediate Casing la);Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 Schlumbcrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 5: centralizer placement Top of centralization :7286.0 ft Bottom Cent. MD :13438.4 ft Casing Shoe :13458.4 ft NB of Cent. Used :35 NB of Floating Cent. :35 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 11498.4 0 0/0 0.0 11516.2 12418.4 23 1/1 HYDROFORM HFD 0.0 12401.1 12978.4 0 0/0 0.0 12418.4 13458.4 12 1/1 HYDROFORM HFD 0.0 12995.7 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) HYDROFORM HFD 9 5/8 12.250 12.250 Yes Weatherford(1 N.A. N.A. N.A. ft 0 20 60 80 100 > — — Between Cent. 40 6 O + +At Cent. O— _ f 8 N r - — N O- M r - CO - • Well Pipe Standoff Page 13 op09-s1 cade v1 4-12-11.cfw.04-13-2011: LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S1 Sdllmberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 6: WELLCLEAN II Simulator 0, ok ft 0 20 40 60 80 100 0 20 40 60 80 100 _ — Std Betw.Cent. -Mud Contamination g — Cement Coverage - Uncontaminated Slurry O— g� - 1�- 1 '-'->„,.... ... 1F .0,-- 1 ____________,R - 0'S _ Cement Coverage Uncontaminated Slurry Fluids Concentratiog nns Risk Mud on the Wall soon a000 8000-. -8000 9000 9000 9000 i -9000 10000 10000 E 10000 -10000 4 ::.47 x a - n is 11000 ',',,A I; 11000 $ o° 11000 I s ' -11000 0 12000 1516e, 12000 12000 1 -12000 :t J 13000 . -. 13000 13000 -13000 1 1 I `0 0 z z MI Mud = High f'' I Low = DeepCRETE I I Medium I I None MI MUDPUSHII Page 14 op09-slcade v1 4-12-11.cfw;04-13-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461_08 S P E O IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. Eri E&P Division REVISION STAP-P-1-M-6140 0 11 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) ND = True Vertical Depth (m) MW = Actual Mud Weight(kg/I). INS ENI S.p.A. S P E O IDENTIFICATION CODE PAG 207 OF 338 E&P Division REVISION STAP-P-1-M-6140 0 11 1 1 1 1 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. S P E O IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. Eril E&P Division REVISION STAP-P-1-M-6140 0 1 1 I 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. III III r.,_ thol ENI S.p.A. S P E O IDENTIFICATION CODE PAG 209 OF 338 Ern E&P Division REVISION STAP-P-1-M-6140 0 1 I 1 [1.1 LEAK-OFF TEST REPORT Report N. Date: WELL NAME: WELL CODE: l CONTRACTOR: RIG NPME: RIG CODE: Open hole depth(m): 825 Mud Twe: FWG EL Rig twe: J.UPs Hole Dameter(in): 1T1/4 Weight(KgA): 1.3 R.K.B.elevation(m): 28 Last Cog.Shoe(m): 797 Marsh\Ascosity(seclot): 44 Water Depth(m): 24 Cog.diameter On): 13'3/8 P.V.(cps): 19 Pumps: 12-P-160 Grade: J.55 Y.P.06/100 fe): 5 Liners On): 8.5" Weight(1b/t): 61 Gels(lb/100 t': 2/B Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(0c130 min): 10.5 ..... Litholog y Shale Expected EMW 1.68 Kg/cm2I10 m Time Volume Pressure Time Volume Pressure Time Vdume Pressure [min) (bd) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 0.50 100 95 2 480 3 0.75 200 10 2 470 4 100 300 10.5 2 483 5 125 400 11 2 465 6 ISO 500 11.5 2 460 7 1.75 570 12 2 446 8 200 600 13 2 440 8 2D0 550 14 2 437 8.5 200 505 15 2 435 Nde: Pumped with a constant low rate of(b bl): Ublume pumped(bbl): Wlume returned(bbl): (psi) 1000 900 800 stop pump P 700 r e 600 shut in curve S 500 ' S +—�_. �v • ..__. U 400 r 18 m inut es e 300 • 200 100 - 0 . • . . . . 0 0,25 0,5 0,75 1 1,25 1,5 1,75 Z 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(1314 11 I Time mins RESULTS:(Press.,, +Press.LO.)x10/Depth=[(1.3 x 797/10)+(430 x 0.07)]x 10/797=1.68(Kg/cm2/10 m) Note: Company Reeresentatiie 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 OI iktok OLIKTOK 5 Point INTAKE DOCK OPP • IN THIS Sb I MODULE et PR6 P� �5 SURVEY _O t :i\ �`v�r� ,1�, DS-3R DEW UNE('� SITE STP .s— , OUKTOK PDII■1 MODULES _ N 1C STAGING AREA', T13N, R9E DS-3Q 18 Z)://1 71.:1 .1 : , i5 SCALE: .`� 1" = 150' � 4-130 4 21N AU, S TP PAD \ VICINITY MAP oo �� SCALE: 1" = 1 Mile O°off°o `, 0 O090 �0� \ o°-o °X0'7' \. r'prz Ooo°-o o ° 0 \\„\\ O9'o 00, OS \0O � 00 i900 0 -13 ` 1 \ o O0O 0 --lt, 1J \ _ - < LA \ ` OLIKTOK ` \ °'0 POINT PAD ,\ \ ,..s \ 0 1 / 9Av \ ' / \ \\ SEE SHEET 3 FOR NOTES / \ \ o Existing Conductor LOUNSBURY f & ASSOCIATES, INC. • Conductor Asbuilt this survey / SURVEYORS ENGINEERS PLANNERS i AREA: MODULE: UNIT:• frAliS— Eno Petroleum OLIKTOK COUNT PAD Eli ` ASBUILT LOCATIONS CAD LK680D1 10/9/08 DRAWING NO: NSK 6.80—d1 I PART: 1 OF 3 I REV: 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-12 6,036,328.85 1,656,784.83 70°30'38.977" 149°51'57.795" 2,056 1,526 12.2 4.0 0P03-P05 6,036,325.10 1,656,777.76 70°30'38.940" 149°51'58.004" 2,059 1,533 12.2 4.0 OPO4-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 • AK STATE PLANE (NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD 0.G. WELL NO. 'y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. ° OP25 6,036,004.35 1,656,510.91 70°30'35.791" 149°52'05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70°30'35.867" 149°52'05.456" 2,372 1,787 12.2 -2.7 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS i AREA: MODULE: UNIT: Eno 'r etirolleunmi WELL CONDUCTOR D CI�II ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK68001 10/9/08 NSK 6.80-di 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 0P26 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. _��P7� OF q�s+.i SURVEYOR'S CERTIFICATE „ • • • �1 ■�•'% ,L., I HEREBY CER71FY THAT I AM PROPERLY • �`h /\ REGISTERED AND LICENSED TO PRACTICE 0 v7 1 •,• LAND SURVEYING IN THE STATE OF 0 J Ro0KU5 o r ALASKA AND THAT THIS PLAT REPRESENTS ■ : a -iP LS-803 0• A'i A SURVEY DONE BY ME OR UNDER MY 4��F •. . J�,, DIRECT SUPERVISION AND THAT ALL S+4'<`p..'•,tI A.3 AV p`'i D CORRECT ASAOFF EDR E T2A3IL, 2008. ,+,,11111"`‘O6 ♦•♦ 0 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS Z AREA: MODULE: UNIT: tra Enil eZiroIIeui WELLOCONDUCTOR D " Enil ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-di 3 OF 3 2 TRANSMITTAL LETTER CHECKLIST WELL NAME ,ka(i4 4 OF0 5/ PTD# 2/ 0 Development Service Exploratory Strati ra hic Test Non-C nventional Well FIELD: /, / 4. POOL: / f-e .(4 Qr Circle Appropriate Letter I 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 Li E To u m O n toN a) o o m .0 5 c (0 Q O a) o co c J o N O C E _c N 0 u To N M n co L cD -O E O E co o N = = 0) w o C C 3 E a o O n J w 0 C O. a o n m E O ° < a°) 2 C v o m V c X O O d) r co o o O 4) C.) 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To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. voki eni EnO Petirolleuim FINAL WELL REPORT MUDLOGGING DATA NIKAITCHUQ OP09-S1 OLIKTOK POINT, ALASKA • -F1 3 Al 9 a,.re 1r' i —1liiig!! CANRIG 1)KII.LI\G Tr:cti' 1.1x, Lru. Approved by: Andrew Buchanan Compiled by: Emil Opitz Lees F. Browne Zach Beekman Steven Pike Distribution: July 27, 2011 Date: July 10, 2011 9jf— ci eni Enil Petroleum OP09-S1 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/ Lateral Section 9 3.3 Lithologic Descriptions/Stratigraphy 10 3.4 Connection Gas Summary 44 3.5 Trip/Wiper Gas Summary 44 3.6 Sampling Program and Sample Dispatch 45 4 PRESSURE AND FORMATION STRENGTH DATA 46 4.1 Pore Pressure Gradient Evaluation 46 4.2 Quantitative Methods 46 5 DRILLING DATA 47 5.1 Daily Activity Summary 47 5.2 Survey Data 50 5.3 Bit Record 56 5.4 Mud Record: Surface and Intermediate Hole 57 5.5 Mud Record: Production Hole 58 6 DAILY REPORTS 59 Enclosures 2" : 100' Formation Log (MD and TVD) 2" : 100' Gas Ratio Log (MD) 2" : 100' LWD Combo Log (MD and TVD) 2" : 100' Drilling Dynamics Log (MD) Final Well Data on CD/ROM 2 CANRIG IJaii.i.ic T;<;Hnn n:r I.i i. ryi eni Eni Petroleum OP09-S1 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type/Position Downtime Comments (hours) Casing Pressure Cable to 1502 transducer, 0 for BOP tests only. Driller's Console Azonics 0 Pitwatcher's Console Azonics 0 Computer for RigWatch Remote, HP Compaq 0 Company Man, camp (wireless connection) Computer for Company RigWatch Remote, HP Compaq 0 Man/Toolpusher, office (wireless connection) Computer for RigWatch Remote, HP Compaq 0 Mud Engineer Computers for RigWatch Remote, Cybernet, 0 Toolpusher(2) and RigReport, HP Compaq Computers for Mudlog compilation and editing, Mudloggers (3) RigWatch Master, & RigWatch 0 Remote, all HP Compaq QGM Gas Trap gas (mounted in possum belly), 6/16—Change Out QGM as Ditch Flame Ionization Detector(FID) 4 Total Gas and Chromatography. Hook Load/Weight on bit Drilling line sensor on rig floor 0 Mud Flow In Derived from pump rate&output 0 Mud Flow Out Flow line Sensor 0 Pit Volumes, Gain/Loss 10 radar pit sensors 0 Pump Pressure Standpipe Transducer 0 Pump stroke counters (3) 2 proximity sensors 0 Rate of penetration Drawworks Encoder 0 RPM PLC feed 0 Torque PLC feed 0 Wits In (LWD Data) LWD Computer to RigWatch 0 Master Computer 3 C:ANRIG frOi en; Enl Petroleum OP09-S1 1.2 Crew Unit Number: ML059 Unit Type: Arctic/Steel Mudloggers Years of Days at Sample Days at Technician Days at Experience OP09-S1 Catchers OP09-S1 OP09-S1 Steven Pike 10 30 Dean Kekaualua 26 Emil Opitz 4 21 Debbie Bomar 22 Zach Beekman 3 21 Steve Franzen 5 Lees F. Browne 30 11 4 CANRIG O elni Eni Petroleum OP09-S1 2 WELL DETAILS 2.1 Well Summary Well: Nikaitchuq OP 09-S1 API Index#: 50-029-23448-00-00 Field: Nikaitchuq Surface Co-Ordinates: 3,194' FSL, 1,583' FEL S5 T13N R9E Umiat Meridian Borough: North Slope Primary Targets: OA Sand of the Schrader Bluff State: Alaska Primary Target Depth: 22,281' MD/-3,774.1' SSTVD Rig Name/Type: NAD 245E/Arctic Triple TD Depth: 22,370' MD/-3,730.6' SSTVD Spud Date: June 13, 2011 Ground Elevation: 12.20'AMSL TD Date: July 11, 2011 RT Elevation: RKB @ 53.40'AMSL Days Drilling: 32 TD Formation: Schrader Bluff OA Sand Classification: Producer 2.2 Hole Data Maximum Depth Mud Shoe Depth Hole MD TVD TD Weight Dev. Casing/ MD TVD FIT Section (ft) (ft) Formation (ppg) ( inc) Liner (ft) (ft) (PPM Conductor 160 160 Recent N/A 0 20" 160 160 N/A 16" Surface 2340 2177 Ugnu 9.2+ 40.2 133/" 2325 2177 11.7 12W Schrader Intermediate 13220 3931 Bluff, OA 9.4 85.84 9%" 13195 3928 13.0 Sand 8%" Schrader Production 22370 3731 Bluff, OA 9.4 99.4 5W 21740 3868 N/A Sand 5 C:ANRIG eni EnII Petroleum OP09-S1 2.3 Well Synopsis The OP09-S1 well was spudded on the 13th of June 2011, entering a pre-set conductor pipe at a depth of 160'. New 16"hole was drilled to a depth of 2340' MD/2170.2'TVD/-2116.8'TVDSS. 13%", 681b/ft L-80 surface casing was set at 2325' MD/2159.1'TVD/-2105.7'TVDSS. The float equipment and shoe were drilled out and 20'of new hole was drilled to 2360' MD. A Leak Off Test(LOT)was performed to an EMW of 11.4 ppg. The intermediate section was drilled with a hole diameter of 12W. At 9120' MD it was decided to trip out of the hole to put on a new bit. A similar BHA and drill bit assembly was put back in the hole to finish drilling the intermediate section. After drilling 38' MD in 19.5 hours to a depth of 9158' MD, another bit trip was performed. A 3rd bit for the intermediate section was put on with a similar BHA and drilling was resumed. The intermediate section was drilled to a depth of 13220' MD. The hole was back-reamed to the existing casing shoe and circulated clean. After laying down the drilling assembly, 9%", 40 lb/ft L-80 Hydril 563 casing was floated in dry and set at 13195' MD/3928.8'TVD/-3875.4'TVDSS. An 83/4"bit and a drilling assembly were picked up and run in to the intermediate casing shoe. The casing shoe was drilled out with 20'of additional new hole to 13240' MD where a Formation Integrity Test (FIT) was performed yielding a 13.0 ppg EMW. Rotary drilling was resumed using an 83/4" PDC bit, and the borehole was extended to TD at 22370' MD/ 3784.0' TVD/-3730.6'TVDSS. TD was reached on July 10, 2011. Production liner was set at 21740' MD/ 3868'TVD/-3814.6' TVDSS. 6 CANRIG rAis eni Eni Petroleum OP09-S1 3 GEOLOGICAL DATA 3.1 Target and Offset Well Data OP09-S1 Reference Wells Prognosis(WP5) Zone/Horizon OPO4-07 OP08-04 OP26-DSPO2 TVDSS TVDSS TVDSS TVDSS MD SV-4 -659.8 -660 -659.1 -655.3 708 SV-3 -911.5 -913 -902.8 -910.4 967.2 SV-2 -1.175.5 -1.177 -1,163.2 -1,174.3 1,243.5 SV-1 -1,632.1 -1.639 -1,648.1 -1,644.7 1,760.0 Permafrost Base -1.722.1 -1725 — -1,725.0 — Uanu Top(UG4) -1.967.9 -1.969 -1.957.2 -1,978.2 2,140.9 13%"SCP — — — -2,120.0 2,321 UG-2 Coal Bed Marker -2.473.4 -2.465 -2.428.2 -2,481.9 2,921.1 L Uanu -3.198.7 -3,120 -3.122.5 -3,258.8 8,319.7 Schrader Bluff -3.516.4 -3.316 -3,325.0 -3,259.4 8,323.8 N Seauence Top -3.569.2 -3.362 — -3,551.9 10,468.2 N Sand Top -3,613.9 -3,407 -3.382.6 -3,617.6 10,954.0 N Sand Bottom -3,628.0 -3.550 -3.423.3 -3,690.5 11,516.0 N Seauence Base -3.705.5 - — -3,752.7 12,034.7 OA Sand Top -3.779.7 -3,575 -3.536.4 -3,791.7 12,393.2 0A2 -3.793.4 - — -3,852.5 13,019.1 9%" ICP -3.504.0 -3,576 — -3,862.7 13,125.5 Fault 1 — — — - - Total Depth -3,469.0 — -3,774.1 22,371 7 CANRIG eni Erd Petroleum 0P09-S1 3.2 Formation Tops: 3.2.1 Surface and Intermediate Section Zone or Horizon Depth (ft) Prognosed Depth (ft) MD ND TVDSS MD TVDSS 20"Conductor Shoe 160.0 160.0 -106.6 160.0 -106.8 SV-4 718.0 717.5 -664.1 708.0 -655.3 SV-3 978.0 972.1 -918.7 967.3 -910.4 SV-2 1,253.0 1,230.3 -1,176.9 1,243.5 -1,174.3 SV-1 1,802.0 1,727.6 -1,674.2 1,759.9 -1,644.7 Permafrost Base 1,852.0 1,772.3 -1,718.9 1,850.0 -1,725.0 Ugnu Top (UG4) 2,142.0 2,017.7 -1,964.3 2,140.9 -1,978.2 13 3/8" Casing Shoe 2,325.0 2,159.1 -2,105.7 2,321.0 -2,120.0 TD 16" Borehole 2,340.0 2,170.2 -2,116.8 2,321.0 -2,120.0 UG-2 Coal Bed Marker 2,962.0 2,524.2 -2,470.8 2,921.1 -2,481.9 Lower Ugnu 8,465.0 3,337.9 -3,284.5 8,319.5 -3,258.8 Schrader Bluff 10,643.0 3,626.7 -3,573.3 10,467.1 -3,551.9 N Sequence Top 11,092.0 3,692.1 -3,638.7 10,952.9 -3,617.6 N-1 11,615.0 3,755.8 -3,702.4 11,514.0 -3,690.5 N-2 11,679.0 3,764.6 -3,711.2 n/a n/a N-3 11,867.0 3,786.8 -3,733.4 n/a n/a N-Sand Bottom 12,017.0 3,804.0 -3,750.6 12,033.0 -3,752.7 Lower N Marker 12,440.0 3,849.3 -3,795.9 n/a n/a N Sequence Base 12,560.0 3,862.0 -3,808.6 12,392.0 -3,790.6 Fault#1 12,732.0 3,879.9 -3,826.5 12,400.0 -3,791.5 OA Sand Top 12,948.0 3,903.7 -3,850.3 13,017.0 -3,852.5 OA sb12 13,054.0 3,915.2 -3,861.8 13,123.6 -3,862.7 OA sbl3 13,106.0 3,920.6 -3,867.2 n/a n/a 9 5/8" Casing Shoe 13,195.0 3,928.8 -3,875.4 13,172.5 -3,867.4 TD 12 1/4" Borehole 13,220.0 3,930.2 -3,876.8 13,172.5 -3,867.4 8 C:ANRIG eni Emil Petroleum OP09-S1 3.2.2 Production/Lateral Section Zone or Horizon Depth (ft) Prognosed Depth (ft) MD TVD TVDSS MD TVDSS OA sbl3 14,398.0 3,919.9 -3,866.5 n/a n/a OA sb12 14,547.0 3,914.3 -3,860.9 n/a n/a OA sb12 15,472.0 3,915.5 -3,862.1 n/a n/a OA sbl3 15,841.0 3,923.4 -3,870.0 n/a n/a Fault A 17,010.0 3,922.4 -3,869.0 n/a n/a OA sbl2 17,923.0 3,916.5 -3,863.1 n/a n/a OA sbl3 18,230.0 3,919.3 -3,865.9 n/a n/a OA sb13 19,388.0 3,899.2 -3,845.8 n/a n/a OA sb12 19,692.0 3,884.0 -3,830.6 n/a n/a OA sb12 20,007.0 3,874.4 -3,821.0 n/a n/a OA sbl3 20,245.0 3,879.1 -3,825.7 n/a n/a Fault B (Canning Hue) 21,685.0 3,870.3 -3,816.9 n/a n/a OA Bottom 22,113.0 3,824.0 -3,770.6 n/a n/a OA sbl4 22,182.0 3,813.5 -3,760.1 n/a n/a OA sbl3 22,278.0 3,798.9 -3,745.5 n/a n/a OA sbl2 22,319.0 3,792.3 -3,738.9 n/a n/a TD 8 3/4" Borehole 22,370.0 3,784.0 -3,730.6 22,371.0 -3,774.1 dB 9 C:ANRIG frOt eni €ni Petroleum OP09-S1 3.3 Lithologic Descriptions/Stratigraphy PERMAFROST AND RECENT/QUATERNARY DEPOSITS SURFACE TO 2142.0'MD/-1964.3'TVDSS Samples were not collected and lithologies were not logged in the surface hole. The permafrost sections of correlated wells consist of interbedded sand and clay with sporadic conglomerates. Although no oil shows were seen, some minor gas hydrates were encountered. This interval extends from surface down to the top of the Ugnu at 2142.0'MD/-1964.3 TVDSS 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 conglomeratic 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 436 28 142 5 0 1 PEAKS Depth TG C1 C2 C3 C4l C4N C5l C5N 1803 5 917 34 15 SV-4 718.0MD/-664.1' TVDSS SV-3 978.0' MD/-918.7' TVDSS SV-2 1253.0' MD/-1176.9' TVDSS SV-1 1802.0' MD/-1674.2' TVDSS PERMAFROST BASE 1852.0' MD/-1718.9' TVDSS 10 CANRIG rYI ec u Ed Petroleum OP09-S1 UGNU TOP (UG4)2142.0' MD/-1964.3' TVDSS The Ugnu Formation consists of two units, upper and lower Ugnu. The upper portion of the formation is essentially similar in nature and appearance to the overlying material. However, the sands are generally finer grained and exhibit slightly greater wear through transport/erosion. The section consists primarily of thickly bedded sand/sandstone occasionally grading to conglomeratic sandstone and conglomerate. Moderate to thin claystone and siltstone interbeds occur throughout. No unforeseen problems were encountered drilling this section, and no marketable hydrocarbons were found. Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 474 1 216 141 0 29 PEAKS Depth TG C1 C2 C3 C41 C4N C51 C5N 2954 141 27621 102 42 133/8" CASING SHOE 2325.0' MD/-2105.7' TVDSS TD 16" BOREHOLE 2340.0' MD/-2116.8' TVDSS Sand (2390-2480) = predominantly clear to translucent with some white, light gray to dark gray, light greenish gray, pale green, very pale blue, and grayish blue; mostly quartz grain sand matrix, with abundant dark colored lithic fragments throughout; upper very fine to lower medium grain sand; fair to poorly sorted; well rounded to subrounded with some subangular to very angular; moderate sphericity; mostly loose uncemented quartz sand interbedded with thin beds of sandy siltstone; some sand grains appeared to be slightly frosted in places; no visible sample fluorescence was observed; no other petroleum indicators were observed. Siltstone(2480-2550)= dark gray to medium dark gray, with some light gray; mushy to somewhat pasty; mostly brittle to crunchy; irregular fracture; amorphous cuttings habit; earthy to slightly dull luster; very silty texture with some slightly gritty; very thin beds of sandy siltstone interbedded with very thick beds of predominantly loose unconsolidated quartz sand; no visible sample fluorescence was observed. Sand/Sandstone (2550-2660)= clear to translucent with some white, gray, pale blue, and light greenish gray; predominantly quartz grain sand matrix; mostly loose uncemented sand with some very friable siliceous to slightly calcareous cemented sandstone throughout; upper very fine to medium grain with some coarse grains throughout sample interval; subangular to angular to few subrounded grains; moderate to poor sphericity; samples are all abundant with fine to very fine grained black lithics giving a salt and pepper appearance; brilliant green to moderate green to translucent blue green glauconite throughout; >10% pyrite throughout sample, both as crystals and as secondary growth on mineral surfaces; no visible sample fluorescence was observed. Claystone (2660-2710) = brownish gray to grayish brown, and light brown; mushy to very pasty; crumbly; very irregular fracture; amorphous cuttings habit; very dull to earthy luster; predominantly clayey texture with some very gritty to slightly granular in places; very thin beds of sandy silty claystone interbedded with thicker beds of silty quartz sand and sandstone; no visible sample fluorescence. Sand/Sandstone(2710-2830) =white, medium light to light gray with a slight bluish gray secondary hue; formation is firm to hard; sample recovered as unconsolidated or uncemented loose grains with variable amounts of matrix clay residue; poor to moderately sorted; upper fine to medium grain; grading to medium 11 BRIG eat Eli Petroleum 0P09-S1 upper to coarse upper and granule as depth increases; material coarsens with increasing depth; generally angular to sub-angular with trace moderately rounded grains; predominantly translucent to white to clear quartz with abundant dark colored lithic fragments; some frosted grain; common light gray to light blue gray grains trace to common smoky quartz; trace glauconite; trace medium grain brownish chert; no visible sample fluorescence was observed. Siltstone (2830-2900) = dark gray to medium gray with some light brown hues throughout sample interval; soft to easily friable; consistency is generally mushy and pasty to somewhat clumpy; very brittle to crumbly; irregular fracture; amorphous cuttings habit; very dull to earthy luster; mostly clayey texture with some slightly gritty in places; no visible sample fluorescence was observed; no other petroleum indicators were observed. Coal/Carbonaceous Shale{2900-2950)= dark gray brown to black to brown; hard to very firm; splintery to crumbly; silty in part; thinly interbedded with hard brownish black to dark gray black silty carbonaceous shale; coal is poorly developed and retains much of its original lignitic characteristics; trace silty black carbonaceous material. UG-2 COAL BED MARKER 2962.0' MD/-2470.8' TVDSS Sand/Sandstone(2950-3040) = mostly translucent to clear, with white, light gray, light pale green, and pale blue; predominantly quartz sand matrix, with abundant dark colored lithic fragments throughout; upper very fine to lower medium grain sand; fair to poorly sorted; well rounded to subrounded with some subangular to very angular; moderate sphericity; mostly loose uncemented quartz sand interbedded with thin beds of sandy siltstone; some sand grains appeared to be slightly frosted in places; no visible sample fluorescence was observed; no other petroleum indicators were observed. Siltstone/Claystone (3040-3100) = light brownish gray; soft to very soft; dull earthy to gritty luster; irregular fracture; amorphous cuttings habit throughout; very easily washes away in sample preparation slightly to very sandy; tends to contain fine to very fine grain quartz sand; flocculates immediately in hcl; no oil indicators; non to very slightly calcareous. Sand/Sandstone(3100-3235) = clear to translucent with some milky white, light gray, pale blue, moderate blue green, and light greenish gray hues; upper very fine to medium grain sand, with trace of lower to upper coarse; predominantly quartz grain sand matrix, with abundant dark colored lithic fragment throughout; poorly sorted; finer material is dominated by angular to sub-angular smoky quartz and light gray lithics; becoming increasingly silty; trace fine coal clastics; trace micro thin carbonaceous lamina; trace fine flaky fragments of red chalcedony and occasional iron stained light gray quartzite pebble fragments; trace fine white calcite; abundant pyrite, both in crystal form and in secondary growth on mineral surface; very thick sand beds interbedded with thinner beds of sandy siltstones; no visible sample fluorescence was observed; no other petroleum indicators were observed. Siltstone(3235-3310)= medium gray to light gray to dusky brown in some cuttings; samples consist of reworked globular masses containing sand and other accessory mineral grains; grades between clayey siltstone and silty claystone throughout the interval; mushy and pasty consistency; moderately cohesive; slightly adhesive; texture varies between clayey silty to silty and gritty; very thin beds of clayey siltstones interbedded with very thick beds of quartz sand and sandstones; no sample fluorescence was observed. Carbonaceous Shale(3310-3380) = black to brownish black to dusky brown; crumbly to crunchy and brittle; sub blocky fracture; mostly tabular cuttings; dull earthy to slightly waxy greasy luster; matte texture; some thin fissile laminae throughout sample interval of dark to dusky brown; some oxidation has occurred leaving reddish brown to dark brownish red cuttings; interbedded with minor claystones and sands. Sand/Sandstone(3380-3490) = mostly clear to translucent, with some milky white, light gray, pale blue, dark yellowish brown, and light greenish gray hues; predominantly quartz grain sand matrix with abundant dark colored lithic fragments throughout; mostly unconsolidated loose sand with some slightly cemented with siliceous cement matrix; friable to somewhat hard; upper very fine to medium grain sand with some 12 CANING rolik eni Eni Petroleum 0P09-S1 coarse grains intermittent throughout; very angular to subangular with some subrounded to well rounded; moderate to high sphericity; some grains appeared to be slightly polished in places; thick beds of quartz sand and siliceous cemented sandstones interbedded with thin beds of clayey siltstones and sandy claystones; no visible sample fluorescence was observed. Siltstone(3490-3570) = light gray to medium gray to dusky brown, samples consist of mechanically reworked globular masses containing sand and other accessory minerals, cuttings grade between silty claystone and clayey siltstone throughout the sample interval, mushy to pasty consistency, very soft to slightly gelatinous; moderately cohesive, slightly to non adhesive, texture follows makeup of cuttings, varying from silty and clayey to gritty and silty, no visible sample fluorescence; no other petroleum indicators were observed. Sand (3570-3635)=clear to milky white to medium gray to dusky brown, upper fine to upper medium predominate with few lower fine grained, moderately sorted, subrounded to subangular to locally angular grains, low to moderate sphericity, quartz grains vary between transparent to slightly smoky to light gray, trace pyrite, glauconite ranges from very pale green to brilliant green, sample is slightly calcareous; no visible sample fluorescence. Sand (3635-3700) = medium light gray to medium gray to olive gray; medium lower to medium upper with trace fine upper and coarse upper; moderately to moderately well sorted; subrounded to rounded to locally subangular; moderate sphericity; disaggregated; pre-dominantly clear transparent to trans- lucent quartz with trace milky white grains; abundant pale green to grayish green lithics with few brilliant green; sample is slightly calcareous; no oil indicators. Sand (3700-3780) = medium gray to medium light gray to slight olive gray hues; disaggregated quartz sands with trace amounts of slightly silty matrix; lower medium to upper medium grained to scattered upper fine; moderate to moderately well sorted; subrounded to subangular; moderate sphericity; trace very soft to soft grains of sandstone; abundant pale green to grayish green lithics; trace pyrite grains; sample slightly calcareous; no sample fluor-escence or oil indicators. Sand (3780-3850) = medium gray to medium light gray to brownish gray dis-aggregated sand; upper fine to lower medium grained to trace lower fine; moderately sorted; subrounded to sub-angular with moderate sphericity; quartz grains are clear transparent to trans- lucent to few slightly milky white; abundant brownish gray to brownish black lithics; scattered dark gray to grayish black very fine grain minerals; trace pyrite and trace orange lithics; sample very slightly to slightly calcareous; no oil indicators. Sand/Siltstone (3850-3950) = medium light gray to medium gray with brownish gray hues; upper fine to lower fine to locally lower medium grained; moderately sorted; subrounded to subangular with moderate sphericity; disaggregated sand; predominantly clear colorless to translucent quartz; abundant brownish gray to dark gray lithics; trace pyrite grains; increase in silt content with depth of interval; silt matrix is very light gray to light brownish gray; very very soft and mushy; trace amounts of pale green to moderate green lithics; trace pyrite grains; sample is very slightly to slightly calcareous; no sample fluorescence and no oil indicators. Sand (3950-4000) = medium gray to medium light gray to light olive gray; lower fine to upper fine to lower medium grained; moderate sorting; subrounded to subangular with moderate sphericity; disaggregated; clear colorless to translucent predominates with scattered slightly smoky quartz; abundant pale green to greenish gray lithics; slightly calcareous; no oil indicators. Sand (4000-4050) = medium light gray to medium gray to light olive gray; lower fine to upper fine to trace upper very fine; moderate sorting; subangular to subrounded; moderate to low sphericity; predominantly clear colorless to translucent quartz grains; abundant pale green to grayish green lithics; scattered very fine grained dark gray to black minerals/lithics; no sample fluorescence and no oil indicators. Sand (4050-4150) = medium gray to medium light gray to light olive gray overall; lower fine to upper fine to upper very fine; moderately sorted; subangular to subrounded to trace angular grains with moderate to low sphericity; pre-dominantly clear colorless to trans- lucent disaggregated quartz grains; few scattered slightly smoky quartz grains; abundant pale green to light green lithics; trace to scattered amounts of silty 13 C.ANIIG 1)xi.i.i n;Tiu:H i.uc:v I.ri. eni Erd Petroleum OP09-S1 material within sample interval; trace pyrite grains; sample is very slightly to slightly calcareous; no sample fluorescence and no oil indicators present. Siltstone(4150-4200) = light gray to pinkish gray to light brownish gray; slightly cohesive; very soft and mushy; irregular fracture; globby locally massive cuttings habit; dull earthy luster; silty to gritty texture; no visible structure; very slight reaction with acid; no sample fluorescence and no oil indicators present. Siltstone (4200-4250) = sample consists of a medium light gray to pinkish gray to light brown; slightly cohesive; poorly adhesive; mushy to curdy to globular consistency; no visible structure; slightly nodular cuttings habit; dull earthy luster with a silty to gritty texture; very slight reaction to acid; no sample fluorescence and no oil indicators. Siltstone/Claystone (4250-4300) = light brownish gray to light brown to medium light gray; slightly cohesive; poorly adhesive; mushy to pasty to globular consistency; no visible structure; slightly nodular cuttings habit; dull earthy luster with a silty gritty texture grading to silty clayey; no sample fluorescence and no oil indicators. Siltstone/Claystone (4300-4350) = medium light gray to light brownish gray to light brown; slightly cohesive; mushy to pasty to mushy consistency; no visible structure; slightly nodular cuttings habit; dull earthy luster; silty clayey texture grading to silty gritty; no sample fluorescence/no oil indicators. Siltstone(4350-4400) = light gray to medium light gray to light brownish gray; slightly cohesive; very soft to mushy; irregular fracture; dull earthy luster; silty gritty texture; no visible structure; no sample fluorescence and no oil indicators. Siltstone/Claystone(4400-4450) = medium light gray to light brownish gray to light brown; slightly cohesive; mushy to pasty consistency; no visible structure; slightly nodular cuttings habit; dull earthy luster; silty clayey texture; no oil indicators. Siltstone/Claystone(4450-4500) = medium gray to light brownish gray to light brown; slightly cohesive; mushy to pasty consistency; no visible structure; slightly nodular cuttings habit; dull earthy luster; silty clayey texture; no sample fluorescence and no oil indicators. Siltstone(4500-4550) = light gray to medium light gray to light brownish gray; slightly cohesive; very soft to mushy to slightly pasty consistency; irregular fracture; dull earthy luster; silty gritty texture to silty clayey texture; no visible structure; slight reaction to acid; no sample fluorescence and no oil indicators. Siltstone/Claystone (4550-4600) = light brownish gray to light brown to medium light gray; slightly cohesive; poorly adhesive; mushy to pasty to very soft consistency; no visible structure; slightly nodular cuttings habit; dull earthy luster; texture grading back and forth between silty gritty and silty clayey; no sample fluorescence and no oil indicators. Siltstone (4600-4650) = light gray to medium light gray to light brownish gray; slightly cohesive; very soft to mushy; irregular fracture; dull earthy luster; silty clayey texture grades to a more silty gritty; no visible structure; no sample fluorescence and no oil indicators. Sand (4650-4700) = medium gray to medium light gray to olive gray; lower fine to upper fine to lower medium grained; moderate sorting; subrounded to subangular with moderate sphericity; disaggregated; clear colorless to translucent predominates with scattered slightly smoky quartz; abundant pale green to greenish gray to brilliant green lithics; slightly calcareous. Siltstone (4700-4750) = sample consists of a medium light gray to pinkish gray to light brown; slightly cohesive; poorly adhesive; mushy to curdy to slightly pasty consistency; no visible structure; dull earthy luster with a silty to gritty texture; no oil indicators. Sand (4750-4850) = medium gray to medium light gray to light olive gray overall; lower fine to upper fine to upper very fine; moderately sorted; subangular to subrounded to trace angular grains with moderate to low sphericity; pre-dominantly clear colorless to trans- lucent and transparent disaggregated quartz grains; few scattered slightly smoky quartz grains; quartz percentage is 70% quartz 30% scattered dark gray lithics; abundant pale green to light green lithics; trace to scattered amounts of silty material within 14 CANING eni EnH Petroleum OP09-S1 sample interval; trace pyrite grains; sample is very slightly to slightly calcareous; no sample fluorescence and no oil indicators present. Siltstone (4850-4900) = light gray to pinkish gray to light brownish gray; slightly cohesive; very soft and mushy to slightly pasty; irregular fracture; locally massive cuttings habit; dull earthy luster; silty to gritty texture; no visible structure; very slight reaction with acid; no sample fluor-escence and no oil indicators present. Sand (4900-5000) = medium gray to medium light gray to olive gray overall; lower fine to upper fine to upper very fine; moderately sorted; subrounded to subangular to trace angular grains all with moderate to low sphericity; pre-dominantly clear colorless to trans- lucent and transparent disaggregated quartz grains; few scattered slightly smoky quartz grains; sand percentage is 60% quartz 40% scattered dark gray lithics; abundant pale green to brilliant green to moderate green lithics; trace to scattered amounts of amounts of silty material within sample interval seem to increase slightly with depth; trace pyrite grains; sample is very slightly to slightly calcareous; no sample fluorescence and no oil indicators present. Siltstone(5000-5050) = light gray to pinkish gray to light brownish gray; slightly cohesive; very soft and pasty to slightly mushy; irregular fracture; slightly nodular cuttings habit; dull earthy luster; silty to gritty texture; no visible structure; very slight reaction with acid; no sample fluor-escence and no oil indicators present. Sand (5050-5150)= sample consists of a medium gray to medium light gray to olive gray slurry of mostly dis-aggregated sand; lower fine to upper fine grained to trace upper very fine; moderately sorted; subrounded to sub-angular with moderate sphericity; quartz sand is predominantly clear and colorless to translucent to slightly smoky quartz; abundant to common pale green to grayish green to brilliant green glauconite/lithics; trace pieces very poorly consolidated sandstones which are very soft to soft; scattered amounts of silty material within interval; very slightly to non-calcareous; no sample fluorescence observed and no oil indicators present. Siltstone(5150-5200)= light gray to light brownish gray to pinkish gray; slightly cohesive; very soft to mushy to slightly pasty; irregular fracture; slightly nodular cuttings habit; dull earthy luster; silty to gritty texture; no visible structure; very slight reaction with acid; no sample fluor-escence and no oil indicators present. Sand (5200-5250)= composed of medium gray to medium light gray to light olive gray disaggregated sands; lower fine to upper fine to trace upper very fine; moderately sorted; subangular to sub- rounded to trace angular; moderate to low sphericity; abundant to common pale green to greenish gray glauconite lithics; very slight to non-calcareous; no sample fluorescence. Siltstone(5250-5310) = light gray to medium dark gray; pasty consistency throughout sample interval; slightly to poorly adhesive; moderately cohesive; dull earthy luster; texture varies depending on amount of sand and accessory mineral grains between silty and gritty to silty and clayey; no visible structures; sand content increases with sample depth; no visible sample fluorescence was observed. Claystone (5310-5440) = light gray to brownish gray and grayish brown; pasty masses of clay containing variable amounts of silt and sand; the mixture is olive gray when wet and light olive gray to slightly brown when dry; samples display excellent cohesion, and plasticity varies inversely with silt content; both decrease rapidly near the base of this interval; somewhat firm, rounded cuttings can be found in the masses of loose material; the cuttings are brittle, with irregular, earthy surfaces when broken; a waxy to dull luster is underlain by a clayey texture that is mostly silty; bedding is only slightly perceptible; sand typically constitutes 30%to 40% overall of the sample; the sand is mostly very fine grained and grades into silt; quartz and lesser black lithics comprise the bulk of the sand; no visible sample fluorescence was observed; no other petroleum indicators were observed. Sand (5440-5570) = predominantly clear to translucent, with milky white, white light gray, pale blue, light greenish gray, and dark yellowish orange hues; medium with some coarse grains throughout sample interval; subangular to angular to few subrounded grains; moderate to poor sphericity; samples are all abundant with fine to very fine grained black lithics giving a salt and pepper appearance; brilliant green to moderate green to translucent blue green glauconite throughout sample interval, fine to medium grained, 15 CANING 1)ui i.i.i vi:TILL:H\'VLVGI'I.ru. eni Eni Petroleum OP09-S1 subrounded to subangular with high to moderate sphericity, throughout the sample >10%; pyrite was observed both as individual grains and as growths on the surfaces and within other minerals; very thick beds of quartz sand interbedded with thicker beds of sandy silty claystones and clayey to somewhat sandy in places siltstones; no visible sample fluorescence was observed. Siltstone(5570-5670) = light gray to medium gray with some light brownish gray and some grayish red and grayish brown; easily friable; predominantly mushy and pasty to semi clumpy; moderately cohesive; moderate to poor adhesiveness; massive cuttings come over shakers as reworked clumps with sand and other mineral grains consolidated within the masses; dull earthy to slightly vitreous and waxy luster; clayey silty to gritty texture, depending on the amount of sand grains present; slightly thicker beds of clayey siltstone interbedded with thick beds of loose uncemented quartz sand, with some silty to slightly sandy claystone; no visible sample fluorescence was observed; no other petroleum indicators were observed in the sample. Claystone (5670-5740) = medium gray to medium dark gray, with brownish gray; thinner claystones reworked with sand and other minerals; pasty to mushy consistency; moderately to high cohesive poorly adhesive; intergrades between silty claystone and clayey siltstone; dull earthy luster; silty clayey texture to locally gritty due to reworked sand; no visible sample fluorescence was observed. Sand (5740-5850) = translucent to clear with white, milky white, light gray, light greenish gray, dark yellowish orange, and very pale blue hues; predominantly upper very fine to lower fine with occasional upper fine grains; very well sorted; subangular to subrounded with moderate to high sphericity; translucent brilliant green to moderate green to bluish green fine grained glauconite, subrounded, high sphericity, approximately 5-10%; black lithics throughout the sample interval; abundant pyrite throughout the sample, both as individual crystals and as secondary growth on grains; thicker beds of unconsolidated quartz sands, interbedded with thinner beds of clayey to sandy siltstones, and sandy claystones; no visible sample fluorescence was observed. Siltstone(5850-5950)= brownish gray to medium light gray; predominantly pasty to somewhat mushy and clumpy; this sample contains large amounts of sand, and grades in between clayey siltstone and silty claystone throughout the sample interval; slight to poor adhesiveness; moderate cohesiveness; consistency is predominantly pasty with some mushy cuttings; dull earthy luster; texture varies with clay and silt amounts, but is typically clayey silty to silty gritty throughout sample interval; no visible structures; abundant pyrite throughout the sample, both in crystal form and as secondary growth on mineral surface; no visible sample fluorescence was observed; no other oil indicators were observed. Claystone (5950-6060) = brownish gray to grayish brown, with some light gray; thinner beds of claystones which contain decreasing amounts of sand and other accessory minerals as depth increases; cuttings alternate between clayey siltstone and silty claystone, with increasing clay and decreasing silt as depth increases; pasty to mushy consistency; moderate to occasionally high cohesive properties; predominantly slight adhesiveness throughout; dull earthy luster; texture varies with grain content and depth, but generally is clayey to silty with some very gritty; abundant pyrite throughout the sample, both as secondary growth on mineral surfaces and crystal form; no visible sample fluorescence was observed; no other oil indicators were observed. Sand (6060-6210) = clear to translucent with some white, light gray; sand with minor disaggregated silt; the sand is a well sorted sand that is mostly upper fine-to upper very fine-grained, with minor amounts of lower very fine-grained sand grading into silt as well as trace to minor medium-to coarse-grained chips and rare coarse pebbles; the sand is predominantly comprised of very light gray to colorless to pale yellow, translucent to transparent quartz, with the remainder consisting of gray to black, siliceous cryptocrystalline lithics and minor blue green glauconite; the quartz sand is subangular with moderate sphericity while the lithics are subrounded with good to moderate sphericity; quartz grain surfaces display both impact abrasions and etching; rare pyrite can be found within the samples, as well as within the black lithics; the coarse chips and pebbles consist of white quartz, orange to yellow chert, and gray or black lithics; the chips are angular, while the pebbles are well rounded and often polished; no petroleum stain, odor nor fluorescence is detectable. 16 C:ANRIG eni Enii Petroleum OP09-S1 Siltstone/Claystone(6210-6300) = brown to grayish brown and brownish gray; consisting of pulverulent claystone and silt and loose sand with a few plastic clumps of clayey material; aggregate samples are olive gray and have an earthy luster underlain by a silty texture that is variably clayey and gritty; sand and clay content decrease slightly with depth in this interval; the sand consists of clear to translucent to milky white, and gray quartz with lesser grains of siliceous black lithics; samples are slightly calcareous; no oil stain are visible sample fluorescence was observed; no other oil indicators were observed. Sand/Sandstone (6300-6430) = clear to translucent, with milky white, light gray, white, pale blue, dark yellowish orange, and light greenish gray hues; predominantly quartz grain sand with abundant dark colored lithic fragments; predominantly upper very fine to lower fine with occasional lower very fine and upper fine grains throughout sample interval; very well sorted; subangular to subrounded with moderate to high sphericity; bluish green to translucent brilliant green to moderate green very fine to fine grained glauconite; mostly subrounded to subangular, with some very rounded to very angular; moderate sphericity, approximately 20%-25%very fine to fine dark colored lithics; some grains appeared to be slightly to severely frosted in places; thicker beds of mostly uncemented loose quartz sand interbedded with thinner beds of silty claystones, and sandy siltstones; no visible sample fluorescence was observed; no other petroleum indicators were observed. Claystone(6430-6520) = light gray to gray with some brownish gray and grayish brown hues with light olive; moderate cohesion, yet only modest plasticity due to sand and silt content; the clay/silt/sand mixture is mushy and pasty, and disregarding the sand, there is a dull earthy texture and a smooth, clayey to silty texture to the sample; thinner beds of sandy claystones interbedded with thicker beds of predominantly loose uncemented quartz sand, and friable to hard siliceous cemented fine grained sandstones; no visible sample fluorescence was observed. Siltstone(6520-6610)= dark gray to medium gray with some brownish gray; pasty to somewhat mushy and punky; this sample contains large amounts of sand, and grades in between clayey siltstone and silty claystone throughout the sample interval; slight to poor adhesiveness; moderate cohesiveness; consistency is predominantly pasty with some mushy cuttings; dull earthy luster; texture varies with the concentrations of silt, sand and clay; much thinner siltstone beds interbedded with thicker beds of predominantly loose uncemented quartz sand, and siliceous, slightly calcareous cemented fine grained sandstones; no visible sample fluorescence was observed. Sand/Sandstone (6610-6700) = mostly translucent to clear, with white, milky white, light gray, dark yellowish orange, pale blue, and light greenish gray hues; predominantly quartz sand matrix throughout; upper very fine to upper fine with some lower medium grain sand; moderate to well sorted; very well rounded to very angular with subrounded to subangular; moderate to high sphericity; some sand grains appeared to be slightly frosted;thicker beds of loose unconsolidated quartz sand and siliceous to slightly calcareous cemented very fine grain sandstones interbedded with thinner clayey to somewhat sandy siltstones and sandy claystones. Claystone(6700-6790) = light gray to gray with some brownish gray and grayish brown hues with light olive; moderate cohesion, yet only modest plasticity due to sand and silt content; the clay/silt/sand mixture is mushy and pasty, and disregarding the sand, there is a dull earthy texture and a smooth, clayey to silty texture to the sample; thinner beds of sandy claystones interbedded with thicker beds of predominantly loose uncemented quartz sand, and friable to hard siliceous cemented fine grained sandstones; no visible sample fluorescence was observed. Siltstone(6790-6880) = medium gray to dark gray with some brownish gray; punky to somewhat mushy and pasty; this sample contains large amounts of sand, and grades in between clayey siltstone and silty claystone throughout the sample interval; slight to poor adhesiveness; moderate cohesiveness; consistency is predominantly punky with some mushy cuttings; dull earthy luster; texture varies with the concentrations of silt, sand and clay; much thinner siltstone beds interbedded with thicker beds of predominantly loose uncemented quartz sand, and siliceous, slightly calcareous cemented fine grained sandstones; no visible sample fluorescence was observed. Sand/Sandstone(6880-6950) = mostly translucent to clear, with white, milky white, light gray, grayish orange, pale blue, and light greenish gray hues; predominantly quartz sand matrix throughout; upper very 17 CANRIG eni Eni Petroleum OP09-S1 fine to upper fine with some lower medium grain sand; moderate to well sorted; very well rounded to very angular in part; trace subrounded to subangular; moderate to high sphericity; scattered dark gray siliceous lithics; no sample fluor-escence and no oil indicators. Claystone(6950-7050) = light gray to gray with some brownish gray and grayish brown hues with light olive; moderate cohesion, poorly adhesive; poor plasticity due to amount of sand content; clayey/silty cuttings are mushy to pasty; there is a dull earthy luster and a silty clayey to somewhat silty gritty texture depending on the amount of reworked sand grains; sandy/silty claystones are interbedded with thicker beds of predominantly loose dis-aggregated sands and friable to slightly firm siliceous fine grained sandstones; sample is non-calcareous; no visible sample fluorescence and no oil indicators were observed. Siltstone(7050-7140)= medium light gray to medium gray to a brownish gray; cuttings are mushy to pasty to somewhat punky; sample contains large amounts of sand and grades in between clayey siltstone and silty claystone throughout the sample interval; slight to poor adhesiveness; moderate cohesiveness; consistency is predominantly mushy with some pasty cuttings; dull earthy luster; texture varies with the amount of silt, clay, and reworked sand; much thinner siltstone beds interbedded with thicker beds of predominantly loose dis-aggregated quartz sand and siliceous, slightly calcareous cemented fine grain sandstones; no visible sample fluor-escence was observed. Sand/Sandstone(7140-7230) = mostly translucent to clear, with white, milky white, light gray, grayish orange, pale blue, and light greenish gray hues; predominantly quartz sand matrix throughout; upper very fine to upper fine with some lower medium to upper medium grain; moderate to well sorted; very well rounded to subrounded to subangular in part; moderate to high sphericity; scattered dark gray to brownish black siliceous lithics; trace pale blue to pale green, brownish gray and orange lithics; fine grained sand- stones are friable to firm to some hard in part; cemented; little to very slightly calcareous; no sample fluor- escence and no oil indicators observed. Claystone(7230-7300) = medium light gray with some brownish gray and grayish brown hues; moderately cohesive; poorly adhesive; poor plasticity due to high amount of sand content; cuttings are mushy to pasty; dull earthy luster with a clayey silty texture; thin silty claystone are interbedded with thicker beds of predominantly loose dis-aggregated sands and siliceous, cemented fine grained sandstones; non-calcareous; no sample fluorescence and no oil indicators were observed. Siltstone(7300-7350) = medium light gray to medium gray to a brownish gray; cuttings are mushy to pasty; contains sands and grades between silty claystone and clayey siltstone throughout sample interval; poor adhesiveness; moderate cohesiveness; dull earthy luster with a silty clayey texture grading to a silty gritty texture with increased sands. Sand/Sandstone(7350-7450) = sample consists of a slurry of clear colorless to translucent, with milky white, light gray, grayish orange, pale blue and light greenish gray hues; predominantly quartz sand matrix throughout; upper very fine to upper fine to some lower medium grain in part; moderate to well sorted; subrounded to subangular to trace angular; moderate to high sphericity; abundant dark gray to brownish black, rounded, siliceous lithics; trace pale blue to pale green lithics; trace amounts of pyrite grains; cemented fine grained sandstones are friable to firm; very slightly to non-calcareous; no sample fluorescence and no oil indicators observed. Claystone (7450-7540) = medium gray to dark gray with some grayish brown hues with light olive gray; moderate cohesion, poorly adhesion; plasticity is poor due to high sand content; cuttings mushy to punky; claystones have a dull earthy luster and silty clayey to a somewhat smooth texture in part disregarding the sand grains; sample interval contains silty claystones that grade to clayey siltstones; thin clay-stones interbedded with predominantly larger beds of loose disaggregated sands and cemented, siliceous fine grained sandstones; sample is very slightly to non-calcareous; no visible sample fluor-escence and no oil indicators observed. Sand/Sandstone(7540-7630) = sample consists of a slurry of translucent to to clear, with milky white, light gray, grayish orange, pale blue and light greenish gray hues; predominantly quartz sand matrix throughout; upper fine to lower medium to some upper very fine grain in part; moderate to well sorted; well 18 CANRIG eni Ernie Petroleum 0P09-S1 rounded to subrounded to some subangular; moderate to high sphericity; abundant dark gray to brownish black, rounded, siliceous lithics; trace pale blue to pale green lithics; cemented fine grained sandstone cuttings are friable to firm to trace hard; very slightly to non-calcareous; no sample fluorescence and no oil indicators observed. Claystone (7630-7700) = medium gray to dark gray with some brownish gray and grayish brown hues; moderately cohesive; poorly adhesive; plasticity is poor; pasty to mushy cuttings; dull earthy luster with a silty clayey texture; thin silty claystone are interbedded with thicker beds of loose sands and cemented fine grained sandstones; non-calcareous; no sample fluorescence and no oil indicators were observed. Sand/Sandstone(7700-7800) = sample consists of a slurry of clear colorless to translucent, with milky white, light gray, slightly smoky and light greenish gray hues; predominantly quartz sand matrix throughout; upper fine to lower medium to lower fine grain throughout; moderate to well sorted; subangular to angular to trace subrounded; moderate to few high spherical grains; abundant dark gray to brownish black siliceous lithics; common pale green to light green lithics; trace amounts of pyrite; cemented fine grained sandstones are friable to firm; trace amounts of brownish black to black carbonaceous shale/coal fragments observed in 7800 sample; blocky fracture and flaky cuttings habit; dull slightly resinous luster; sample is very slightly calcareous; no sample fluorescence and no oil indicators. Claystone(7800-7900) = dark gray to medium gray with some brownish gray and grayish brown hues; moderately cohesive; poorly adhesive; poor plasticity; mushy to pasty consistency; dull earthy luster with a clayey silty texture; thin silty claystone are interbedded with thicker beds of loose sands and cemented fine grained sandstones and some carbonaceous shale/coal; non-calcareous; no sample fluorescence and no oil indicators were observed. Siltstone(7900-7950) = medium gray to medium light gray to a brownish gray; cuttings are mushy to pasty; contains sands and grades between silty claystone and clayey siltstone throughout sample interval; poor adhesiveness; moderate cohesiveness; dull earthy luster with a silty clayey texture grading to a silty gritty texture; non-calcareous; no sample fluorescence and no oil indicators observed. Siltstone(7950-8050) = medium gray to grayish orange to a brownish gray; cuttings are mushy to pasty to an occasional crumbly; cuttings contain large amounts of sand; grade between clayey siltstone and silty claystone throughout sample interval; poor to slight adhesion; moderate cohesion; consistency is predominantly mushy to pasty overall; slightly crumbly tenacity localized cuttings; dull earthy luster and a silty clayey texture to slightly gritty texture due to sand content; siltstone beds are thin and interbedded with thicker beds of loose quartz sand and cemented fine grained sandstones; no visible sample fluorescence and no oil indicators observed. Sand/Sandstone (8050-8150)= sample consists of a slurry of clear colorless to translucent, light gray, and light greenish gray hues; predominantly lower fine to upper very fine with some upper fine grain throughout; moderate to well sorted; subrounded to subangular to rounded in part; moderate to high sphericity; abundant brownish black to black very fine minerals/lithics; common pale green to light green lithics to an occasional grayish blue green; trace pyrite as grains and growths on other grains; sandstone cuttings are fine grained, cemented, and are friable to slightly firm; sample is slightly calcareous; no sample fluorescence and no oil indicators visible. Claystone (8150-8200)= medium gray to dark gray with some brownish gray and dark yellowish brown hues; moderately cohesive; poor adhesion; poor plasticity due to sand content; consistency is pasty to mushy; dull earthy luster; silty clayey texture; non-calcareous; no sample fluorescence and no oil indicators visible. Siltstone(8200-8250) = medium light gray to brownish gray to some grayish orange; cuttings are predominantly soft; mushy to pasty consistency; trace crumbly tenacity; cuttings grade between a silty claystone and a clayey siltstone throughout interval; poor adhesion; moderate cohesion; dull earthy luster; silty clayey texture grading to a silty gritty texture; non-calcareous; no sample fluorescence visible. Claystone(8250-8300) = dark gray to medium gray with some grayish brown and dark yellowish brown hues; moderately cohesive; poor adhesion; poor plasticity due to sand content; consistency is mushy to 19 CANRIG eni Enil Petroleum OP09-S1 punky; dull earthy luster; silty clayey texture; non-calcareous; no sample fluorescence and no oil indicators visible. Siltstone(8300-8350) = medium light gray to brownish gray to some grayish orange; cuttings are predominantly soft; mushy to pasty consistency; trace crumbly tenacity; cuttings grade between a silty claystone and a clayey siltstone throughout interval; moderate cohesion; dull earthy luster; silty gritty to silt clayey texture; non-calcareous; no oil indicators visible. Sand/Sandstone(8350-8450) = sample consists of a slurry of clear colorless to translucent, white to milky white, light gray, and light olive gray hues; predominantly lower fine to upper very fine grain throughout; moderate to well sorted; subangular to subrounded to angular in part; moderate to high sphericity; abundant brownish black to black very fine minerals/lithics; common pale green to light green lithics to an occasional grayish blue green; trace pyrite as grains and growths on other grains; sample is slightly calcareous; no sample fluorescence and no oil indicators observed. LOWER UGNU 8465.0' MD/-3284.5' TVDSS Siltstone (8450-8550) = olive gray to olive black with some dark greenish gray; siltstone is easily friable to friable; very poorly to poorly indurated; tenacity is brittle to crumbly; fracture is irregular and earthy; cuttings habit is massive with bladed cuttings at the end of the interval; luster is earthy to dull; texture is silty to gritty; structure is overall massive with thin micro- laminations where carbonaceous material is present; abundant quartz sand interbedded which is fine grained; carbonaceous material in laminated beds within the siltstone; very faint dull green yellow sample fluorescence was observed, approximately <5%; no solvent cut. Sand/Sandstone(8550-8660) = clear to translucent with some white, milky white, pale blue, light greenish gray, dark yellowish orange, and dark gray; predominantly loose unconsolidated quartz sand with lesser amounts of siliceous cemented fine grained sandstones; upper very fine to upper medium grain sand; moderate to well sorted throughout; very angular to subangular with some subrounded; moderate to high sphericity; some grains appeared to be slightly frosted; thicker beds of sand and sandstone interbedded with thinner beds of sandy siltstones; abundant pyrite throughout, both as crystals and as secondary growth on grain surfaces; little or no sample fluorescence was observed; no other petroleum indicators were observed in the sample. Siltstone (8660-8740) = dark gray to medium gray with some dark brown; slightly stiff to somewhat firm; interbedded with very fine quartz sand; brittle to somewhat stiff; mostly irregular fracture with some slightly planar; platy to amorphous cuttings habit; dull to greasy luster; very silty to gritty in places due to sand content; thinner beds of sandy siltstone interbedded with mostly loose very fine quartz sand and very fine grained siliceous cemented sandstones; no visible sample fluorescence was observed; no other petroleum indicators were observed. Sand/Sandstone(8740-8850) = clear to translucent, with milky white, light gray, white, pale blue, dark yellowish orange, and light greenish gray hues; predominantly quartz grain sand with abundant dark colored lithic fragments; predominantly upper very fine to lower fine with occasional lower very fine and upper fine grains throughout sample very well sorted; subangular to angular to subrounded; high to moderate sphericity, approximately 20%-25%very fine to fine dark colored lithics; some grains appeared to be slightly to severely frosted in places; thicker beds of mostly uncemented loose quartz sand, and siliceous cemented very fine sandstones interbedded with thinner beds of sandy siltstones; no fluorescence was observed; no other petroleum indicators were observed. Siltstone (8850-8930) = grayish black to black with brownish black hues; stiff to firm; mostly brittle tenacity to crumbly; mostly irregular fracture to planar; amorphous cuttings habit to platy; dull to earthy luster; predominantly silty to slightly gritty; thin beds of sandy siltstones interbedded with very thick beds of loose unconsolidated quartz sand and siliceous cemented very fine grained sandstones; no visible sample fluorescence was observed; no other petroleum indicators were observed. 20 CANRIG eni €nil Petroleum OP09-S1 Sand/Sandstone(8930-9020) = mostly translucent to clear, with white, milky white, light gray, grayish orange, pale blue, and light greenish gray hues; predominantly quartz sand matrix throughout; upper very fine to upper fine with some lower medium to upper medium grain; moderate to well sorted; very angular to subangular with some subrounded in part; moderate to high sphericity; scattered dark gray to brownish black siliceous lithics; trace pale blue to pale green, brownish gray and orange lithics; sandstones are friable to firm to some hard with siliceous cement that is very slightly calcareous; no sample fluorescence was observed. Siltstone(9020-9150) = medium light gray to medium gray to light brownish hues; stiff to slightly firm; brittle to crumbly; predominantly irregular fracture with some slightly planar; mostly amorphous cuttings habit; mostly dull to earthy luster with some slightly greasy in places; very silty texture with some very gritty in places; siltstone very calcareously cemented starting about 9110' md; thinner beds of sandy siltstone interbedded with thicker beds of loose uncemented quartz sand; abundant pyrite throughout sample, both as crystals and as secondary growth on mineral surfaces; very little or no visible sample fluorescence, <1%very faint dull yellow green sample fluorescence. Siltstone(9150-9240) = dark gray to light gray and brownish gray; stiff to slightly firm; irregular to slightly planar fracture; platy to amorphous cuttings habit; greasy to dull luster; very silty to somewhat smooth texture; very calcareous, becoming very finely sandy; interbedded with thicker beds of sand and sandstone; the sandstones consists of white to light gray, fine to coarse grained sand with floating very coarse grains; silty matrix consists of cloudy white to clear quartz and broken cherty fragments with minor dark lithic minerals; weak to moderate well calcite cement; no visible sample fluorescence was observed. Sand (9240-9350) = predominantly clear to translucent, with some white, light gray, milky white, light greenish gray, light blue, and dark yellowish orange; mostly quartz grain sand matrix with abundant dark colored lithic fragments; upper fine to upper medium with some lower coarse grains; fair to poorly sorted; very angular to subangular with some subrounded; moderate to high sphericity; abundant pyrite throughout, both as crystals and as secondary growth on other minerals; thicker beds of loose uncemented quartz sand and fine to medium grained calcareous cemented sandstones interbedded with thinner beds of sandy siltstones; very little sample fluorescence was observed, less than 3%, faint dull yellow fluorescence; no solvent cut; no other petroleum indicators were observed. Siltstone(9350-9440) = dark gray to light gray with some brownish gray; moderately firm to stiff; very dense to brittle; irregular to slightly blocky fracture; platy to amorphous cuttings habit; greasy to waxy luster; very silty with some very gritty; thinner beds of sandy slightly calcareous siltstones, interbedded with thicker beds of loose unconsolidated quartz sand, and fine to medium grained siliceous cemented sandstones; pyrite throughout the sample both as crystals and secondary growth on mineral surfaces; no visible sample fluorescence was observed; no other petroleum indicators were observed. Sand/Sandstone (9440-9560) = clear to translucent, with some milky white, light gray, white, light greenish gray, pale blue, and dark yellowish orange hues; predominantly quartz grain sand matrix with abundant dark colored lithic fragments throughout; upper fine to upper medium with some lower coarse grain sand; fair to poorly sorted; very angular to subangular with some well rounded to subrounded; moderate to high sphericity; thick beds of loose uncemented quartz sand and fine to medium grained calcareous cemented sandstones, interbedded with thinner beds of sandy siltstones; pyrite throughout the sample both as crystals and as secondary growth in mineral surfaces; very little sample fluorescence was observed, less than 3% faint yellow sample fluorescence; slow milky white solvent cut. Siltstone(9560-9650) = dark gray to medium gray with some brownish gray; predominantly firm to slightly stiff; poorly to moderately poorly indurated; tenacity is brittle to dense; fracture is earthy and irregular; cuttings habit is massive with some bladed; luster is dull to earthy; silty to gritty texture; massive structure; pyrite throughout the sample; thinner beds of sandy siltstones, interbedded with thicker beds of mostly loose unconsolidated sand, and fine to medium grained calcareous cemented sandstones; very little sample fluorescence, less than 3%, faint dull yellow sample fluorescence; slow milky white solvent cut. Sand/Sandstone(9650-9770) = clear to translucent, with some white, light gray, pale blue, and greenish gray; predominantly the sand is a quartz sand matrix, with abundant dark colored lithic fragments throughout; upper fine grain to upper medium grain sand; fair to well sorted; very angular to subangular 21 C:ANRIG VIOs en; Evil Petroleum OP09-S1 with some well rounded to subrounded; moderate sphericity; quartz sands interbedded with thinner beds of sandy siltstones; sands consists of minor blue green glauconitic lithics and brown to black siliceous lithics; minor to trace amounts of calcite is scattered throughout the samples, trace yellowish orange to reddish orange lithics; very faint dull yellow sample fluorescence was observed, less than 5%; slow milky white solvent cut. Siltstone (9770-9830) = medium gray to light gray and brownish gray; stiff to slightly firm; irregular to slightly planar fracture; platy to amorphous cuttings habit; greasy to dull luster; very silty to somewhat smooth texture; very calcareous, becoming very finely sandy; interbedded with thicker beds of quartz sand and fine grained sandstones; very faint dull yellow sample fluorescence, approximately 5%; slow milky white solvent cut. Sand/Sandstone(9830-9940) = clear to translucent, with some white, light gray, and greenish gray throughout; predominantly the sand is a quartz sand matrix, with abundant grayish black to black very fine grained minerals/lithics throughout giving a salt and pepper appearance; upper fine to lower medium with some lower fine grained; moderate to well sorted; subangular to subrounded with trace amounts of rounded; moderate to high sphericity; thicker beds of quartz interbedded with thinner beds of sandy siltstone; sands contain trace very pale blue green glauconitic lithics and brown to black siliceous lithics; trace yellowish orange to reddish orange lithics; very faint dull yellow sample fluorescence observed (< 5%); no odor and no cut was observed. Siltstone(9940-10000) = medium gray to pinkish gray and light brownish gray; cuttings are soft to slightly stiff; irregular fracture; slightly platy to amorphous cuttings habit; dull earthy luster with a silty texture; no visible structure; cuttings are very calcareous; interbedded with beds of quartz sand and fine grained sandstones; sample exhibits a very faint dull yellow sample fluor-escence in siltstone cuttings; very slow dull yellow to milky white cut. Sand/Sandstone(10000-10100) = clear to translucent, with some white, light gray, and light olive gray throughout; predominantly the sand is a quartz sand matrix, with abundant grayish black to black very fine grained minerals/lithics throughout; lower fine to lower medium with trace upper medium grained; moderate to well sorted; subangular to subrounded with trace amounts of angular; moderate to high sphericity; thicker beds of quartz sand interbedded with thinner beds of sandy siltstone; contains trace moderate blue green glauconitic lithics and brown to black siliceous lithics; trace reddish orange lithics; no sample fluorescence and no oil indicators observed. Sand/Sandstone (10100-10170) = clear to translucent, with some white, light gray, and light olive gray throughout; predominantly the sand is a quartz sand matrix, with abundant black very fine grained mineral/lithics giving salt and pepper appearance; lower fine to lower medium grained; moderate to well sorted; subangular to angular to trace subrounded; moderate to high sphericity; trace amounts of pale green to moderate blue green glauconitic lithics; trace orange lithics; no sample fluorescence and no oil indicators. Siltstone(10170-10250) = medium gray to light gray to light brownish gray; cuttings are soft to firm to hard at base of interval; irregular fracture; amorphous cuttings habit; dull earthy to slightly greasy luster with a silty texture; cuttings are very calcareous; interbedded with beds of quartz sand and fine grained sandstones; sample exhibits a very faint dull yellow sample fluor-escence in siltstone cuttings(2-3%). Sand/Sandstone(10250-10350) = clear to translucent, with some white, light gray, and light olive gray throughout; predominantly the sand is a quartz sand matrix, with abundant grayish black to black very fine grained minerals/lithics throughout; lower fine to lower medium with trace upper medium grained; moderate to well sorted; subangular to angular with trace amounts of sub- rounded; moderate sphericity; interbedded with thin sandy siltstone; sands contain trace very pale blue to moderate blue green glauconitic lithics; brown to black siliceous slightly cherty lithics; trace reddish orange lithics; no sample fluorescence and no oil indicators observed. Siltstone(10350-10430) = medium light gray to pinkish gray to light brownish gray overall; soft to slightly firm; slightly stiff tenacity; irregular fracture; slightly platy to amorphous cuttings habit; dull earthy luster; silty to slightly gritty texture; cuttings are very calcareous; thinner siltstone beds interbedded with thicker 22 CANRIG eni Eni Petroleum OP09-S1 beds of quartz sand and fine grained sandstones; sample exhibits a very faint dull yellow sample fluorescence in siltstone cuttings; very slow dull yellow to milky white cut. Sand/Sandstone (14430-10550) = clear to transparent to translucent, with white, pale blue, light greenish gray, milky white, and dark yellowish orange hues; mostly quartz sand matrix, with dark colored lithic fragments throughout; upper very fine to upper fine grain sand; well sorted; very well rounded to subrounded, with some very angular to subangular; moderate sphericity; some grains appeared to be slightly frosted in places; thick beds of quartz mostly loose unconsolidated, with lenses of very fine to fine grained siliceous cemented sandstone, very hard to slightly friable, interbedded with thinner beds of sandy siltstones; some pyrite in sample both as crystals and secondary growth on mineral surfaces; no visible sample fluorescence was observed; no other petroleum indicators were observed in the sample. Siltstone(10550-10660) = light gray to dark gray with some brownish gray; moderately firm to somewhat stiff; mostly brittle to stiff; irregular to slightly planar fracture; amorphous to platy cuttings habit; greasy to waxy luster; predominantly silty texture with some very gritty in places, resulting from increased very fine sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand and very fine grained siliceous cemented sandstones; very bright yellow sample fluorescence in the sandy siltstones, approximately 30%-40%; instantaneous bright white solvent cut; some oil staining was observed on the surface of the sandy siltstones; no free oil was observed in the sample; no petroleum odor. 23 CANfIG eni Enlil Petroleum 0P09-S1 SCHRADER BLUFF 10643.0' MD/-3573.3' 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"OA"Sand. The Schrader Bluff is an Upper Cretaceous turbidite deposit formed as sand lobes. The"N" Sand was encountered at 11092' MD/-3638.7 TVDSS. Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 393 2 169 224 1 43 PEAKS Depth TG C1 C2 C3 C4I C4N C5I C5N 11101 224 43716 173 96 51 64 50 34 Sand/Sandstone(10660-10800) = mostly translucent to clear, with some white, light gray, light greenish gray, pale blue to light blue, and dark yellowish orange hues; predominantly quartz sand matrix with abundant dark colored lithic fragments throughout sample; the sandstones are mostly comprised of friable to slightly stiff siliceous, very slightly calcareous cemented very fine to fine grain sand; the loose uncemented quartz sand consists of upper very fine to upper fine, with medium and lower coarse grains; poorly sorted; very well rounded to subrounded, with some very angular to subangular; moderate sphericity; some sand grains appeared to be frosted in places; some of the finer loose quartz grains appeared to be slightly stained pale brown; bright yellow sample fluorescence was observed, approximately 35%-45%; instantaneous bright white solvent cut, with a pale straw yellow streak; no free oil was observed in the sample; no petroleum odor in sample. Siltstone(10800-10910) = light gray to light brown with brownish gray, and grayish black to dark gray; slightly stiff to moderately firm; stiff to mushy to brittle; mostly irregular fracture; platy cuttings habit; greasy to waxy luster; predominantly silty texture with some very gritty in places, resulting from an increase in the sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand and very fine grained siliceous cemented sandstones; very bright yellow sample fluorescence, approximately 20%-30%; instantaneous bright white solvent cut, and straw yellow streak; some oil staining was observed on the surface of the sandy siltstones; no free oil was observed in the sample; no petroleum odor. Sand/Sandstone (10910-11040) =clear to translucent, with some light gray, white, dark yellowish orange; light greenish gray, and very pale blue hues; quartz sand matrix with abundant dark colored lithic fragments; upper very fine to upper fine grain sand; well sorted; very well rounded to subrounded, with some very angular to subangular; moderate sphericity; some grains appeared to be slightly frosted in places; thick beds of quartz mostly loose unconsolidated sand, with lenses of very fine to fine grained siliceous cemented sandstone, very hard to slightly friable, interbedded with thinner beds of sandy siltstones; the sandy siltstones appeared to be stained with old petroleum hydrocarbons; no petroleum odor; bright yellow green sample fluorescence, approximately 20%-30%; instantaneous bright white solvent cut. N SEQUENCE TOP 11092.0' MD/-3638.7' TVDSS Siltstone (11040-11150) = light gray to brownish gray with some dark gray to grayish black; mostly firm to friable; brittle to very stiff; irregular to planar fracture; mostly amorphous to somewhat platy habit; dull to earthy luster with some waxy luster; predominantly silty texture with some very gritty, due to the increasing in sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand, 24 CANRIG VI ill eni Eni Petroleum OP09-S1 and thin lenses of siliceous cemented very fine grained, friable sandstone; some pyrite crystals were observed throughout the sample, however much less than in above hole samples; bright yellow sample fluorescence, approximately 20%-30%; instantaneous milky white to straw yellow solvent cut. Sand/Sandstone (11150-11270)= mostly translucent to clear, with some light gray, white, milky white, pale blue, dark yellowish orange, and light greenish gray hues; predominantly quartz sand matrix, with abundant dark colored lithic fragments; upper very fine to upper fine grain sand; well sorted; very well rounded to subrounded, with some very angular to subangular; moderate sphericity; some grains appeared to be slightly frosted in places; thick beds of loose unconsolidated quartz sand, with thinner lenses of very fine grained siliceous cemented friable sandstone, interbedded with thinner beds of sandy siltstones; the siltstones were stained with old petroleum hydrocarbons, which have a bright yellow sample fluorescence; no visible sample fluorescence for the sands and sandstones. Siltstone(11270-11350) = brownish gray, to light gray and dark gray; mostly very firm to stiff; brittle to dense; to brittle; mostly irregular fracture; platy cuttings habit; greasy to waxy luster; predominantly silty texture with some very gritty in places, resulting from an increase in the sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand and thin lenses of siliceous cemented very fine grained, friable sandstone; bright yellow sample fluorescence, approximately 20%-30%; instantaneous milky white to straw yellow solvent cut. Sand/Sandstone(11350-11450) = mostly translucent to clear, with some light gray, white, milky white, and light greenish gray hues; predominantly quartz sand matrix; upper very fine to upper fine grained with trace lower medium; well to moderately well sorted; subrounded to rounded to slightly sub-angular; moderate to high sphericity; thicker beds of loose disaggregated quartz sand interbedded with thinner beds of sandy siltstones; thin lenses of siliceous cemented sandstones also interbedded throughout interval; abundant brownish black to black very fine grained lithics with occasional medium grained; no visible sample fluor-escence observed in the sands and sandstone cuttings. Siltstone(11450-11550) = brownish gray to medium gray and medium dark gray; mostly stiff to firm to some soft; brittle to crumbly tenacity; mostly irregular fracture; platy to amorphous cuttings habit; greasy to waxy luster; predominantly silty texture to slightly gritty in part; sandy siltstone inter- bedded with thicker beds of loose disaggregated quartz sand and thin lenses of siliceous cemented very fine grained sandstone; no odor present; very slight oil staining visible in siltstone cuttings (5%); bright yellow sample fluorescence, approximately 20%-30%; instantaneous milky white cut fluor-escence; pale straw to straw cut; bright yellow residual fluorescence with light brown visible residue. N SAND-1 11615.0' MD/-3702.4' TVDSS Sand/Sandstone(11550-11650) = sample consists of a slurry of translucent to clear, milky white, light gray and light greenish gray hues; predominantly quartz sand matrix; upper very fine to upper fine grained with trace lower medium; well to moderately well sorted; subrounded to subangular to trace rounded; moderate to high sphericity; some sand grains appear to be frosted; thicker beds of loose disaggregated quartz sand interbedded with thinner beds of sandy siltstones; thin lenses of siliceous cemented sandstones also interbedded throughout interval; abundant brownish black to black, very fine grained lithics with occasional medium grained; trace pyrite found as individual grains; no odor present; trace oil staining; bright yellow sample fluorescence (10%-20%); very slow dull yellow cut fluorescence. N SAND-2 11679.0' MD/-3711.2' TVDSS Siltstone(11650-11750) = medium light gray to medium gray to light brownish hues; mostly soft to slightly firm; stiff to brittle tenacity; mostly irregular fracture; amorphous cuttings habit; greasy waxy to slightly dull luster; silty to somewhat smooth texture to gritty in part; grades from silty sandstone to sandy siltstone; thin beds of sandy siltstone interbedded with thicker beds of loose disaggregated quartz sand and thin 25 C:ANRIG eni Ell Petroleum OP09-S1 lenses of siliceous cemented very fine grained sandstone; no oil odor; trace oil staining; dull yellow sample fluorescence (10%-20%); very faint yellow to milky white solvent cut. Sand/Sandstone(11750-11850) = sample contains mostly translucent to clear, milky white, light gray and light greenish gray hues; upper very fine to upper fine to lower medium to trace upper medium; well to moderately well sorted; subangular to subrounded to trace angular and rounded; moderate to high sphericity; trace grains appear frosted; thick beds of loose dis-aggregated quartz sand with thin lenses of siliceous cemented very fine grained sandstones interbedded with thinner beds of sandy siltstone; trace oil staining; no odor; 10% patchy dull yellow sample fluorescence. N SAND-3 11867.0' MD/-3733.4' TVDSS Siltstone(11850-11930) = medium light gray to medium gray to light brownish hues; mostly soft to mushy; stiff to crumbly tenacity; irregular fracture; amorphous cuttings habit; dull earthy lusty; mostly silty texture to slightly gritty with increased sandy content; thin sandy siltstone interbedded with thicker beds of loose disaggregated quartz sand; no oil odor; trace oil staining; dull yellow sample fluor-escence (10%- 20%); very faint yellow to milky white solvent cut. Sand/Sandstone (11930-12000) = sample contains mostly translucent to clear, milky white, light gray and light greenish gray hues; upper very fine to upper fine to lower fine to trace upper fine; well to very well sorted; sub-rounded to subangular trace rounded; high sphericity; no odor; 30%-40% oil staining; 60% even dull yellow sample fluorescence with 40% patchy bright yellow; instantaneous milky white cut fluorescence; light brown to brown cut; dull yellow residual fluorescence. N SAND BOTTOM 12017.0' MD/-3750.6'TVDSS Siltstone(12000-12100) = medium light gray to medium gray to light brownish hues; soft to mushy to pasty; slightly pulverulent tenacity; irregular fracture; amorphous cuttings habit; greasy waxy to slightly dull luster; silty to somewhat smooth texture to gritty in part; siltstone cuttings grade from clayey siltstone to silty claystone; thinner beds of clayey silt-stone interbedded with thicker beds of loose disaggregated quartz sand and thin lenses of siliceous cemented very fine grained sandstone; no oil odor; trace oil staining; patchy bright yellow sample fluorescence (30%-40%); streaming milky white straw solvent cut. Sand/Sandstone (12100-12200) = sample contains a slurry of translucent to clear, milky white, light gray and light greenish gray hues; predominantly quartz sand matrix; lower very fine to lower fine grained with trace upper fine; well to moderately well sorted; subrounded to rounded to trace sub-angular; moderate to high sphericity; thicker beds of loose disaggregated quartz sand interbedded with thinner beds of clayey siltstones; abundant brownish black to black, very fine grain mineral/lithics; trace orangish pink to pale yellowish orange calcareous shell fragments; trace dark gray to grayish black siliceous cherty grains; no odor present; trace oil staining; 30%-40% patchy yellow sample fluorescence; streaming milky white cut fluorescence; light straw to straw visible cut. Siltstone(12200-12300) = dark gray to medium gray, and light gray, with some brownish gray; mostly stiff to moderately firm; brittle to dense; irregular fracture; amorphous cuttings habit; greasy waxy to slightly dull luster; silty to somewhat smooth texture to gritty in part; grades from silty sandstone to sandy siltstone; thin beds of sandy siltstone interbedded with thicker beds of loose disaggregated quartz sand and thin lenses of siliceous cemented very fine grained sandstone; no oil odor; trace oil staining; dull yellow sample fluorescence (40%-50%); very faint yellow to milky white solvent cut. Sand/Sandstone (12300-12410) = clear to translucent, with some white, light gray, very pale blue, dark yellowish orange, and light greenish gray hues; predominantly quartz sand matrix with abundant dark colored lithic fragments; upper very fine to upper fine grain sand; well sorted; very well rounded to subrounded, with some very angular to subangular; moderate sphericity; some grains appeared to be 26 CANFIG eni Enii Petroleum 0P09-S1 slightly frosted in places; thick beds of loose unconsolidated quartz sand, with thinner lenses of very fine grained calcareous cemented friable sandstone, interbedded with thinner beds of sandy siltstones; the siltstones are stained with old petroleum hydrocarbons, which have a bright yellow sample fluorescence, approximately 30%-40%; instantaneous bright white solvent cut with white to light straw visible stream. LOWER N MARKER 12440.0' MD/-3795.9' TVDSS Siltstones (12410-12520) = medium gray dark gray with some blackish gray; to light gray and dark gray; mostly very firm to stiff; brittle to dense; to brittle; mostly irregular fracture; platy cuttings habit; greasy to waxy luster; predominantly silty texture with some very gritty in places, resulting from an increase in the sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand and thin lenses of calcareous cemented very fine grained, friable sandstone; bright yellow sample fluorescence, approximately 25%-35%; instantaneous white to bright yellow solvent cut; very faint petroleum hydrocarbon odor; no free oil in sample; poor to fair sample porosity. N SEQUENCE BASE 12560.0' MD/-3808.6' TVDSS Claystone(12520-12580) = light gray to brownish gray and grayish brown; mushy to slimy; soft to crumbly; irregular fracture; amorphous cuttings habit; earthy to dull; very clayey to slightly gritty; very thin beds of claystones interbedded with thicker beds of loose uncemented quartz sand and thin lenses of calcareous cemented sandstones and sandy siltstones. Sand/Sandstone(12580-12700) = mostly translucent to clear, with some light pale blue, dark yellowish orange, light greenish gray, light gray and white hues; predominantly quartz sand matrix with dark colored lithics; upper very fine to upper fine grain; well sorted; very well rounded to subrounded, with some very angular to subangular; moderate sphericity; some grains were very polished or frosted; very thick beds of loose unconsolidated quartz sand, with thinner lenses of very fine grained calcareous cemented sandstone, interbedded with thinner beds of sandy siltstones; the siltstones were slightly stained with petroleum hydrocarbons; bright yellow sample fluorescence, approximately 25%-35%; instantaneous white to straw yellow solvent cut; very slight petroleum hydrocarbon odor; no free oil in sample. FAULT#1 12732.0' MD/-3826.5' TVDSS Claystone (12700-12780) =grayish brown to brownish gray with some light gray and light brown; pasty to mushy; predominantly soft to crumbly; irregular fracture; amorphous cuttings habit; earthy to dull; very clayey to slightly gritty; very thin beds of claystones interbedded with thicker beds of loose uncemented quartz sand and thin lenses of calcareous cemented sandstones and thinner beds of sandy claystones; no visible sample fluorescence was observed in the claystones. Siltstone(12780-12890) = dark gray to light gray with some brownish gray; predominantly stiff to somewhat clumpy; mostly brittle with some slightly dense; irregular fracture; mostly amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some very gritty, because of increasing sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand, and thin lenses of calcareous cemented very fine grained friable sandstone; some pyrite crystals were observed throughout the sample, bright yellow sample fluorescence was observed, approximately 30%-40%; instantaneous milky white to straw yellow solvent cut. Sand/Sandstone(12890-13020) = mostly translucent to clear with white, light gray, dark yellowish orange, light greenish gray, and very pale blue hues; mostly quartz sand matrix with abundant dark colored lithic fragments throughout sample; upper very fine to upper fine with some upper and lower medium grain sand; moderately sorted; very well rounded to very angular with some subrounded to 27 CANRIG Uni.i.iNC Trx:N ni...:v I.ri>. eni Ena Petroleum OP09-S1 subangular; moderate sphericity; some grains appeared to be polished or frosted; very thick beds of loose unconsolidated quartz sand, with thinner lenses of very fine grained calcareous cemented sandstone, interbedded with thinner beds of sandy siltstones; the siltstones were slightly stained with petroleum hydrocarbons; bright yellow sample fluorescence, approximately 60%-70%; instantaneous white to straw yellow solvent cut; slight petroleum odor; no free oil in sample. 28 BRIG en' EnO Petroleum OP09-S1 OA SAND TOP 12948.0' MD/-3850.3' TVDSS Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 446 5 240 543 1 235 PEAKS Depth TG C1 C2 C3 C4I C4N C5I C5N 14176 543 14267 596 332 177 223 173 118 20391 462 86317 813 453 242 304 235 161 OA SUBLAYER 2 13054.0' MD/-3861.8'TVDSS Claystone(13020-13090) = grayish brown, light brown, light gray to dark gray; mushy to pasty; soft to brittle; irregular fracture; amorphous cuttings habit; earthy to dull; very clayey to slightly gritty; very thin beds of claystones interbedded with thicker beds of loose uncemented quartz sand and thin lenses of calcareous cemented sandstones and thinner beds of sandy claystones; no visible sample fluorescence was observed in the claystones. OA SUBLAYER 3 13106.0' MD/-3867.2' TVDSS Sand/Sandstone(13090-13220) = mostly translucent to clear with white, light gray, dark yellowish orange, light greenish gray, and very pale blue hues; mostly quartz sand matrix with abundant dark colored lithic fragments throughout sample; upper very fine to upper fine with some upper and lower medium grain sand; moderately sorted; subangular to subrounded to some angular; moderate to high sphericity; few grains appear frosted; thinner interbedded siltstones are slightly stained with petroleum hydro-carbons; approximately 60%-70% bright yellow sample fluorescence; instantaneous white to dull yellow cut fluorescence; no free oil in sample. 9%" CASING SHOE 13195.0' MD/-3875.4' TVDSS TD 121/4" BOREHOLE 13220.0' MD/-3876.8'TVDSS Sand (13220-13340) = predominantly translucent to clear, with some white, light gray, dark gray, light greenish gray, pale blue, and milky white hues; mostly quartz grains sand matrix, with abundant dark colored lithic fragments throughout; upper very fine to upper fine with some lower medium grain; moderately sorted; very well rounded to very angular with some subrounded to very subangular; moderate sphericity; some grains appeared to be polished or frosted; very thick beds of loose unconsolidated quartz sand interbedded with thinner beds of sandy slightly clayey siltstones. Siltstone(13340-13410) = dark gray to light gray with some brownish gray, and grayish brown; mostly mushy to stiff; very brittle to somewhat dense; mostly irregular fracture; platy cuttings habit; greasy to waxy luster; predominantly silty texture with some very gritty in places, resulting from an increase in the sand concentrations; thinner beds of sandy siltstones interbedded with very thick beds of mostly loose unconsolidated quartz sand. Sand (13410-13490) =translucent to clear, with some milky white, light gray, dark gray, white, very pale blue, light greenish gray hues; predominantly quartz sand matrix with abundant dark colored lithic fragments throughout; upper very fine to upper fine grain sand; fair to very well sorted; very angular to very 29 C:ANRIG eni Eni Petroleum OP09-S1 well rounded with some subangular to subrounded; moderate sphericity; some grains appeared to be slightly frosted to impacted in places; fair to good sample porosity. Siltstone(13490-13560)= brownish gray to dark gray, black, brownish black; predominantly stiff to somewhat clumpy; mostly brittle with some slightly dense; irregular fracture; mostly amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some very gritty, because of increasing sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand; poor to fair sample porosity. Sand (13560-13650) = predominantly clear to translucent with some milky white, light gray, dark gray, dark yellowish orange, milky white hues; mostly quartz sand matrix; lower very fine to upper fine; very well sorted throughout; very well rounded to very angular with some very subrounded to very subangular; predominantly moderate sphericity; some grains appeared to be polished or frosted; very thick beds of loose unconsolidated quartz sand interbedded with thinner beds of sandy slightly clayey siltstones; very poor to fair sample porosity. Siltstone(13650-13720) = dark gray to blackish gray with some grayish brown and brownish gray; slightly stiff to somewhat firm; brittle to slightly dense; irregular fracture; mostly amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some very gritty, because of increasing sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand; poor sample porosity. Sand (13720-13810) = predominantly translucent to clear with some light to dark gray, white, very pale blue, milky white and light bluish gray hues; predominantly quartz sand matrix with abundant dark colored lithic fragments throughout sample; lower very fine to upper fine; very well sorted throughout; very well rounded to very angular with some very subrounded to very subangular; somewhat moderate sphericity; some grains appeared to be polished or frosted; very thick beds of loose unconsolidated quartz sand interbedded with thinner beds of sandy slightly clayey siltstones; very poor to fair sample porosity. Siltstone (13810-13880)= grayish brown to dark gray with some grayish black; stiff to somewhat firm; brittle to slightly dense; irregular fracture; mostly amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some very gritty, because of increasing sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand; poor to fair sample porosity. Sand (13880-13970) = clear to translucent, with some light gray, dark gray, white, dark yellowish orange, light pale blue and milky white hues; predominantly quartz sand matrix; lower very fine to upper fine; very well sorted throughout; rounded to very angular with some very subrounded to very subangular; somewhat moderate sphericity; some grains appeared to be polished or frosted; very thick beds of loose unconsolidated quartz sand interbedded with thinner beds of sandy slightly clayey siltstones; very poor to fair sample porosity. Siltstone(13970-14020) = brownish gray to dark gray with some black and grayish black; mostly firm to stiff; irregular fracture; amorphous cuttings habit; earthy to dull; very clayey to slightly gritty; very thin beds of claystones interbedded with thicker beds of loose uncemented quartz sand; poor sample porosity. Sand (14020-14100) =translucent to clear, with white, light gray, light pale blue, dark yellowish orange hues; predominantly quartz sand matrix with abundant dark colored lithic fragments; lower very fine to upper fine; very well sorted throughout; very well rounded to very angular with some very subrounded to very subangular; somewhat moderate sphericity; some grains appeared to be frosted or polished; very thick beds of loose unconsolidated quartz sand interbedded with thinner beds of sandy slightly clayey siltstone; very poor to fair sample porosity. Siltstone(14100-14160) = black to grayish black with some grayish brown and brownish gray; stiff; crumbly tenacity; irregular fracture; amorphous cuttings habit; dull earthy lusty; mostly silty texture to slightly gritty with increased sand content; thin sandy siltstone interbedded with thicker beds of loose disaggregated quartz sand; fair to poor sample porosity. Sand (14160-14250) =translucent to clear, with some white, light gray, milky white, dark yellowish orange, light pale blue and greenish gray hues; mostly quartz sand matrix throughout; lower very fine to upper fine; 30 C:ANRIG eni Enil Petroleum OP09-S1 very well sorted throughout; very well rounded to very angular with some very subrounded to very subangular; somewhat moderate sphericity; some grains appeared to be polished or frosted; very thick beds of loose unconsolidated quartz sand interbedded with thinner beds of sandy slightly clayey siltstone; very poor to fair sample porosity. Siltstone(14250-14320) = brownish gray to dark brown, and dark gray; stiff to somewhat firm; brittle to slightly dense; irregular fracture; mostly amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some very gritty, because of increasing sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand; poor to fair sample porosity. Sand (14320-14390) = predominantly clear to translucent, with milky white, light gray, white, dark yellowish orange, pale blue, and greenish gray hues; predominantly quartz sand matrix with abundant dark colored lithic fragments throughout sample; lower very fine to upper fine; very well sorted throughout; very well rounded to very angular with some very subrounded to very subangular; somewhat moderate sphericity; some grains appeared to be polished or frosted; very thick beds of loose unconsolidated quartz sand interbedded with thinner beds of sandy slightly clayey siltstone; very poor to fair sample porosity; light straw yellow sample fluorescence above obm fluorescence. OA SUBLAYER 3 14398.0' MD/-3866.5' TVDSS Siltstone (14390-14500) = brownish gray to dark gray and grayish black; predominantly stiff to somewhat clumpy; mostly brittle with some slightly dense; irregular fracture; mostly amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some very gritty, because of increasing sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand; poor to fair sample porosity. Sand (14500-14600) = predominantly translucent to clear, with some dark yellowish orange, light gray, white, light pale blue, and light greenish gray hues; mostly quartz sand matrix; lower very fine to upper fine grain sand; moderately well sorted throughout; very well rounded to very angular with some very subrounded to very subangular; somewhat moderate sphericity; some grains appeared to be polished or frosted; very thick beds of loose unconsolidated quartz sand interbedded with thinner beds of sandy slightly clayey siltstone; very poor to fair sample porosity; light straw yellow sample fluorescence above obm fluorescence. OA SUBLAYER 2 14547.0' MD/-3860.9'TVDSS Siltstone(14600-14670) = brownish gray to blackish brown and dark gray; somewhat stiff to very slightly clumpy; mostly brittle with some slightly dense; irregular fracture; mostly amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some very gritty, because of increasing sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand; poor to fair sample porosity. Sand (14670-14760) = sample consists mostly of translucent to clear, with light gray, white, and light greenish gray hues; predominantly quartz sand matrix; lower very fine to lower fine with some upper fine grain; moderately well to well sorted throughout interval; well rounded to subrounded to some subangular; moderate sphericity; some grained appear to be slightly polished; scattered brownish black to black very fine grained lithics; very thick beds of loose quartz sands interbedded with thinner beds of sandy siltstone; fair sample porosity; obm odor; trace to very slight oil staining; light yellow sample fluorescence only slightly above obm fluorescence. Siltstone(14760-14830) = brownish gray to blackish brown and dark gray; very slightly clumpy to stiff to some slightly hard; brittle to dense tenacity irregular fracture; predominantly amorphous cuttings habit; dull earthy luster; mostly a silty texture with some slightly gritty cuttings due to increase in sand concentrations; 31 C:ANRIG I>aii.i.i n:Tr:<:Hv ii.i n:r I:rig. II VOI emm Enll Petroleum OP09-S1 thin beds of sandy siltstone interbedded with thicker beds of loose quartz sands; poor to fair sample porosity. Sand (14830-14920) = sample consists mostly of translucent to clear, with light gray, milky white, and light olive gray hues; predominantly quartz sand matrix; lower very fine to lower fine with some upper fine grain; well to moderately well sorted throughout; well rounded to subrounded with some angular and subangular; moderate sphericity; trace grains appear slightly polished; scattered brownish black to black very fine grained lithics; very thick beds of loose quartz sands interbedded with thinner beds of sandy siltstone; fair sample porosity; obm odor; trace to very slight oil staining; light yellow sample fluorescence only slightly above obm fluorescence. Siltstone(14920-14990) = cuttings are mainly brownish gray to blackish brown and dark gray; slightly clumpy to stiff to slightly hard; brittle to dense tenacity; irregular fracture; mostly amorphous cuttings habit; dull earthy to slightly waxy luster; mostly silty texture to slightly gritty in part where higher sand concentration occurs; thin beds of sandy siltstone interbedded with thicker beds of loose quartz sand; poor to fair sample porosity. Sand (14990-15090) = sample contains mainly translucent to clear, with light gray, milky white, and light olive gray hues; predominantly quartz sand matrix; lower very fine to lower fine with some trace upper fine grain; well to slightly moderately well sorted throughout; well rounded to some angular with subrounded and subangular; moderate sphericity; trace grains appear slightly polished or frosted; scattered brownish black to black very fine grained lithics; very thick beds of loose unconsolidated quartz sands interbedded with thinner beds of sandy siltstone; fair sample porosity; obm odor; very slight to trace oil staining; light yellow sample fluor-escence only slightly above obm fluorescence. Siltstone(15090-15150) = cuttings are mainly brownish gray to medium gray and dark gray; slightly clumpy to stiff to some hard; crumbly to dense tenacity; irregular fracture; mostly amorphous to earthy cuttings habit; dull earthy to slightly waxy luster; mostly silty texture to slightly gritty in part; thin beds of sandy siltstone interbedded with thicker beds of loose quartz sand; poor to fair sample porosity. Sand (15150-15250) = predominantly translucent to clear, with light gray, milky white, and light olive gray hues; predominantly quartz sand matrix; lower very fine to upper fine grained; well to moderately well sorted throughout interval; well rounded to subrounded with some angular and subangular in part; moderate sphericity; some grains appear slightly frosted; scattered brownish black to black very fin grained lithics; large thick beds of loose unconsolidated quartz sands interbedded with thinner beds of dark gray siltstones; fair sample porosity; obm odor; very slight to trace oil staining; light yellow sample fluor-escence only slightly above obm fluorescence. Siltstone(15250-15300) = mostly brownish gray to medium gray and dark gray; slightly clumpy to stiff; brittle dense tenacity; irregular fracture; amorphous cuttings habit; dull earthy luster; mainly silty texture with some slightly gritty; thin siltstone inter- bedded with thicker beds of loose quartz sands; poor sample porosity. Sand (15300-15400) = predominantly translucent to clear, with light gray, milky white, and light olive gray hues; predominantly quartz sand matrix; lower very fine to upper fine grained; well to moderately well sorted throughout interval; well rounded to subrounded with some angular and subangular in part; moderate sphericity; some grains appear slightly frosted; scattered brownish black to black very fine grained lithics; large thick beds of loose unconsolidated quartz sands interbedded with thinner beds of dark gray siltstones; fair sample porosity; obm odor; very slight to trace oil staining; light yellow sample fluor-escence only slightly above obm fluorescence. Siltstone(15400-15460) = cuttings are mainly brownish gray to medium gray and dark gray; slightly clumpy to stiff to some hard; crumbly to dense tenacity; irregular fracture; mostly amorphous to earthy cuttings habit; dull earthy to slightly waxy luster; mostly silty texture to slightly gritty in part; thin beds of sandy siltstone interbedded with thicker beds of loose quartz sand; poor to fair sample porosity. OA SUBLAYER 2 15472.0' MD/-3862.1' TVDSS 32 CANRIG eni Evil Petroleum OP09-S1 Sand (15460-15550) = slurry consists of translucent to clear, with light gray, milky white, and light greenish gray hues; predominantly quartz sand matrix; lower very fine to upper fine grained; well to moderately well sorted throughout; well rounded to angular with subrounded and subangular; moderate sphericity; common brownish black to black very fine grained lithics; thicker beds of loose unconsolidated quartz sand interbedded with thinner beds of sandy siltstone; fair sample porosity; obm odor; very slight to trace free oil in sample; light yellow sample fluor-escence only slightly about obm sample fluorescence. Siltstone (15550-15620)= brownish gray to medium gray and dark gray; slightly clumpy to stiff consistency; brittle to dense tenacity; irregular fracture; amorphous cuttings habit; dull earthy luster; silty to slightly gritty texture thin beds of siltstone interbedded with larger beds of loose quartz sand; poor sample porosity. Sand (15620-15730) = predominantly translucent to clear, with light gray, milky white, and light olive gray hues; predominantly quartz sand matrix; lower very fine to upper fine grained; well to moderately well sorted throughout; well rounded to subrounded with some angular and subangular in part; moderate sphericity; some grains appear slightly frosted and polished; scattered brownish black to black very fine grained lithics; abundant to common orangish pink to pale yellowish orange shell fragments; large thick beds of loose unconsolidated quartz sands interbedded with thinner beds of dark gray silt-stones; fair sample porosity; obm odor; trace amounts of free flowing oil in sample and on shaker screens; light yellow sample fluorescence only slightly above obm fluorescence. Siltstone (15730-15800) = cuttings are mainly brownish gray to medium gray and dark gray; slightly clumpy to stiff to somewhat hard; brittle to dense to slightly crumbly; irregular fracture; primarily amorphous to slightly earthy cuttings habit; dull earthy luster; mostly silty texture to slightly gritty in part; thin beds of sandy siltstone interbedded with thicker beds of loose unconsolidated quartz sands; poor to fair sample porosity. OA SUBLAYER 3 15841.0' MD/-3870.0' TVDSS Sand (15800-15900) = primarily translucent to clear, with light gray, milky white, and light greenish gray; predominantly quartz sand matrix; lower very fine to lower fine with some upper fine grain; moderately well sorted; rounded to angular with some subangular and subrounded in part; moderate sphericity; some grains appear slightly frosted and polished; scattered brownish black to black very fine grained lithics; common to trace orangish pink to pale yellowish orange shell fragments; large thick beds of loose unconsolidated quartz sands interbedded with thinner beds of dark gray silt-stones; fair sample porosity; obm odor; trace amounts of free flowing oil in sample and on shaker screens; light yellow sample fluorescence only slightly above obm fluorescence. Siltstone(15900-15950) = brownish gray to medium gray and dark gray; slightly clumpy to mushy to stiff; brittle to dense tenacity; irregular fracture; amorphous cuttings habit; dull earthy luster; silty to slightly gritty texture thin beds of siltstone interbedded with larger beds of loose quartz sand; poor sample porosity. Sand (15950-16070) = mostly clear to translucent, with some light gray, white, light greenish gray, pale blue, and dark yellowish orange hues; predominantly quartz sand matrix, with abundant dark colored lithic fragments throughout sample; mostly lower very fine to lower fine with some upper fine grain; moderately well to well sorted throughout; well rounded to subrounded to some subangular; moderate sphericity; some grains appeared to be slightly polished; scattered brownish black to black very fine grained lithics; very thick beds of loose quartz sands interbedded with thinner beds of sandy siltstone; fair sample porosity; obm odor; trace to very slight oil staining; light yellow sample fluorescence only slightly above obm fluorescence. Siltstone (16070-16150) = medium gray to dark gray with some brownish gray; very slightly clumpy to stiff to some slightly hard; brittle to dense tenacity irregular fracture; predominantly amorphous cuttings habit; dull earthy luster; mostly a silty texture with some slightly gritty cuttings due to increase in sand 33 BRIG eni Eni Petroleum OP09-S1 concentrations; thin beds of sandy siltstone interbedded with thicker beds of very fine grain mostly unconsolidated quartz sand; fair to poor apparent sample porosity; trace to very slight oil staining; light yellow sample fluorescence, slightly above obm; obm odor throughout sample. Sand (16150-16250) = predominantly translucent to clear, with some white, light gray, light pale blue, and dark yellowish orange hues; mostly quartz grain sand matrix; lower very fine to upper fine grain; very well sorted throughout sample; very well rounded to very angular with some subrounded to very subangular; moderate sphericity; some grains appeared to be slightly frosted; very thick beds of loose uncemented quartz sand interbedded thinner beds of sandy siltstone; poor sample porosity; obm odor; trace to very slight oil staining; light yellow sample fluorescence only slightly above obm fluorescence. Siltstone(16250-16330) = dark gray to light gray with some brownish gray and grayish brown, light brown; mostly pasty to stiff; brittle to dense; irregular fracture; predominantly amorphous cuttings habit; dull to earthy; mostly a silty texture with some gritty due to the increase in sand concentrations; thin beds of sandy siltstone interbedded with thicker beds of very fine grain mostly uncemented quartz sand; fair to poor apparent sample porosity; trace to very slight oil staining; light yellow sample fluorescence, slightly above obm; obm odor throughout sample. Sand (16330-16440) = predominantly translucent to clear with some white, light gray, dark yellowish orange, and very pale blue hues; predominantly quartz sand matrix, with abundant dark colored lithic fragments throughout sample; lower very fine to upper fine grain; very well sorted throughout sample; very well rounded to very angular with some subrounded to very subangular; moderate sphericity; some grains appeared to be slightly polished; very thick beds of loose uncemented quartz sand interbedded thinner beds of sandy siltstone; poor sample porosity; obm odor; slight trace oil staining; light yellow sample fluorescence only slightly above obm fluorescence. Siltstone (16440-16520)= light brown to medium brown with some light gray, brownish gray and grayish brown; predominantly stiff to somewhat mushy; mostly brittle with some slightly dense; irregular fracture; mostly amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some very gritty, because of increasing sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand; poor to fair sample porosity. Sand (16520-16630) =translucent to clear with some white, light gray, pinkish gray, dark yellowish orange, and light greenish gray hues; predominantly quartz sand matrix, with abundant dark colored lithic fragments throughout sample; mostly lower very fine to lower fine with some upper fine grain; moderately well to well sorted throughout; well rounded to subrounded to some subangular; moderate sphericity; some grains appeared to be slightly frosted; very thick beds of mostly loose uncemented quartz sand interbedded with very thin lenses of very fine grained siliceous cemented sandstones and thin beds of sandy siltstones; poor to fair apparent sample porosity; very strong obm odor; bright yellow sample fluorescence slightly above obm fluorescence. Siltstone (16630-16700) = medium to light gray, with light brown, brownish gray and grayish brown; predominantly pasty to stiff; brittle to dense; irregular fracture; predominantly amorphous cuttings habit; dull to earthy; mostly a silty texture with some gritty due to the increase in sand concentrations; thin beds of sandy siltstone interbedded with thicker beds of very fine grain mostly uncemented quartz sand; fair to poor apparent sample porosity. Sand (16700-16800) = predominantly translucent to clear with light gray, white, dark yellowish orange, pinkish gray, and light greenish gray hues; mostly lower very fine to lower fine with some upper fine grain; moderately well to well sorted throughout; well rounded to subrounded to some subangular; moderate sphericity; some grains appeared to be slightly polished; very thick beds of mostly loose uncemented quartz sand interbedded with very thin lenses of very fine grained siliceous cemented sandstones and thin beds of sandy siltstones; poor to fair apparent sample porosity; very strong obm odor; bright yellow sample fluorescence slightly above obm fluorescence. Siltstone (16800-16870)= light brown, brownish gray to grayish brown with some light brownish gray; mostly stiff to mushy; dense to brittle; irregular fracture; predominantly amorphous cuttings habit; dull to earthy; mostly a silty texture with some gritty because of the amount of sand concentrations; thin beds of 34 C:ANRIG eni Eni Petroleum OP09-S1 sandy siltstone interbedded with thicker beds of very fine grain mostly unconsolidated quartz sand; fair to poor apparent sample porosity. Sand (16870-16990) = predominantly clear to translucent, with white, dark yellowish orange, light gray, pinkish gray, and milky white hues; predominantly quartz sand matrix, with abundant dark colored lithic fragments throughout the sample; mostly lower very fine to lower fine with some upper fine grain; moderately well to well sorted throughout; well rounded to subrounded to some subangular; moderate sphericity; some grains appeared to be slightly polished; very thick beds of mostly loose unconsolidated quartz sand interbedded with very thin lenses of very fine grained siliceous cemented sandstones and thin beds of sandy siltstones; poor to fair apparent sample porosity; very strong obm odor; bright yellow sample fluorescence slightly above obm fluorescence. Siltstone(16990-17060) = light brown to brownish gray and grayish brown; predominantly stiff to somewhat mushy; mostly brittle with some slightly dense; irregular fracture; mostly amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some very gritty, because of increasing sand concentrations; thinner beds of sandy siltstones interbedded with loose uncemented quartz sand; poor to fair sample porosity. FAULT A 17010.0' MD/-3869.0' TVDSS Sand (17060-17170) = predominantly clear to translucent, with white, medium light gray, light gray, light olive gray, and milky white hues; predominantly quartz sand matrix, with abundant dark colored lithic fragments throughout the sample; mostly lower very fine to lower fine with some upper fine grain; moderately well to well sorted throughout; well rounded to subrounded to some subangular; moderate sphericity; some grains appeared to be slightly polished; very thick beds of mostly loose unconsolidated quartz sand interbedded with very thin lenses of very fine grained siliceous cemented sandstones and thin beds of sandy siltstones; poor to fair apparent sample porosity; very strong obm odor; bright yellow sample fluorescence slightly above obm fluorescence. Siltstone(17170-17250) = light brown to medium dark gray and brownish gray; predominantly stiff to somewhat mushy; mostly brittle to crumbly some slightly dense; irregular fracture; mostly amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some gritty and trace clayey textures; thinner beds of siltstones interbedded with loose uncemented quartz sand; poor to fair sample porosity. Sand (17250-17350) = predominantly translucent to clear, with white, light gray, light bluish gray, light olive gray, and milky white hues; predominantly quartz sand matrix, with abundant dark colored lithic fragments throughout the sample; mostly lower very fine to lower fine with some upper fine grain; moderately well to well sorted throughout; well rounded to subrounded to trace angular; moderate sphericity; some grains appeared to be slightly polished; very thick beds of mostly loose unconsolidated quartz sand interbedded with thinner beds of sandy siltstones; poor to fair apparent sample porosity; very strong obm odor; bright yellow sample fluorescence slightly above obm fluorescence. Siltstone (17350-17420) = pinkish gray to brownish gray to medium dark gray; predominantly stiff to somewhat mushy; mostly brittle to crumbly some slightly dense; irregular fracture; primarily amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some gritty depending on increased sand content; thinner beds of sandy siltstone interbedded with loose uncemented quartz sand; poor to fair sample porosity. Sand (17420-17530) = predominantly clear to translucent, with white, light bluish gray, light gray, light olive gray, and milky white hues; predominantly quartz sand matrix, with abundant dark colored lithic fragments throughout the sample; mostly lower very fine to lower fine with some upper fine and trace lower medium; moderately to moderately well sorted throughout; well rounded to subrounded with some subangular to trace angular; moderate sphericity; some grains appeared to be slightly polished; very thick beds of mostly loose unconsolidated quartz sand interbedded with thinner beds of sandy siltstones; poor to fair apparent 35 CANING efli Ens Petroleum OP09-S1 sample porosity; very strong obm odor; bright yellow sample fluorescence slightly above obm fluorescence. Siltstone(17530-17600) = medium light gray to brownish gray to dark gray; predominantly stiff to somewhat mushy; mostly crumbly to brittle some slightly dense; irregular fracture; primarily amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some gritty depending on increased sand content; thinner beds of sandy siltstone interbedded with loose uncemented quartz sand; poor to fair sample porosity. Sand (17600-17700) = predominantly clear to translucent, with white, light greenish gray, light gray, light olive gray, and milky white hues; predominantly quartz sand matrix, with abundant dark colored lithic fragments throughout the sample; mostly lower very fine to lower fine with some upper fine grained; moderately to moderately well sorted throughout; well rounded to subrounded with some subangular and trace angular; moderate sphericity; some grains appear to be slightly polished; very thick beds of mostly loose uncemented loose quartz sand interbedded with thinner beds of sandy siltstones; poor to fair apparent sample porosity; very strong obm odor; bright yellow sample fluorescence slightly above obm fluorescence. Sand/Sandstone(17700-17800) = light gray to clear to translucent with greenish to milky white hues; upper very fine to lower fine predominantly; very well sorted; subangular to angular with moderate sphericity; rare muscovite fragments; sandstone is calcareously cemented, firmly friable to easily friable; 3-5% moderate green to light bluish green very fine to fine grains; slight to fragrant oil odor; no visible oil staining on free sand grains; 100% even bright white to yellowish white sample fluorescence; immediate moderately bright white cut fluorescence with dark straw visible cut; pale straw visible residue; faint to dull yellowish white residual fluorescence; all oil indicators skewed by obm; samples are contaminated by safecarb mud additive. Sand/Sandstone(17800-17900) = clear to light gray to very light gray with reddish brown to greenish secondary hues throughout sample interval; upper very fine to lower fine; very well sorted; angular to subangular with moderate sphericity; 5-8% fine black lithics; 3-5% brilliant green to moderate green fine grains; rare muscovite and pyrite; sandstone is calcareously cemented, friable to easily friable; fragrant oil odor; no visible oil staining on free sand grains; 100%even bright white to yellowish white sample fluorescence; slow blooming dull white cut fluorescence; straw visible cut; light pale straw visible residue; moderately bright white residual fluorescence; show skewed by obm; safecarb in samples. OA SUBLAYER 2 17923.0' MD/-3863.1'TVDSS Sand/Sandstone (17900-18000)=clear to very light gray to translucent with brownish to reddish brown to greenish secondary hues; upper very fine to lower fine predominantly; very well sorted; subangular to angular with moderate sphericity; trace muscovite sheet fragments; sandstone is calcareously cemented, easily friable to friable; fragrant oil odor; no visible oil stain on free sand grains; 100% even bright white sample fluorescence; blooming dull white cut fluorescence; straw to dark straw visible cut; light pale straw visible residue; dull yellowish white residual fluorescence; oil show skewed by obm; safecarb contaminates samples. Sand/Sandstone(18000-18100) = clear to light gray to translucent; upper very fine to lower fine primarily; very well sorted; subangular to angular with moderate sphericity; trace muscovite sheet fragments and crystalline pyrite grains in samples; moderate orange pink to pale yellowish orange shell fragments in samples; slight oil odor; no visible oil stain; 100% even bright white sample fluorescence; slow blooming dull white cut fluorescence; straw visible cut; no visible residue; faint white residual fluorescence; oil indicators skewed by obm; samples continue to be contaminated by safecarb mud additive. Sand/Sandstone (18100-18200) = light gray to translucent to very light gray with greenish to reddish brown secondary hues; upper very fine to lower fine; very well sorted; subangular to angular to subrounded with moderate sphericity; sandstone is calcareously cemented, friable to easily friable; trace 36 C ANRIG eni Eni Petroleum OP09-S1 crystalline pyrite grains and muscovite sheet fragments; slight to fragrant oil odor; no visible oil stain; 100% even bright white sample fluorescence; oil shows skewed by obm; samples contain safecarb mud additive. Siltstone(18160-18220) = light olive gray to olive brown to medium gray; easily friable to firmly friable; crumbly with primarily planar fracture; tabular cuttings habit; greasy waxy to dull luster; silty to gritty texture depending upon sand grain content; rare thin black to brownish black laminations in samples. OA SUBLAYER 3 18230.0' MD/-3865.9' TVDSS Sand/Sandstone(18200-18300) =very light gray to translucent to light gray with greenish to reddish brown hues; upper very fine to lower fine primarily with occasional upper fine grains; very well to well sorted; subangular to subrounded with moderate to high sphericity; sandstone is friable to easily friable, calcareously cemented; 100% bright even white sample fluorescence; blooming dull white cut fluorescence; straw visible cut; oil indicators distorted by obm. Sand/Sandstone (18300-18420)= mostly translucent to clear with some light gray, dusky blue, white, and dark yellowish orange hues; predominantly quartz grain sand matrix, with abundant dark colored lithic fragments throughout the sample; mostly lower very fine grain sand to upper fine with the occasional lower medium grain; well sorted; predominantly well rounded to subrounded with some subangular; grains appeared to be slightly frosted; very thick beds of mostly loose unconsolidated quartz sand interbedded with thinner beds of sandy siltstones, and the occasional thin lenses of very fine grained siliceous cemented sandstones; poor to fair apparent sample porosity; very strong obm odor; bright yellow sample fluorescence above obm fluorescence. Siltstone (18420-18490)= light brown to grayish brown and brownish gray; predominantly stiff to somewhat mushy; mostly crumbly to brittle some slightly dense; irregular fracture; primarily amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some gritty depending on increased sand content; thinner beds of sandy siltstone interbedded with loose uncemented quartz sand; poor to fair sample porosity. Sand/Sandstone(18490-18590) = clear to translucent with some very dusky purple, dusky blue, white, light gray, and dark yellowish orange hues; quartz grain sand matrix throughout; mostly lower very fine grain sand to upper fine with the some lower medium grain ; well sorted; very well rounded to subrounded with some subangular; moderate sphericity; some grains appeared to be polished; very thick beds of mostly loose unconsolidated quartz sand interbedded with thinner beds of sandy siltstones, with some very thin lenses of very fine grained siliceous cemented sandstones; poor to fair apparent sample porosity; very strong obm odor; bright yellow sample fluorescence above obm fluorescence. Siltstone(18590-18680) = medium gray to brown with some brownish gray; mostly mushy to somewhat stiff; mostly crumbly to brittle some slightly dense; irregular fracture; primarily amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some slightly gritty due too increasing sand concentrations; mostly thinner beds of sandy siltstones interbedded with very thick beds of mostly loose uncemented quartz sand, and thin lenses of very fine grained siliceous cemented sandstones; poor to fair apparent sample porosity. Sand/Sandstone (18680-18800) = mostly translucent to clear with white, milky white, light gray, dark yellowish orange and dusky blue hues; mostly quartz sand matrix, with abundant dark colored lithic fragments throughout the sample; lower very fine grain sand to upper fine with some lesser amounts of lower medium grain; moderate to well sorted; very well rounded to subrounded with some subangular; moderate sphericity; some grains appeared to be frosted; very thick beds of mostly loose unconsolidated quartz sand interbedded with thinner beds of sandy siltstones, and some very thin lenses of fine grained siliceous cemented sandstones; poor to fair apparent sample porosity; very strong obm odor; bright white yellow sample fluorescence above obm fluorescence. 37 C:ANRIG eni Erd Petroleum OP09-S1 Siltstone(18800-18890) = grayish brown, light to medium brown, and brownish gray; mostly stiff to slightly mushy; mostly crumbly to brittle some slightly dense; irregular fracture; primarily amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some slightly gritty due too increasing sand concentrations; mostly thinner beds of sandy siltstones interbedded with very thick beds of mostly loose unconsolidated quartz sand and thin lenses of very fine grained siliceous cemented sandstones; poor to apparent sample porosity. Sand/Sandstone (18890-19000)= mostly clear to translucent, with some milky white, light gray, dusky blue, dark yellowish orange, and white hues; predominantly quartz sand matrix; mostly lower very fine grain sand to upper fine with the some lower medium grain ; well sorted; very well rounded to subrounded with some subangular; moderate sphericity; some grains appeared to be polished; very thick beds of mostly loose unconsolidated quartz sand interbedded with thinner beds of sandy siltstones, with some very thin lenses of very fine grained siliceous unconsolidated sandstones; poor to fair apparent sample porosity; very strong obm odor; bright yellow sample fluorescence above obm fluorescence. Siltstone(19000-19090) = light brown to medium brown, brownish gray, with some dark gray and grayish black; mostly pasty to slightly stiff; mostly crumbly to brittle some slightly dense; irregular fracture; primarily amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some slightly gritty due to increasing sand concentrations; mostly thinner beds of sandy siltstones interbedded with very thick beds of mostly loose uncemented quartz sand and thin lenses of very fine grained siliceous cemented sandstones; poor to apparent sample porosity. Sand/Sandstone(19100-19210) = clear to translucent, with light gray, white, some milky white, grayish pink, and dark yellowish orange hues; predominantly quartz sand matrix with abundant dark colored lithics; mostly lower very fine grain sand to upper fine with the some lower medium grain ; well sorted; very well rounded to subrounded with some subangular; moderate sphericity; some grains appeared to be frosted; very thick beds of mostly loose unconsolidated quartz sand interbedded with thinner beds of sandy siltstones, with some very thin lenses of very fine grained siliceous unconsolidated sandstones; poor to fair apparent sample porosity; very strong obm odor; bright white yellow sample fluorescence above obm fluorescence. Siltstone (19210-19275)= brown to gray with some grayish brown; predominantly firm to somewhat mushy; mostly crumbly to brittle some slightly dense; irregular fracture; primarily amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some gritty depending on increased sand content; thinner beds of sandy siltstone interbedded with loose uncemented quartz sand; poor to fair sample porosity. Sand/Sandstone(19275-19400) =very light gray to translucent to light gray with reddish to greenish to yellowish brown secondary hues; upper very fine to lower fine predominantly; very well sorted; angular to subangular with moderate sphericity; sandstone is calcareously cemented, friable to firmly friable to easily friable; slight oil odor; no visible oil staining; 100% even bright white sample fluorescence; straw visible cut; all oil indicators distorted by obm; samples contaminated by safecarb mud additive. OA SUBLAYER 3 19388.0' MD/-3845.8' TVDSS Siltstone(19390-19500) = olive gray to olive brown to medium light gray; easily friable to firmly friable; crumbly to brittle; planar to irregular fracture; dull earthy to greasy luster; silty to silty gritty texture varying with sand grain content; thin black to brownish to reddish brown laminations occasionally; cuttings vary between silty sandstone and sandy siltstone. Sand/Sandstone(19400-19550) = light gray to translucent to very light gray to clear to milky white; upper very fine to lower fine predominantly with some upper fine grains; very well to well sorted; subangular to angular with moderate sphericity; sandstone is calcareously cemented, easily friable to firmly friable, grades between silty sandstone and sandy siltstone; pale yellowish orange to moderate orange pink shell fragments throughout sample interval; fine grained black to moderate green to brilliant green lithics, 38 C:ANRIG eni Eni Petroleum OP09-S1 approx 10%; slight oil odor; no visible oil staining on sand grains; 100% even bright white to yellowish white sample fluorescence; blooming moderately bright white cut fluorescence; amber to brown visible cut; medium pale straw to straw visible residue; faint to dull yellow to yellowish white residual fluorescence; oil shows distorted by obm; samples heavily contaminated by safecarb mud additive. Siltstone(19500-19600) = olive gray to medium gray to dusky yellowish brown to brownish gray; easily friable to firmly friable; crumbly to brittle; planar to irregular fracture; earthy dull to greasy luster; silty to gritty texture varying with sand grain content of cuttings; thin brown to reddish brown to black laminations; cuttings grade to sandy siltstone and silty sandstone. Sand/Sandstone(19550-19750) = light gray to clear to very light gray to translucent with reddish to brownish to greenish secondary hues throughout sample interval; upper very fine to lower fine predominantly; very well sorted; subangular to angular with moderate sphericity; sandstone cuttings are friable to firmly friable and are calcareously cemented; black to moderate green to brilliant green lithics; slight oil odor; no visible oil staining; 100% even yellowish white sample fluorescence with immediate moderately bright white cut fluorescence; amber visible cut; light pale straw residue; dull yellowish white residual fluorescence; oil shows skewed by obm; samples continue to be contaminated by safecarb mud additive. Siltstone(19600-19750) = medium gray to olive gray to brownish gray to yellowish brown; friable to easily friable to firmly friable; crumbly and brittle; planar to irregular fracture; earthy to dull luster within cuttings, greasy exterior; silty to gritty texture; thin reddish brown to black to dark brown laminations; cuttings continually grade to sandy siltstone and silty sandstone. OA SUBLAYER 2 19692.0' MD/-3830.6'TVDSS Sand (19750-19850) = clear to very light gray to translucent with reddish to yellowish brown to greenish secondary hues; upper very fine to lower fine with occasional upper fine grains; very well sorted; subangular to angular to subrounded with moderate sphericity; slight oil odor; no visible oil staining on free sand grains; 100% even yellowish white sample fluorescence; blooming moderately bright white cut fluorescence with amber cut; light straw residue; dull yellowish white residual fluorescence; oil indicators distorted by obm; samples contaminated by safecarb mud additive. Sand/Sandstone (19850-19950) = clear to very light gray to translucent with reddish to brownish to yellowish brown to greenish hues; upper very fine to lower fine; very well sorted; subangular to angular to subrounded with moderate sphericity; sandstone is moderately hard to friable and calcareously cemented; slight to no oil odor; no visible oil staining; 10-30% patchy dull yellowish white sample fluorescence; slow blooming faint white cut fluorescence with straw to pale straw cut; no visible residue; very faint white residual fluorescence; oil show skewed by obm; samples heavily contaminated by safecarb mud additive. Sand (19950-20050) = clear to very light gray to translucent with yellowish brown to reddish to greenish secondary hues; upper very fine to lower fine with some upper fine grains; very well to well sorted; subangular to angular primarily with moderate sphericity; moderate orange pink to pale yellowish orange shell fragments in this interval; black to moderate green to brilliant green lithics; no to very slight oil odor; no visible oil staining; 70-100% even dull to moderately bright yellow to yellowish white sample fluorescence; blooming dull white cut fluorescence with amber to brown cut; medium straw visible residue; dull yellowish white residual fluorescence; oil indicators distorted by obm; safecarb mud additive still in samples. OA SUBLAYER 2 20007.0' MD/-3821.0' TVDSS Sand/Sandstone(20050-20100) = clear to light gray to translucent with reddish to brownish to greenish hues; upper very fine to lower fine predominantly; very well sorted; subangular to angular with moderate 39 CANRIG eni Enn Petroleum OP09-S1 sphericity; pale yellowish orange to moderate orange pink shell fragments becoming more abundant; no oil odor or stain; this sample interval is 70-80% safecarb mud additive. Siltstone (20100-20190) = medium gray to dark gray with some grayish brown; mostly pasty to slightly firm; mostly crumbly to brittle some slightly dense; irregular fracture; mostly amorphous cuttings habit; dull to earthy luster with some waxy; predominantly silty texture with some slightly gritty due to increasing sand concentrations; mostly thinner beds of sandy siltstones interbedded with very thick beds of mostly loose uncemented quartz sand and thin lenses of very fine grained siliceous, slightly calcareous cemented sandstones; poor apparent sample porosity. Sand/Sandstone (20190-20320) = mostly clear to translucent with some white, light gray, milky white and pinkish gray hues; predominantly quartz sand matrix, with abundant dark colored lithic fragments throughout sample; mostly lower very fine grain sand to upper fine with the some lower medium grain ; well sorted; very well rounded to subrounded with some subangular; moderate sphericity; some grains appeared to be frosted; very thick beds of mostly loose unconsolidated quartz sand interbedded with thinner beds of sandy siltstones, with some very thin lenses of very fine grained siliceous uncemented sandstones; poor to fair apparent sample porosity; no petroleum odor above obm; no residual oil stains were observed on sand grains; 40%-60% even dull yellow to white sample fluorescence above obm residual fluorescence; delayed very faint white streaming solvent cut. OA SUBLAYER 3 20245.0' MD/-3825.7' TVDSS Siltstone(20320-20420) =dark gray to medium gray with some light gray, grayish brown and brownish gray; moderately firm to somewhat mushy; very dense; mostly irregular fracture; predominantly amorphous cuttings habit dull to earthy luster with some waxy; predominantly silty texture with some slightly gritty due to increasing sand concentrations; mostly thinner beds of sandy siltstones interbedded with very thick beds of mostly loose unconsolidated quartz sand and thin lenses of very fine grained siliceous, slightly calcareous cemented sandstones; poor apparent sample porosity. Sand (20420-20510) = predominantly very light gray; clast size ranges from medium lower to very fine upper; mean size is fine grained; moderate to some poorly developed sphericity; scattered discoidal grains; moderate with some poor local sorting; impacted to pitted textures; sub mature nature; scattered very fine grained sandstone loosely consolidated; overall unconsolidated arenaceous clean sand; no visible matrix grain supported; composed of quartz with trace lithics; trace disminated and aggregated pyrite; rare framboidal pyrite in parts; fair to mostly good estimated porosity and permeability; scattered grayish orange siltstone as possible thin beds and/or cavings; trace shell fragments; continued oil base mud fluorescence contamination. Siltstone(20510-20600) = light brownish gray to light gray and various hues of both colors; moderate induration; crunchy; stiff; moderate cohesion; no adhesiveness; sub planar fracture; sub platy to sub patchy habit; dull earthy luster; gritty to silty to slightly abrasive in parts; occurs as thin to thick beds with distinct black carbon fines interbedded with some planar orientation in parts; some siltstone is grading to a very fine grained lower sandstone with matrix supported and becoming dense. Sand (20600-20700) = clear to very light gray to translucent with reddish to greenish to yellowish brown hues; upper very fine to lower fine predominantly with grain size approaching lower medium; well to very well sorted; subangular to angular with generally moderate sphericity; pale yellowish orange to moderate orange pink shell fragments; trace pyrite crystalline grains; slight oil odor; no visible oil staining; 100% even moderately bright yellowish white sample fluorescence; blooming dull white cut fluorescence; amber cut; medium straw residue; dull yellowish white residual fluorescence; oil shows skewed by obm; samples contaminated by safecarb mud additive. Sand (20700-20800)=very light gray to translucent with milky white to reddish to brownish hues; upper very fine to upper fine with some lower medium grains in samples; well sorted; angular to subangular with moderate sphericity; sandstone cuttings are calcareously cemented; trace pyrite; shell fragments in 40 C:ANRIG rgis eni EnII Petroleum OP09-S1 sample interval; no oil odor; no oil staining; no sample fluorescence; immediate faint white cut fluorescence; straw visible cut; no visible residue; faint yellow residual fluorescence; oil shows skewed by obm; samples heavily contaminated by safecarb mud additive. Sand (20800-20900) = light gray to clear to milky white with reddish to brownish to greenish secondary hues throughout sample interval; upper very fine to upper fine predominantly with some medium grains; well sorted; subangular to angular to subrounded with moderate sphericity; some easily friable to friable calcareously cemented sandstone cuttings; trace pyrite; moderate orange pink to pale yellowish orange shell fragments this interval; faint oil odor; no visible oil staining; slow blooming dull white cut fluorescence; dark straw to straw visible cut; no visible residue on spot dish; faint yellow residual fluorescence; oil indicators are distorted by obm; this sample interval was very heavily contaminated by safecarb mud additive, approximately 75-85%. Sand (20900-21000) = clear to very light gray to milky white to translucent with reddish to grayish to brownish hues; upper very fine to upper fine primarily; well sorted; subangular to angular to subrounded with moderate sphericity; trace amounts of pyrite in samples; pale yellowish orange to moderate orange pink shell fragments throughout interval; soft to easily friable fine moderate green to brilliant green grains; faint oil odor; no visible oil staining on free sand grains; 100% even dull white sample fluorescence, in part due to safecarb; streaming dull to moderately bright white cut fluorescence; dark straw to light amber visible cut; light straw to pale straw visible residue; faint yellow residual fluorescence; oil indicators distorted by obm and safecarb mud additive; samples continue to be heavily contaminated by safecarb. Sand (21000-21100) = clear to light gray to milky white to translucent with reddish to yellowish brown hues; upper very fine to upper fine predominantly with some medium grains; well sorted; subangular to angular to subrounded with moderate sphericity; trace pyrite; slight oil odor; no visible oil stain; 100%dull yellowish white sample fluorescence; amber visible cut; light pale straw residue; dull yellow residual fluorescence; oil shows skewed by obm; samples continue to contain safecarb. Sand (21100-21200) =very light gray to clear to light gray to milky white with reddish to greenish to bluish secondary hues throughout sample interval; upper very fine to upper fine primarily with some medium grains; well sorted; angular to subangular to subrounded with moderate sphericity; trace amounts of crystalline pyrite grains; moderate orange pink to pale yellowish orange shell fragments becoming slightly more abundant as depth increases; slight oil odor; no visible oil staining; 100% even dull yellowish white sample fluorescence with blooming dull white cut fluorescence; amber visible cut; light pale straw visible residue; dull yellow residual fluorescence; oil indicators distorted by obm; samples continue to be contaminated by safecarb mud additive. Sand (21200-21300) = light gray to clear to very light gray to milky white with reddish to brownish hues; upper very fine to lower fine predominantly with grain size up to lower medium; well sorted; subangular to angular to subrounded with moderate sphericity; trace pyrite in samples; contains soft to friable calcareously cemented sandstone cuttings; slight oil odor; no visible oil staining on sand grains; 100% even dull yellowish white sample fluorescence; blooming dull white cut fluorescence; amber to light amber cut; light pale straw visible residue; dull yellow residual fluorescence; oil shows skewed by obm; samples contaminated by safecarb mud additive. Sand (21300-21400) = very light gray; clast size ranges from medium upper to very fine upper with trace coarse lower and very fine lower at 21350'; becoming finer(medium lower to very fine lower)from 21350 to 21400'; sub angular to sub round; moderate developed sphericity; mean size faction is fine upper to medium lower; moderate to poor sorting; impacted to pitted textures; sub mature nature; non to weak silicic cement; unconsolidated with some grading to very fine grained sandstones weakly consolidated with grain and some matrix support decreasing sandstone content with depth; quartz with trace lithics; 10% shell fragments @ 21350'; fair porosity and permeability; any oil shows contaminated with oil base mud. Sand (21400-21450)=very light gray; clast size range medium upper to very fine upper; sub angular to sub round; moderate developed sphericity; mean size faction is fine grained; moderate to poor sorting; impacted to pitted textures; sub mature nature; unconsolidated grains with scattered very fine sandstone 41 CANRIG I)HII.1.1uu T•.vH <n.i r:v I.ru. eni Enl Petroleum OP09-S1 with matrix support; composed of quartz with very minor lithics; 10% shell fragments in parts; fair overall porosity and permeability; oil base mud in use. Sand (21450-21550)=very light gray; clast size ranges from medium upper to very fine upper; sub angular to sub round; moderate developed sphericity; moderate to poor sorting; impacted to pitted textures; sub mature nature; unconsolidated with scattered very fine grained sandstone clusters matrix supported; sand is composed of quartz with trace dark lithics; 5-10% shell fragments; fair over all estimated porosity and permeability; continued oil base mud contamination in all sample fluorescent cuts. Sand (21550-21600) =very light gray; clast size ranges from medium upper to fine lower; sub angular to sub round; moderate developed sphericity; moderate sorting; impacted to pitted textures; sub mature nature; unconsolidated and arenaceous appearance; scattered very fine grain sandstone clusters; composed of predominantly quartz with trace dark lithics; trace to 10% shell fragments; fair to good estimated porosity and permeability; continued oil base mud contamination of all or any oil cuts. Sand (21600-21700) =very light gray; clast size ranges from medium upper to fine lower; sub angular to sub round; moderate developed sphericity; some prolated grains with overall equant grains; moderate sorting; impacted to pitted textures; sub mature nature; no visible cement; unconsolidated; appears arenaceous; no visible matrix material; scattered very fine grain sandstone clusters @ 21700'; composed of predominant quartz; fair to good estimated porosity and permeability; continued oil base mud contamination of sample oil cuts. FAULT B (Canning Hue) 21685.0' MD/-3816.9'TVDSS Sand (21700-21750) =very light gray; clast size range medium upper to very fine upper; sub angular to sub round; moderate developed sphericity; moderate sorting; some local poor sorting 21750'; impacted to pitted texture; sub mature nature; no visible cement; scattered very fine grain sandstone clusters; unconsolidated arenaceous sands; no visible matrix material; composed of predominantly quartz; fair to good estimated porosity and permeability; oil base mud masking oil cuts from samples. Siltstone(21750-21800) = light brownish gray; poor to some moderate induration; brittle to stiff; crumbly to crunchy; slight to moderate cohesiveness; non adhesive; sub nodular to sub platy habit; sub earthy fracture; dull earthy luster; silty texture; thin to thick beds; trace disminated pyrite; interbedded with carbon fines with no orientation. Siltstone (21800-21850)= light brownish gray; poor to some moderate induration; brittle to stiff; crumbly to crunchy; slight to moderate cohesiveness; non adhesive; sub nodular to sub platy habit; sub earthy fracture; dull earthy luster; silty texture; thin to thick beds; trace disminated pyrite; interbedded with carbon fines with no orientation. Siltstone(21850-21900) = medium light gray to light brownish gray; poorly indurated; brittle; crumbly to crunchy; slightly cohesive; non adhesive; sub nodular habit; sub earthy fracture; dull earthy luster; silty texture; thick to massive beds of homogeneous siltstone; interbedded carbon fines without any orientation. Siltstone (21900-21950) = light gray to medium gray to olive gray to brownish gray; crumbly to crunchy and brittle; slight cohesiveness; no adhesiveness; irregular fracture; earthy dull luster; silty to silty clayey texture; thin black to reddish brown to brown laminations. Siltstone(21950-22000) = medium gray to olive gray to brownish gray; poor induration; crumbly to slightly crunchy and brittle; no adhesiveness and slight cohesiveness; irregular earthy fracture; dull earthy luster; silty to silty clayey texture; thin unoriented black to brown laminations. Siltstone(22000-22050) = olive gray to medium gray to brownish gray cuttings; poorly indurated; crumbly to crunchy; not adhesive and poorly cohesive; irregular earthy fracture; dull earthy luster; silty to silty and clayey texture; unoriented black to dark brown to reddish brown laminations. 42 CANRIG Uxii.i.i ui:TI.I:H\l lt,l)l:l'I:ru. eni End Petroleum OP09-S1 Siltstone (22050-22100) = medium gray to olive gray to brownish gray; soft to easily friable; crumbly primarily; no adhesiveness and poor cohesiveness; irregular fracture; dull earthy luster; silty to silty clayey texture; thin black to brown laminations; samples contain safecarb mud additive. OA BOTTOM 22113.0' MD/-3770.6' TVDSS Siltstone(22100-22150) = medium gray to brownish gray to olive gray; soft to easily friable; crumbly to slightly crunchy and brittle; not adhesive and poorly cohesive; irregular fracture; dull earthy luster; silty to silty clayey texture; thin black to reddish brown to brown unoriented laminations; samples contaminated by safecarb mud additive; no oil shows. Siltstone(22150-22200) = medium gray to olive gray to brownish gray; easily friable to soft; primarily crumbly; not adhesive and poorly cohesive; irregular fracture to earthy fracture; dull earthy luster; silty to silty clayey texture; thin black to brown laminations; no oil indicators. OA SUBLAYER 4 22182.0' MD/-3760.1' TVDSS Sand (22200-22300) = very light gray to clear to translucent with reddish to greenish secondary hues; upper very fine to upper fine primarily with some medium sized grains; well sorted; subangular to angular with moderate sphericity; some sandstone cuttings intact, easily friable to friable and calcareously cemented; trace shell fragments; trace crystalline pyrite grains; faint oil odor; no visible oil staining; 100% even dull yellowish white sample fluorescence with blooming dull white cut fluorescence; amber visible cut; light pale straw visible residue; dull yellow residual fluorescence; oil shows skewed by obm; samples contaminated by safecarb mud additive. OA SUBLAYER 3 22278.0' MD/-3745.5' TVDSS OA SUBLAYER 2 22319.0' MD/-3738.9' TVDSS Sand (22300-22370) =clear to very light gray to translucent; upper very fine to upper fine with some medium grains; well sorted; subangular to angular to subrounded with moderate sphericity; trace pyrite and shell fragments; sandstone grades to silty sandstone and sandy siltstone, calcareously cemented, easily friable to friable; samples contain safecarb mud additive. TD 8 3/4" BOREHOLE 22370.0' MD/-3730.6' TVDSS 43 CANRIG eni Eni Petroleum OP09-S1 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 Gases noted. The well was circulated while making connections 3.5 Trip/Wiper Gas Summary Depth at Trip(ft) Trip To Depth (ft) Max Gas Pumps Off Comments MD TVDSS MD TVDSS (units) (hours) Note: No Trip/Wiper Gas noted. The well was drilled slightly over balanced. 44 C:ANRIG eni Eric Petroleum 0P09-S1 3.6 Sampling Program and Sample Dispatch Sample Program Dry samples: (2 sets) Every 50' from 2340' to TD (22370' MD). Iso-Jars: Every 500'from 13250' to TD. Iso-Tubes: Every 500' from 13250'to TD. Set Processed As Frequency* Interval* Dispatched to Reference Samples Fugro Data Solutions A Washed, dried, and 50' 2340' to 22370' 3311 South U.S. Highway 77 stored in plastic vials. Schulenburg, Texas 78956 Set Owner: ENI Reference Samples AOGCC B Washed, dried, and 50' 2340' to 22370' 333 W. 7th Avenue, Suite 100 stored in plastic vials. Anchorage, Alaska 99501 Set Owner: AOGCC Headspace Samples Unwashed and Weatherford Laboratories C stored in IsoJars® 500' 13250'to 22370' 8845 Fallbrook Drive Set Owner: ENI Houston, Texas 77064 Mud Gas Samples Weatherford Laboratories D Stored in IsoTubes® 500' 13250' to 22370' 8845 Fallbrook Drive Set Owner: ENI Houston, Texas 77064 Sample frequency and interval may be altered locally according to on-site geologist. 45 C:ANRIG eni En i Petroleum OP09-S1 4 PRESSURE AND FORMATION STRENGTH DATA 4.1 Pore Pressure Gradient Evaluation Formation Primary Secondary Top Of Interval Pore Pressure Trend Indicators Lithology Lithology(%) u (EMW. ppg) ° MD TVDSS Min Max Trend Permafrost n/a n/a n/a n/a 8.8 9.0 Even BG, MW Ugnu Sd 70% Sltst 30% 2142 -1964 9.2 9.4 Even BG, MW Schrader Bluff Sd/Sdst 80% Sltst/Clyst 20% 10643 -3627 9.4 9.4+ ncr BG OA Sand Sd 90% Slst 10% 12948 -3850 9.4 9.5 SI Incr BG No evidence of any accumulations of gas hydrates through the permafrost zones. Good drilling practices avoided any problems with the unconsolidated or brittle sand, gravel, ice and clays. The Ugnu displayed no drilling problems or well control issues with good drilling practices throughout the zone. Background gas rarely breached one hundred units. The Schrader Bluff and OA production interval displayed a slight increase in Pore Pressure with a increase in background gas through the Schrader Bluff to a rolling background gas of two hundred to five hundred units in the OA Sands. There were no break outs of large gas kicks or well control issues with this section having stable compaction and good sample quality. ENI used the E-CD subs for continuous circulation on connections avoiding any connection gases throughout the well. 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 Canrig, 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. 46 C:ANRIG Pal En! Petroleum OP09-S1 5 DRILLING DATA 5.1 Daily Activity Summary 6/12/2011: Pick up 5"drill pipe using the mouse hole and racking back in derrick. Fix hydraulic leak on iron ruff neck, replace fitting. Continue picking up 5"drill pipe.Same,66stds back.Mix spud mud.Continue picking up 5"drill pipe and rack back in derrick. Drift each joint. Pick up and rack back a total of 138 stands. Pick up BHA. Pick up and stand back 14 joints of heavy weight drill pipe and /joint. 6/13/2011: Pick up 5"drill pipe and 5"heavy weight drill pipe for drilling. Service the rig. Pick up and make up 16" bit and mud motor. Fill the conductor and test pumps to 2000 psi. Clean out 160'of conductor and rack back 1 stand of heavy weight drill pipe. Pick up and make up BHA#2. Drill from 160' to 252'. Encountered Gyro issues, pulled out of hole to replace Gyro. Run in hole and continue drilling from 252'to 545'40 RPM, 490 gpm, 720 psi and 5-25 WOB. Still having hard time obtaining Gyro surveys while drilling. 6/14/2011: Continue to drill and slide from 545'to 2205',WOB 10-30K,40 RPM,596 gpm and 1200 psi as of midnight. 6/15/2011: Continue drilling and sliding ahead from 2207' to 2340' TD @ 600 gpm, 1200 psi, 40 RPM. Circulate BU at TD and 1 BU for 2 stands while pulling out of hole, back ream out of the hole. L/D BHA#2, Rig up casing equipment and test landing Joint, RIH w/ 13 3/8" Casing W/Volant Tool to 1422' filling every 10 joints while RIH,skate sensor eye broke and needed repair,continue RIH w/13 3/8"Casing, F/1422'to 2285' and pick up hanger and landing joint. 6/16/2011: Continue to run in hole with 13 3/8"casing to 2325'. Rig down casing equipment and rig up cement head. Circulate and condition mud for cement job. Perform cement job, pumping 5 barrels of water and test lines to 4000 psi. Pump 105 barrels 10.1 ppg mud. Push, drop plug, pump 430 barrels 10.7 ppg lead and 73 barrels 12.3 ppg tail cement. Chased with 324 barrels of spud mud, pump plug.Cement in place @ 08:30. Rig down cement equipment. Rinse and flush lines. Rig down stack and nipple up BOP. Test BOP as of midnight. 6/17/2011: Continue testing BOP. Replace IBOP and test. Rig down testing equipment. Lay down 5" heavy wall drill pipe and pick up 12.25"bit and BHA#3. Run in hole to 2200'. Service rig and slip and cut drilling line. Weld cracked finger in Derrick. Circulate bottoms up and test 13 3/8"casing to 2500 psi for 30 min. Drill out F.C. Plugs from 2232' to 2238' as of midnight. 6/18/2011: Continue drilling out Shoe Track. Drill 20' new of hole from 2340' to 2360'. Circulate bottoms up and displace well to 9.2 ppg LSND. Perform FIT with 430 psi bled down to 256 psi, 11.4 ppg EMW. Drill from 2360' to 4406' as of midnight. 6/19/2011: Continue drilling ahead from 4406'to 7850'as of midnight. 6/20/2011: Rotary drilling from 7850'-9120'and found a hard spot.Vary weight on bit and RPM attempting to increase ROP and minimize stick/slip. Backream 120' and go back to bottom with same results. Circulate bottoms up 3.5 times. Monitor well. Backream 5 stands and attempt to pull out of hole on elevators.Wash and ream to 8605'. Circulate bottoms up 1 time. Back reaming out of hole as of midnight. 6/21/2011: Back reaming from 7085'-3128' laying down 14 joints. Circulate bottoms up 2.5 times while cleaning chunks of clay out of possum bellies and flow line. Back ream to shoe. Circulate bottoms up 3.5 times. Monitor well-STATIC. Pump dry job and pull out of hole on elevators. Lay down a total of 97 joints of drill pipe. Lay down and pick up new BHA as of midnight. 47 C:ANIIG eni Erin Petro let= OP09-S1 6/22/2011: Pick up new BHA. Service top drive. Pick up 87 joints of new drill pipe and single in from 286'- 3062'. Run in hole from 3062'-7176'working tight spots @ 2700,4465, 5078, and 5500'. Run in hole to 8995' and ream and wash to bottom @ 9120'. Rotary drilling on hard spot from 9120'-9146'. 6/23/2011: Rotary drill from 9146'-9152'@>1 ft/hr ROP.Tried different RPM's,varying weight, no luck. Back ream to 8995'and wash and ream back to bottom twice. No results. Back reaming from 9158'to surface for new bit. 6/24/2011:Circulate bottoms up 1 time and monitor well-static. Pull out of hole from 6505'-3923'on elevators. Fix hose on iron roughneck. Lay down BHA. Clean and clear rig floor. Pick up new BHA. Service rig top drive, draw works, crown, change lube filter and clean Y strainer. 6/25/2011: Trip in hole from 6975'-8986'. Fill pipe and ream/wash to 9158'. Rotary drill to 9561'. Service top drive. Drill to 10230'. 6/26/2011: Rotary drilling from 10254'-11320'. Service rig and top drive. Cool motors from overheating issue. Continue drilling to 11856'with no other issues. No losses to formation. 6/27/2011: Rotary Drilled from 11856'-TD @13220' with no issues. MW 9.4 ppg, ECD 11.06 @900 GPM. Circulate and condition 1 bottoms up (16,000 strokes) per stand. Stand back stand on every bottoms up. Circulate and condition 1/2 stand per bottoms up standing back from 12908'-12621'. 6/28/2011: Backream from 12,621'-12,142'setting back one stand every 8000 strokes. Monitor and confirm well is static. Backream 10 minutes per stand to 9,465'working tight spot @4650-4610. 900 GPM, 9.5 ppg MW, 9.9 ECD. 6/29/2011: Backream from 4584-2382'. Circulate and condition standing one stand back every bottoms up from 2382'-1999'. Pull out of hole on elevators. Lay down BHA.Clean rig.Change rams.Test BOP's.Set wear ring for running 9.625" casing. Rig up tools to run casing. Run 9.625" casing to 853' as of midnight. 6/30/2011: Run 9-5/8 L-80 casing. Started rotating @ 5093' RPM 45/TQ 2.3. At 6712' bring RPM's up to 60 TQ-3.5. Run casing to 12008'. Rotating @ 75 RPM and 7.9 TQ. 7/01/2011: Run casing to 13195'rotating @75 RPM w/13.4 TQ. Rig down Tesco tools. Fill casing with 9.4 ppg LSND @ 2 bbls/minute. Vent casing load plugs and confirm well is static. Circulate and condition hole @ 6 bbls/min. Increase rate to 8 bbls/min and incurred losses. Reduced rate back to 6 bbls/min for remainder of circulation. Rig up SLB cementers. Test lines to 3700 psi. Pump 65 bbls mud push. Drop plug and pump 356 bbls cement. Drop bottom plug and pump 10bbls water. Chase with rig pump. 7/02/2011: Displace cement with rig pumps @ 8 bbls/min.6-1300 psi. Bump plug @ 9899 strokes. Pressure up to 1500 psi and check floats-OK. Bullhead 20 bbls down annular. Lay down casing tools. Nipple down BOP's. Set emergency slips. Cut casing joint and install pack off per Vetco Gray. Nipple up BOP's, flow line, catch can, etc. Freeze protect OA w/130 bbls diesel. Change rams and function test.Tripping/picking up 100 stands of drill pipe. 7/03/2011: Trip out of hole with 73 stands of drill pipe installing WEI subs. Pick up test tools, install test plug. Test stack and choke manifold to 3500 psi. 4.7-7" variable rams and IBOP tests failed. Change rams and IBOP insert. Retest. Service Top Drive. Change swivel packing. Electrical work in drilling module. 7/4/2011:Trouble shoot PFD and top drive. Pick up and run in hole with 5"drill pipe and lay down bad joints of hard band. Pick up 5"drill pipe and stand back in derrick with WEI Subs. Pick up 8.75" bit and BHA#7, pick up 4.5" drill pipe to 611'. Work on skate and shallow test BHA. Continue to pick up 4.5"drill pipe and run in hole to 5712' as of midnight. 48 CANRIG VOI eni Evil Petroleum OP09-S1 7/5/2011: Continue to pick up 4.5"drill pipe and run in hole to 9615'. Start to run in hole with 5"drill pipe from derrick,wash down from 12,964'to 13,099'and tag cement. Circulate surface to surface till 9.4 ppg was seen in and out. Test 9 5/8"casing and shoe to 3000 psi for 30 min. Displace LSND to 9.4 ppg FazePro. Cut and slip drilling line. Test WEI Equipment to 5000 psi for 10 min. Drill plug and shoe track from 13,099'to 13,220' and 20' new hole to 13,240'. Circulate hole clean for FIT as of midnight. 7/6/2011: Perform FIT, 780 psi Max. 13.0 ppg EMW. Drill ahead from 13,240'to 15,540' 120 RPM, 553 gpm, 3740 psi, 8K WOB, 15K TRQ and 11.4 ppg. 7/7/2011: Continue drilling f/ 15,540'to 18,000'. 7/8/2011: Continue drilling f/ 18,000' to 19848'. 7/9/2011: Continue drilling f/ 19, 848' to 20,440'. Trouble shoot directional survey tools and continue to drill f/20,440'to 20, 475'. Trouble down loading Exceed tool and continue to drill f/20, 475' to 21,084'. 7/10/2011: Continue to drill f/21,084'to 22,370'. Encounter several hard spots while drilling. TD the well at 22,370' and circulate the hole clean. 49 CANRIG a eni Eni Petroleum OP09-S1 5.2 Survey Data 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) 166.34 0.19 55.16 166.34 0.15 0.16 0.22 0.11 201.91 0.08 16.03 201.91 0.21 0.21 0.28 0.38 262.65 0.07 36.21 262.65 0.28 0.28 0.31 0.04 322.70 0.04 57.52 322.7 0.32 0.32 0.35 0.06 382.81 0.31 21.75 382.81 0.48 0.48 0.43 0.46 473.14 0.85 3.07 473.14 1.37 1.38 0.55 0.63 535.14 1.57 11.3 535.12 2.66 2.67 0.74 1.18 628.15 4.04 32.75 628.01 6.63 6.68 2.77 2.85 725.17 6.8 28.36 724.6 14.48 14.61 7.35 2.88 820.74 9.92 20.12 819.14 27.09 27.32 12.87 3.48 916.22 14.09 24.33 912.51 45.27 45.64 20.49 4.46 1012.30 16.75 20.14 1005.13 68.76 69.29 30.17 3.00 1107.61 20.37 14.56 1095.47 97.56 98.25 38.98 4.23 1202.20 22.42 10.74 1183.55 131.08 131.91 46.48 2.62 1264.76 23.4 10.62 1241.17 154.93 155.84 50.99 1.57 1360.41 24.68 10.4 1328.52 193.11 194.16 58.10 1.34 1457.59 25.72 10.06 1416.45 233.70 234.87 65.45 1.08 1552.92 25.24 8.81 1502.51 274.03 275.33 725.17 0.76 1649.17 24.62 7.89 1589.79 314.06 315.47 78.07 0.76 1745.37 25.80 8.18 1676.83 354.52 356.04 83.80 1.23 1841.25 26.95 8.29 1762.72 396.56 398.19 89.90 1.20 1936.26 30.70 7.23 1845.95 441.83 443.57 96.06 3.98 2032.39 32.32 6.85 1927.90 491.58 493.44 102.21 1.70 2127.04 36.62 7.19 2005.91 544.61 546.59 108.76 4.55 2223.33 38.94 5.90 2082.02 603.08 605.19 115.47 2.55 2256.53 40.18 4.98 2107.61 624.09 626.24 117.47 4.13 2418.35 45.09 3.31 2226.63 733.22 735.52 125.32 3.11 2513.83 50.08 2.18 2291.01 803.54 805.91 128.66 5.3 2609.63 54.09 1.56 2349.88 879.00 881.42 131.12 4.2 2706.46 57.93 2.02 2404.01 959.16 961.64 133.63 4.01 2802.28 61.19 2.94 2452.55 1041.61 1044.16 137.22 3.5 2896.67 63.45 3.58 2496.40 1124.96 1127.61 141.98 2.47 2991.73 66.11 4.07 2536.90 1210.65 1213.41 147.72 2.84 3086.63 68.56 3.95 2573.47 1297.88 1300.76 153.84 2.58 3182.73 71.99 4.10 2605.90 1387.98 1390.98 160.19 3.57 3279.58 75.39 4.42 2633.09 1480.52 1483.66 167.10 3.52 3374.07 79.72 5.04 2653.45 1572.31 1575.60 174.71 4.63 3470.62 82.62 5.03 2668.27 1667.18 1670.62 183.08 3.00 3566.99 82.45 4.78 2680.79 1762.22 1765.83 191.25 0.31 50 CANFIG Igifs eni Ent Petroleum OP09-S1 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) 3661.91 82.40 4.43 2693.30 1855.86 1859.62 198.80 0.37 3757.93 82.28 4.02 3706.10 1950.63 1954 205.81 0.44 3854.52 82.25 4.27 2719.10 2045.96 2049.98 212.73 0.26 3949.90 82.31 3.75 2731.91 2140.11 2144.26 219.34 0.54 4045.60 82.28 3.99 2744.74 2234.60 2238.88 225.74 0.25 4140.72 82.28 3.73 2757.52 2328.52 2332.93 232.09 0.27 4236.48 82.16 3.76 2770.49 2423.08 2427.60 238.28 0.03 4332.37 82.26 3.89 2783.48 2517.74 2522.40 244.62 0.17 4430.11 82.23 4.02 2796.67 2614.23 2619.01 251.30 0.14 4525.98 82.16 3.78 2809.69 2708.86 2713.77 257.76 0.26 4619.72 82.25 3.62 2822.40 2801.42 2806.46 263.76 0.19 4716.11 82.34 3.17 2835.33 2896.66 2901.81 269.41 0.47 4811.13 82.35 2.94 2847.99 2990.60 2995.85 274.43 0.24 4905.89 82.96 2.93 2860.10 3084.36 3089.70 279.24 0.64 5002.57 83.18 3.27 2871.76 3180.09 3185.54 284.43 0.42 5097.91 83.14 4.23 2883.12 3274.42 3280.00 290.62 1.00 5193.88 83.26 4.85 2894.48 3369.27 3374.99 298.17 0.65 5289.26 83.26 4.56 2905.68 3463.52 3469.39 305.94 0.30 5385.37 83.23 4.72 2916.98 3558.51 3564.52 313.66 0.17 5480.74 83.27 4.46 2928.19 2652.74 3658.91 321.48 0.06 5575.98 83.17 4.75 2939.44 3746.84 3753.16 329.32 0.11 5671.77 83.33 4.43 2950.69 3841.51 3847.98 336.94 0.37 5864.24 82.46 2.81 2974.53 4031.84 4038.55 349.40 1.17 5959.02 81.74 0.98 2987.56 4125.59 4132.37 352.51 2.06 6052.73 81.73 357.80 3001.03 4218.31 4225.09 351.52 3.36 6149.73 81.77 356.06 3014.95 4314.24 4320.95 346.38 1.78 6246.02 81.67 356.06 3028.82 4409.40 4416.01 339.83 0.10 6342.76 81.76 355.89 3042.76 4505.00 4511.50 333.12 0.20 6436.85 81.89 356.24 3056.14 4598.01 4604.42 326.72 0.39 6531.52 81.64 356.94 3069.90 4691.62 4697.94 321.15 0.78 6627.41 81.71 358.24 3083.58 4786.47 4792.74 317.16 1.34 6723.34 81.68 358.89 3097.44 4881.39 4887.63 314.78 0.67 6817.96 81.73 359.02 3111.09 4975.02 4981.25 313.08 0.15 6911.64 81.77 358.98 3124.53 5067.73 5073.94 311.46 0.06 7008.05 81.48 358.05 3138.57 5163.11 5169.29 308.99 1.00 7097.50 81.77 358.06 3151.60 5251.59 5257.74 305.98 0.32 7189.68 81.84 358.16 3164.74 5342.82 5348.92 302.97 0.13 7297.48 82.23 359.61 3179.68 5449.58 5455.66 300.90 1.38 7392.81 82.38 1.45 3192.45 5544.01 5550.12 301.77 1.92 7487.88 82.19 2.59 3205.21 5638.09 5644.27 305.09 1.20 51 C NRIG eni Eni Petroleum OP09-S1 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) 7583.97 82.08 1.90 3218.36 5733.12 5739.39 308.82 0.72 7680.51 82.14 2.31 3231.61 5828.61 5834.95 312.33 0.43 7774.84 82.29 0.86 3244.39 5921.97 5928.37 314.92 1.53 7871.73 82.16 1.87 3257.50 6017.89 6024.34 317.20 1.04 7967.94 82.17 2.73 3270.61 6113.04 6119.58 321.03 0.89 8063.47 82.19 2.47 3283.61 6207.50 6214.12 325.32 0.27 8159.30 82.25 2.40 3296.58 6302.27 6308.98 329.36 0.10 8254.78 82.32 2.39 3309.40 6396.72 6403.51 333.31 0.07 8351.17 82.22 2.59 3322.37 6492.06 6498.94 337.46 0.23 8447.02 82.11 2.23 3335.37 6586.85 6593.81 341.45 0.39 8542.51 82.14 1.74 3348.52 6681.31 6688.34 344.73 0.51 8638.55 82.17 0.87 3361.63 6776.37 6783.46 346.90 0.90 8733.97 82.23 359.73 3374.58 6870.88 6877.99 347.39 1.19 8829.77 82.12 358.47 3387.62 6965.79 6972.89 345.90 1.31 8921.65 82.53 358.51 3399.89 7056.84 7063.91 343.50 0.45 9020.39 82.25 358.19 3412.97 7154.70 7161.74 340.68 0.43 9109.82 83.11 357.53 3424.36 7243.38 7250.38 337.37 1.21 9140.07 84.77 357.52 3427.55 7273.45 7280.43 336.07 5.49 9173.95 83.80 357.05 3430.93 7307.16 7314.11 334.47 3.17 9236.04 83.17 357.74 3437.97 7368.81 7375.73 331.47 1.50 9332.21 82.36 359.30 3450.09 7464.22 7471.10 329.20 1.82 9427.71 81.30 359.44 3463.66 7558.74 7565.62 328.17 1.12 9525.61 82.22 0.69 3477.69 7655.61 7662.50 328.28 1.57 9618.60 82.45 0.56 3490.09 7747.73 7754.66 329.29 0.28 9714.01 81.96 0.64 3503.03 7842.22 7849.18 330.27 0.52 9809.58 82.03 0.76 3516.20 7936.77 7943.80 333.54 0.15 9905.46 81.33 1.09 3530.07 8031.59 8038.66 335.07 0.81 10001.03 81.77 0.27 3544.12 8126.08 8133.18 336.19 0.97 10096.27 81.63 0.12 3557.86 8220.30 8227.43 336.51 0.21 10191.81 84.67 0.43 3569.26 8315.12 8322.27 336.97 3.2 10289.14 84.36 0.37 3578.56 8411.98 8419.15 337.65 0.32 10340.69 83.12 358.70 3584.18 8463.22 8470.39 337.23 4.02 10481.36 82.49 357.76 3602.99 8602.60 8609.71 332.49 0.64 10576.61 81.51 355.42 3616.25 8696.83 8703.86 326.88 2.64 10672.88 81.3.6 353.65 3630.59 8791.74 8798.62 326.88 2.64 10768.95 81.36 351.39 3645.02 8886.10 8892.79 305.45 2.33 10863.81 81.31 349.01 3659.32 8978.77 8985.19 289.49 2.48 10958.35 81.94 347.19 3673.09 9070.61 9076.71 270.20 2.02 11055.34 82.89 343.32 3699.03 9255.29 9260.56 221.37 1.94 52 BRIG 1)xii.i.i ne:TI;(:H'crt.ixn'I.l l). V* eni Enii Petroleum OP09-S1 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) 11245.43 83.09 341.72 3710.64 9345.75 9350.54 193.04 1.68 11339.05 83.23 340.32 3721.91 9434.21 9438.49 162.93 1.52 11433.54 83.38 336.03 3732.93 9521.90 9525.59 128.05 4.51 11530.10 83.38 336.47 3744.06 9610.36 9613.38 89.42 0.45 11625.51 81.68 334.50 3756.47 9697.09 9699.45 50.17 2.71 11721.32 82.92 333.50 3769.30 9783.14 9784.78 8.55 1.66 11817.56 83.64 331.93 3780.57 9868.83 9869.72 -35.26 1.78 11913.70 83.52 328.35 3791.32 9952.49 9952.56 -82.82 3.7 12009.64 83.26 326.71 3802.36 10033.77 10032.96 -133.98 1.72 12199.73 84.13 320.91 3824.47 10187.78 10185.04 -245.72 3.05 12296.02 84.56 317.90 3833.96 10261.61 10257.79 -308.07 3.14 12391.16 84.15 314.90 3843.32 10331.30 10325.35 -373.35 3.16 12487.61 83.75 310.82 3854.35 10398.46 10392.34 -441.37 4.13 12583.13 84.15 309.45 3864.42 10460.95 10453.57 -513.99 1.49 12679.11 84.19 308.96 3874.17 10522.58 10513.92 -587.98 0.51 12774.86 83.34 309.59 3884.57 10584.11 10574.18 -661.66 1.10 12870.44 83.50 309.48 3895.52 10645.82 10634.62 -734.89 0.20 12966.32 84.36 310.41 3905.66 10708.30 10695.83 -807.98 1.32 13061.92 83.19 309.86 3916.02 10770.82 10757.09 -880.64 1.35 13156.61 84.85 309.64 3925.89 10882.29 10817.31 -953.04 1.77 13182.76 85.84 309.66 3928.01 10849.27 10833.94 -973.11 3.79 13293.88 90.81 312.78 3931.26 10923.88 10907.10 -1056.61 5.28 13391.34 90.34 311.93 3930.28 10990.79 10972.76 -1128.63 1.00 13490.48 90.46 312.59 3929.59 11058.73 11039.43 -1202.00 0.67 13589.71 89.51 312.27 3929.62 11126.94 11106.38 -1275.24 1.01 13686.12 89.62 311.62 3930.35 11192.62 11170.82 -1346.95 0.69 13786.42 90.48 311.73 3930.26 11260.61 11237.51 -1421.87 0.87 13883.34 89.85 312.24 3929.67 11328.43 11304.11 -1492.30 0.68 13983.00 89.87 311.61 3929.91 11396.31 11370.70 -1566.45 0.63 14080.97 90.11 310.23 3929.93 11461.76 11434.87 -1640.48 1.43 14176.02 90.65 307.09 3929.30 11522.41 11494.24 -1714.69 3.35 14270.71 92.31 305.97 3926.85 11580.07 11550.58 -1790.75 2.11 14374.41 94.26 304.49 3920.91 11641.26 11610.30 -1875.31 2.36 14472.12 91.99 302.73 3915.58 11696.67 11664.30 -1956.55 2.94 14572.48 90.77 297.47 3913.16 11748.47 11714.59 -2043.32 5.38 14671.05 90.07 296.59 3912.44 11794.79 11759.39 -2131.12 1.14 14769.30 90.16 296.94 3912.25 11840.56 11803.63 -2218.85 0.37 14867.57 90.28 299.44 3911.87 11888.48 11850.05 -2305.45 2.55 14965.92 90.51 300.61 3911.19 11939.17 11899.26 -2390.60 1.21 15063.61 90.11 300.94 3910.66 11990.61 11949.25 -2474.53 0.53 53 CANRIG eni Eni Petroleum OP09-S1 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(-) (°1100ft) 15162.07 90.48 301.67 3910.15 12043.23 12000.40 -2558.66 0.83 15260.78 90.05 301.23 3909.70 12096.19 12051.91 -2642.86 0.62 15358.82 88.82 300.95 3910.66 12148.27 12102.53 -2726.82 1.29 15457.49 87.94 300.42 3913.45 12200.08 12152.86 -2811.64 1.04 15555.08 87.68 299.53 3917.18 12250.27 12201.58 -2869.11 0.95 15653.15 89.46 299.88 3919.63 12300.33 12250.16 -2981.26 1.85 15752.33 89.79 307.64 3920.28 12356.83 12305.24 -3063.65 7.83 15850.18 88.10 307.97 3922.08 12418.14 12365.20 -3140.95 1.76 15949.33 88.77 305.68 3924.79 12478.91 12424.60 -3220.28 2.41 16047.66 88.28 302.99 3927.32 12535.76 12480.04 -3301.44 2.78 16146.75 89.25 300.51 3929.46 12589.35 12532.17 -3385.68 2.69 16245.23 89.00 296.57 3930.96 12637.89 12579.20 -3472.16 4.01 16343.06 89.88 296.21 3931.92 12682.89 12622.69 -3559.80 0.97 16440.98 90.71 298.50 3931.41 12729.39 12667.68 -3646.76 2.48 16539.52 89.70 299.32 3931.20 12787.13 12724.02 -3727.53 1.14 16638.35 90.42 300.37 3931.10 12837.95 12773.35 -3813.17 1.13 16737.59 89.84 300.49 3930.87 12889.70 12823.61 -3898.74 0.6 16835.87 91.35 299.87 3929.85 12940.58 12873.01 -3983.69 1.66 16933.81 94.02 302.14 3925.26 12992.42 12923.40 -4067.53 3.58 17032.04 93.65 301.37 3918.69 13045.45 12974.98 -4150.87 0.87 17130.24 91.76 302.85 3914.06 13099.03 13027.12 -4233.95 2.44 17229.17 89.53 303.15 3912.94 13154.34 13080.99 -4316.91 2.27 17326.95 89.14 301.38 3914.08 13207.97 13133.18 -4399.58 1.85 17425.64 89.25 300.60 3915.47 13260.24 13183.99 -4484.17 0.8 17524.27 89.42 301.09 3916.61 13312.28 13234.56 -4568.85 0.53 17622.81 90.55 301.63 3916.64 13365.02 13285.84 -4652.99 1.27 17720.91 90.49 301.40 3915.75 13417.75 13337.12 -4736.62 0.24 17818.77 90.47 300.10 3914.93 13469.24 13387.15 -4820.71 1.33 17917.29 90.96 298.97 3913.70 13519.29 13435.71 -4906.42 1.25 18016.30 90.28 298.61 3912.63 13568.48 13483.39 -4993.19 0.78 18115.22 89.08 296.22 3913.18 13615.55 13528.93 -5080.99 2.7 18213.89 88.08 296.20 3915.62 13660.65 13572.50 -5080.99 2.70 18313.44 88.16 296.48 3918.89 13706.34 13616.64 -5258.65 0.29 18412.35 89.42 297.59 3920.98 13752.82 13661.59 -5346.73 1.70 18508.25 89.73 300.22 3921.69 13800.63 13707.94 -5430.68 2.76 18606.06 89.68 302.22 3922.19 13853.13 13758.99 -5514.10 2.55 18704.45 89.70 305.35 3922.73 13909.60 13814.04 -5595.63 2.68 18803.16 90.82 307.52 3922.28 13969.59 13872.66 -5675.04 2.47 54 C:ANRIG Vlis eni Eni Petroleum OP09-S1 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) 18900.55 91.39 308.22 3920.40 14030.70 13932.44 -5751.90 0.93 18999.07 92.19 307.75 3917.32 14092.65 13993.04 -2829.51 0.94 19094.29 91.16 303.26 3914.54 14149.25 14048.30 -2906.98 4.84 19193.44 93.01 302.05 3910.93 14204.16 14101.76 -5990.39 2.23 19292.52 95.41 299.86 3903.66 14256.46 14152.59 -6075.12 3.28 19391.40 94.64 297.60 3894.99 14305.30 14199.93 -6161.49 2.41 19490.11 92.36 294.92 3888.97 14350.42 14243.51 -6249.83 3.56 19587.21 92.30 296.30 3885.02 14393.80 14285.37 -6337.35 1.32 19686.68 93.30 298.28 3880.16 14440.80 14330.84 -6425.68 2.32 19785.13 92.81 300.91 3879.22 14507.11 14385.84 -6500.94 2.47 19882.73 91.75 303.00 3875.51 14560.16 14447.46 -6583.68 2.31 19981.21 89.79 303.57 3874.19 14615.62 14501.50 -6666.00 2.07 20079.81 87.71 304.07 3876.34 14671.91 14556.36 -6747.89 2.17 20177.24 90.76 303.60 3877.64 14727.86 14610.60 -6828.80 3.17 20275.35 87.52 304.31 3879.11 14783.75 14665.38 -6910.16 3.38 20373.19 88.93 306.52 3882.14 14841.79 14722.05 -6989.85 2.68 20472.12 89.62 305.71 3883.39 14901.48 14780.35 -7069.78 1.08 20569.89 89.51 302.75 3884.14 14957.88 14835.34 -7150.59 3.03 20668.62 90.32 301.33 3884.26 15011.70 14887.72 -7234.28 1.86 20767.83 90.80 300.68 3883.49 15064.28 14938.82 -7319.31 0.71 20867.40 91.18 301.48 3881.94 15117.16 14990.21 -7404.57 0.99 20964.75 91.81 301.40 3879.57 15169.36 15040.98 -7487.61 0.45 21063.14 91.70 300.85 3876.73 15221.66 15091.81 -7571.80 0.57 21259.51 90.56 299.19 3872.31 15323.12 15190.32 -7741.60 0.69 21357.28 90.68 297.65 3871.25 15371.14 15236.85 -7827.58 1.38 21456.16 89.68 298.64 3870.94 15419.29 15283.49 -7914.77 1.42 21554.51 89.73 299.52 3871.45 15468.59 15331.29 -8000.72 0.90 21653.37 90.80 299.60 3870.99 15518.85 15380.06 -8086.71 1.09 21750.26 93.37 298.06 3867.46 15567.01 15426.74 -8171.52 3.09 21849.92 96.05 297.92 3859.28 15615.14 15473.35 -8259.22 2.69 21948.50 97.33 297.26 3847.80 15661.99 15518.70 -8345.99 1.46 22048.58 98.77 298.82 3833.78 15710.09 15865.28 -8433.45 2.11 22144.82 98.72 298.40 3819.15 15757.09 15610.83 -8516.96 0.43 22244.50 98.68 298.96 3804.07 15805.88 15658.11 -8603.40 0.56 22305.86 99.37 299.33 3794.45 15836.31 15687.63 -8656.33 1.27 22370.00 99.37 298.33 3784.00 15867.79 15718.14 -8711.77 1.54 55 CANRIG I)aii.i.i u T:vHi n.icr 1.-rig. $ /� / � / � \ �� co k / \ k > / 7o7 / 70 ± $ — f ± q — g - 4 q q CO q k co ix a \ / f 0 co o \ 2 I / CO co \ k a 2 d $ \ C? \ o.= = b b Co / pCr) \ \ CO q E _ - $ b k ' cNi O q 7 \ CO lr « £ 0 © 2 �\ � � A2 / 2 \ $ k � • R �} a 2 ( - +� j O) ( •$ci�� C 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C f - NNU) (0 ) C) N C'7 C'7MC7 > > O � MC' U) N- 0) 0N N NNN > O Ua ti NN N NNN 10 C +,, O 5 3 OS C) 0) as II II II II 'as m 00 000 5 / > a ., 000000 0 NNNNNCV NNN 2 > a >- N N N N N- N N N N N- N N N ENI Petroleum DAILY WELLSITE REPORT OP09-S1 CRIG REPORT FOR DATE,06/12/2011 DEPTH 160.0 PRESENT OPERATION Picking up BHA TIME 24:00:00 YESTERDAY 160.0 24 HOUR FOOTAGE 0 CASING INFORMATION 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 FLUIDS REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) @ @ CONNECTION GAS HIGH NA 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 Pick up drill pipe p/u 5"drill pipe using the mousehole and racking back in drk.slm every row,service rig fix hyd leak on iron ruffneck,replace fitting,pickup drill pipe coot p/u 5"drill pipe. SUMMARY same,66stds back.mix spud mud,pick up drill pipe cont.p/u 5"dp and rack bk in drk.slm.drift each jt.p/u and rack bk total of 138 stds,pick up bha p/u and std back 14jts hwdp and 1 jt. CANRIG PERSONNEL ON BOARD 2 DAILY COST$3,795.00 REPORT BY Steve Pike ENI Petroleum DAILY WELLSITE REPORT OP09-S1 c44JiRIG REPORT FOR Cormier,Goerlich,Buchanan DATE Jun 15,2011 DEPTH 2340' PRESENT OPERATION Rig up to cement casing. TIME 24:00:00 YESTERDAY 2205' 24 HOUR FOOTAGE 135' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #1 16" Hughes MX-1 5191534 3020,1016 160' 2340 2180' 20 1-1-WT-A-E-I-NO-TD TD for surface casing DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 272.3 @ 2249 58.6 @ 2307 155.3 127.04383 FT/HR SURFACE TORQUE 21870 @ 2208 3012 @ 2269 2475.3 3978.22876 AMPS WEIGHT ON BIT 34 @ 2240 1 @ 2314 15.3 10.50576 KLBS ROTARY RPM 42 @ 2205 1 @ 2209 15.9 36.84024 RPM PUMP PRESSURE 1701 @ 2309 1094 @ 2206 1344.4 1541.39478 PSI DRILLING FLUIDS REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 100 @ 2232 13 @ 2254 62.4 TRIP GAS NA CUTTING GAS 0 @ 2339 0 @ 2339 0.0 WIPER GAS 386 CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 19001 @ 2232 2465 @ 2254 11757.7 CONNECTION GAS HIGH NA ETHANE(C-2) 0 @ 2339 0 @ 2339 0.0 AVG 62 PROPANE(C-3) 0 @ 2339 0 0 2339 0.0 CURRENT 0 BUTANE(C-4) 0 0 2339 0 0 2339 0.0 CURRENT BACKGROUND/AVG 12/62 PENTANE(C-5) 0 0 2339 0 0 2339 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Continue drilling and sliding ahead from 2207'to 2340'TD @ 600 gpm,1200 psi,40 RPM.Circulate BU at TD and 1 BU for 2 stands while pulling out of hole,back ream out of the hole.L/D SUMMARY BHA#2,Rig up casing equipment and test landing Joint,RIH w/13 3/8"Casing W/Volant Tool to 1422'filling every 10 joints while RIH,skate sensor eye broke and needed repair,continue RIH w/13 3/8"Casing,F/1422'to 2285'and pick up hanger and landing joint. CANRIG PERSONNEL ON BOARD 2 DAILY COST$3,795 REPORT BY Steve Pike ENI Petroleum DAILY WELLSITE REPORT CANRIG OP09-S1 REPORT FOR Cormier,Goerlich,Buchanan DATE Jun 16,2011 DEPTH 2340' PRESENT OPERATION Test BOPS TIME 24:00:00 YESTERDAY 2340' 24 HOUR FOOTAGE 0 CASING INFORMATION 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 FLUIDS REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 0 @ 0 0.0 TRIP GAS 183 CUTTING GAS 0 @ 0 0 @ 0 0.0 WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 0 @ 0 0 @ 0 0.0 CONNECTION GAS HIGH NA ETHANE(C-2) 0 @ 0 0 @ 0 0.0 AVG 0 PROPANE(C-3) 0 @ 0 0 @ 0 0.0 CURRENT 0 BUTANE(C-4) 0 @ 0 0 @ 0 0.0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 0 0 @ 0 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Continue RIH 13 3/8"casing to 2323',R/D casing equipment and R/U cement head,circulate and condition mud for cement job.Perform cement job,pumping 5 bbls water and test lines to SUMMARY 4000 psi.Pump 105 bbls 10.1 ppg mud push,drop plug,pump 430 bbls 10.7 ppg lead and 73 bbls 12.3 ppg tail cement.Chased with 324 bbls spud mud,pump plug,CIP @ 08:30.R/D cement equipment,rinse and flush lines.R/D stack and N/U. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4,795 REPORT BY Steve Pike ENI Petroleum DAILY WELLSITE REPORT OP09-S1 ►NRIG REPORT FOR Cormier,Smith,Buchanan DATE Jun 17,2011 DEPTH 2340' PRESENT OPERATION Ream out cement TIME 24:00:00 YESTERDAY 2340' 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #2 12.25" Hycalog MSX619-A6C E142873 3x14,3x15 2340' 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 FLUIDS REPORT DEPTH 2323/2214 MW 9.2 VIS 48 PV 8 YP 17 FL 6.2 Gels 9/10/11 CL- B00 FC 1/- SOL 3 SD - OIL 3/94 MBT 16 pH 9.4 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 0 @ 0 0.0 TRIP GAS NA CUTTING GAS 0 @ 0 0 @ 0 0.0 WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 0 @ 0 0 @ 0 0.0 CONNECTION GAS HIGH NA ETHANE(C-2) 0 @ 0 0 @ 0 0.0 AVG 0 PROPANE(C-3) 0 @ 0 0 @ 0 0.0 CURRENT 0 BUTANE(C-4) 0 @ 0 0 @ 0 0.0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 0 0 @ 0 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Continue testing BOP's.Replace IBOP and test.R/D testing equipment and L/D 5"HWDP.P/U 12.25"Bit and BHA#3.RIH to 2200'.Service rig and slip and cut drilling line.Weld cracked SUMMARY finger in Derrick.Circulate BU and test 13 3/0"Casing to 2500 psi for 30 minutes.Drill out F.C.Plugs F/2232'to 2238'as of midnight. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4,795 REPORT BY Steve Pike ENI Petroleum Nikadchuq DAILY WELLSITE REPORT CANRIG OP09-S1 REPORT FOR Cormier,Smith,Buchanan DATE Jun 18,2011 DEPTH 4406' PRESENT OPERATION Drilling ahead TIME 24:00:00 YESTERDAY 2340' 24 HOUR FOOTAGE 2160' CASING INFORMATION 20"@ 160'13 3/8"@ 2325' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4525.98 82.14 449 2810.18 SURVEY DATA 4430.11 82.2 4.7 2797.12 4332.37 82.24 4.33 2783.88 4236.48 82.15 4.19 2770.86 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 121/4" Hycalog MSX6-A6C E142873 3x14,3,15 2340' - 2160' 15 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 934.3 @ 3935' 16.8 @ 3970' 191.7 181.35 FT/HR SURFACE TORQUE 14429 @ 3879' 611 @ 2420' 4422.8 4822.67 AMPS WEIGHT ON BIT 20 @ 3981' 0 @ 2341' 5.5 6.31 KLBS ROTARY RPM 127 @ 3854' 46 @ 2342' 113.5 120.43 RPM PUMP PRESSURE 1742 @ 4494' 289 @ 2343' 1414.4 1723.19 PSI DRILLING FLUIDS REPORT DEPTH 4406'/2793' MW 9.2 VIS 50 PV 12 YP 26 FL 4.8 Gels 12/17/21 CL- 750 FC 1/- SOL 4.0 SD - OIL 3/93 MBT 7.5 pH 9.8 Ca+ 80 CCI - MWD SUMMARY INTERVAL 2325'TO 4406' ' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 141 @ 2954' 3 @ 2359' 44.9 TRIP GAS- CUTTING GAS 0 @ 4500' 0 @ 4500' 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- i METHANE(C-1) 27621 @ 2954' 647 @ 2358' 9014.6 CONNECTION GAS HIGH- ETHANE(C-2) 102 @ 2954' 0 @ 3019' 2.3 AVG- PROPANE(C-3) 42 @ 2942' 0 @ 3019' 0.9 CURRENT 37 BUTANE(C-4) 0 @ 4500' 0 @ 4500' 0.0 CURRENT BACKGROUND/AVG 65/50 PENTANE(C-5) 0 @ 4500' 0 @ 4500' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Siltstone PRESENT LITHOLOGY 70%Siltstone,30%Sand DAILY ACTIVITY Continue drilling out Shoe Track.Drill 20'new of hole from 2340'to 2360'.Circulate bottoms up and displace well to 9.2 ppg LSND.Perform FIT with 430 psi bled down to 256 psi,11.4 SUMMARY ppg EMW.Drill from 2360'to 4406'as of midnight. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4,795 REPORT BY Zach Beekman ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT OP09-S1 CANRIG REPORT FOR Cormier,Smith,Buchanan DATE Jun 19,2011 DEPTH 7850' PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 4406' 24 HOUR FOOTAGE 3444' CASING INFORMATION 20"@ 160'13 3/8"@ 2325' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7967.94 82.15 3.18 3271.01 SURVEY DATA 7871.73 82.14 2.6 3257.86 7774.84 82.26 1 3244.71 7680.51 82.12 3.5 3231.89 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 121/4" Hycalog MSX6-A6C E142873 3x14,3x15 2340' - 5510' 30.8 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 356.7 @ 5560' 23.6 @ 6965' 242.1 212.25 FT/HR SURFACE TORQUE 16284 @ 7010' 3826 @ 4406' 7849.7 8678.90 AMPS WEIGHT ON BIT 21 @ 6969' 0 @ 7294' 6.4 17.058 KLBS ROTARY RPM 142 @ 5399' 65 @ 6968' 130.5 123.31 RPM PUMP PRESSURE 2464 @ 7290' 1414 @ 4869' 2119.2 1861.31 PSI DRILLING FLUIDS REPORT DEPTH 7850/3255 MW 9.5 VIS 50 PV 12 YP 21 FL 4.6 Gels 10/19/24 CL- 1250 FC 1/- SOL 6.2 SD - OIL 3/91 MBT 17 pH 9.4 Ca+ 100 CCI - MWD SUMMARY INTERVAL 2325'TO 7850' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 103 @ 4701' 0 @ 4895' 34.5 TRIP GAS - CUTTING GAS 0 @ 7850' 0 @ 7850' 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY - METHANE(C-1) 22320 @ 4701' 98 @ 4895' 7005.9 CONNECTION GAS HIGH- ETHANE(C-2) 47 @ 5887' 0 @ 6271' 2.8 AVG- PROPANE(C-3) 14 @ 5887' 0 @ 6271' 1.1 CURRENT 24 BUTANE(C-4) 0 @ 7850' 0 @ 7850' 0.0 CURRENT BACKGROUND/AVG 24/10 PENTANE(C-5) 0 @ 7850' 0 @ 7850' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Claystone/Siltstone PRESENT LITHOLOGY Sand 60%,Claystone 30%,Siltstone 10% DAILY ACTIVITY SUMMARY Continue drilling ahead from 4406'to 7850'as of midnight. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4795 REPORT BY Zach Beekman ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT OP09-S1 CANRIG REPORT FOR Cormier,Smith,Buchanan DATE Jun 20,2011 DEPTH 9120' PRESENT OPERATION Back ream out of hole TIME 24:00:00 YESTERDAY 7850' 24 HOUR FOOTAGE 1270' CASING INFORMATION 20"@ 160' 13 3/8"@ 2325' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9020.39 82.25 358.19 3412.97 SURVEY DATA 8921.65 82.53 358.51 3399.89 8829.77 82.12 358.47 3357.62 8733.97 82.23 359.73 3374.58 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12 1/4" Hycalog MSX6-A6C E142873 3x14,3x15 2340' 9120' 6780' 39.1 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 361.7 @ 8046' 0.9 @ 9117' 243.6 0.928 FT/HR SURFACE TORQUE 20120 @ 9101' 6855 @ 8906' 11827.2 12654.335 AMPS WEIGHT ON BIT 30 @ 9117' 0 @ 9027' 7.3 30.604 KLBS ROTARY RPM 141 @ 8564' 55 @ 9115' 126.4 83.447 RPM PUMP PRESSURE 2660 @ 8901' 1123 @ 9027' 2423.7 2265.874 PSI DRILLING FLUIDS REPORT DEPTH 9120/3429 MW 9.25 VIS 50 PV 11 YP 24 FL 4.5 Gels 14/21/23 CL- 1300 FC 1/- SOL 5.7 SD - OIL 3/91 MBT 15 pH 9.7 Ca+ 80 CCI - MWD SUMMARY INTERVAL 2325 TO 9120 TOOLS Gamma,Resisitivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 27 @ 8460' 1 @ 9115' 11.9 TRIP GAS- CUTTING GAS 0 @ 9117' 0 @ 9117' 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 6102 @ 8460' 313 @ 9115' 2342.7 CONNECTION GAS HIGH- ETHANE(C-2) 39 @ 8898' 0 @ 8806' 8.8 AVG- PROPANE(C-3) 24 @ 8566' 0 @ 8702' 3.2 CURRENT 2 BUTANE(C-4) 0 @ 9117' 0 @ 9117' 0.0 CURRENT BACKGROUND/AVG-/15 PENTANE(C-5) 0 @ 9117' 0 @ 9117' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Siltstone PRESENT LITHOLOGY Sand 50%,Siltstone 30%,Carbonaceous Shale 10%,Sandstone 10% DAILY ACTIVITY Rotary drilling from 7850'-9120'and found a hard spot.Vary weight on bit and RPM attempting to increase ROP and minimize stick/slip.Backream 120'and go back to bottom with same SUMMARY results.Circulate bottoms up 3.5 times.Monitor well.Backream 5 stands and attempt to pull out of hole on elevators.Wash and ream to 8605'.Circulate bottoms up 1 time.Back reaming out of hole as of midnight. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4795 REPORT BY Zach Beekman ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT OP09-S1 CANRIG REPORT FOR Cormier,Smith,Buchanan DATE Jun 21,2011 DEPTH 9120' PRESENT OPERATION Picking up BHA TIME 24:00:00 YESTERDAY 9120' 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@160' 13 3/8"@ 2325' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9020.39 82.25 358.19 3412.97 SURVEY DATA 8921.65 82.53 358.51 3399.89 8829.77 82.12 358.47 3357,62 8733.97 8223 359.73 3374.58 8638.55 82.17 0.87 3361.63 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12 1/4" Hycalog MSX6-A6C E142873 3x14,3x15 2325' 9120' 6795' 39.1 - - 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 FLUIDS REPORT DEPTH 91203429' MW 9.2 VIS 60 PV 14 YP 25 FL 5 Gels 15/27/31 CL- 1400 FC 1/- SOL 6 SD - OIL 3/92 MBT 17 pH 9.6 Ca+ 80 CCI - MWD SUMMARY INTERVAL 2325'TO 9120' TOOLS Gamma,Resistivity,Pressure While Drilling 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 Sand 50%,Siltstone 30%,Carbonaceous Shale 10%,Sandstone 10% DAILY ACTIVITY Back reaming from 7085'-3128'laying down 14 joints.Circulate bottoms up 2.5 times while cleaning chunks of clay out of possum bellies and flow line.Back ream to shoe.Circulate bottoms SUMMARY up 3.5 times.Monitor well-STATIC.Pump dry job and pull out of hole on elevators.Lay down a total of 97 joints of drill pipe.Lay down and pick up new BHA as of midnight. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4795 REPORT BY Zach Beekman ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT ci\iRIG OP09-St REPORT FOR Cormier,Smith,Buchanan DATE Jun 22,2011 DEPTH 9150' PRESENT OPERATION Drilling ahead TIME 24 DODO YESTERDAY 9120 24 HOUR FOOTAGE 30 CASING INFORMATION 20"@ 160' 13 3/8"@ 2325' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9020.39 82.25 358.19 3412.97 SURVEY DATA 8921.65 82.53 358.51 3399.89 8829.77 82.12 358.47 3357.62 8733.97 82.23 359.73 3374.58 8638.55 82.17 0.87 3361.63 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" Hycalog MSX6-A6C E142873 3x14,3x15 2340' 9120' 6780' 39.1 2-S-WT-S-X-I-CT-PR BT 3 121/4" Hycalog MSX619-A6C E144905 3x14,3x15 9120' - 30' 11.5 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 73.3 @ 9137' 0.9 @ 9117' 15.7 4.77 FT/HR SURFACE TORQUE 20680 @ 9120' 10690 @ 9136' 15358.9 16396.46 AMPS WEIGHT ON BIT 30 @ 9117' 1 @ 9135' 19.4 27.96 KLBS ROTARY RPM 83 @ 9117' 41 @ 9150' 64.3 41.75 RPM PUMP PRESSURE 2615 @ 9121' 1620 @ 9149' 2563.1 1648.56 PSI DRILLING FLUIDS REPORT DEPTH 914673431' MW 9.25 VIS 56 PV 13 YP 23 FL 4.9 Gels 16/25/28 CL- 1400 FC 1/- SOL 6 SD - OIL 3/91 MBT 16 pH 10.0 Ca-, 80 CCI - MWD SUMMARY INTERVAL 2340'TO 9120' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 2 @ 9117' 0 @ 9120' 1.4 TRIP GAS- CUTTING GAS 0 @ 9150' 0 @ 9150' 0.0 WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 531 @ 9117' 44 @ 9120' 279.9 CONNECTION GAS HIGH- ETHANE(C-2) 0 @ 9150' 0 @ 9150' 0.0 AVG- PROPANE(C-3) 0 @ 9150' 0 @ 9150' 0.0 CURRENT 2 BUTANE(C-4) 0 @ 9150' 0 @ 9150' 0.0 CURRENT BACKGROUND/AVG 1/1 PENTANE(C-5) 0 @ 9150' 0 @ 9150' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Siltstone/Sand PRESENT LITHOLOGY Calcite cemented Siltstone 60%;Sand/Sandstone 40% DAILY ACTIVITY Pick up new BHA.Service top drive.Pick up 87 joints of new drill pipe and single in from 286'-3062'.Run in hole from 3062'-7176'working tight spots @2700,4465,5078,and 5500'.Run SUMMARY in hole to 8995'and ream and wash to bottom @9120'.Rotary drilling on hard spot from 9120'-9146'. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4795 REPORT BY Zach Beekman ENI Petroleum Nikiatchuq DAILY WELLSITE REPORT ��IriirV JRIG OP09-S1 REPORT FOR Cormier,Smith,Buchanan DATE Jun 23,2011 DEPTH 9158' PRESENT OPERATION Back reaming out of hole TIME 24:00:00 YESTERDAY 9150' 24 HOUR FOOTAGE 8' CASING INFORMATION 20"@ 160' 13 3/8"@ 2325' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9020.39 82.25 358.19 3412.97 8921.65 82.53 358.51 3399.89 SURVEY DATA 8829.77 82.12 358.47 3357.62 8733.97 82.23 359.73 3374.58 8638.55 82.17 0.87 3361.63 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12 1/4" Hycalog MSX619-A6C E144905 3x14,3x15 9120' 9158' 38' 19.5 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 4.8 @ 9150' 0.9 @ 9157' 2.1 0.931 FT/HR SURFACE TORQUE 18163 @ 9151' 14288 @ 9158' 17646.9 14288.925 AMPS WEIGHT ON BIT 29 @ 9151' 10 @ 9153' 22.7 17.837 KLBS ROTARY RPM 129 @ 9158' 41 @ 9150' 102.9 129.544 RPM PUMP PRESSURE 2507 @ 9156' 1594 @ 9151' 2462.3 2501.957 PSI DRILLING FLUIDS REPORT DEPTH 914673431' MW 9.20 VIS 50 PV 12 YP 22 FL 4.8 Gels 13/23/25 CL- 1400 FC 1/- SOL 6 SD - OIL 3/91 MBT 16 pH 9.8 Ca+ 80 CCI - MWD SUMMARY INTERVAL 2340'TO 9158' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 2 @ 9158' 1 @ 9150' 1.7 TRIP GAS- CUTTING GAS 0 @ 9158' 0 @ 9158' 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 317 @ 9156' 216 @ 9150' 246.3 CONNECTION GAS HIGH- ETHANE(C-2) 0 @ 9158' 0 @ 9158' 0.0 AVG- PROPANE(C-3) 0 @ 9158' 0 @ 9158' 0.0 CURRENT 0 BUTANE(C-4) 0 @ 9158' 0 @ 9158' 0.0 CURRENT BACKGROUND/AVG 0/1 PENTANE(C-5) 0 @ 9158' 0 @ 9158' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Siltstone/Sand PRESENT LITHOLOGY Calcite cemented siltstone 60%;Sand/Sandstone 40% DAILY ACTIVITY Rotary drill from 9146'-9152'@,1 ft/hr ROP.Tried different RPM's,varying weight,no luck.Back ream to 8995'and wash and ream back to bottom twice.No results.Back reaming SUMMARY from 9158'to surface for new bit. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4795 REPORT BY Zach Beekman ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT c .4JJRIG OP09-S1 a REPORT FOR Cormier,Smith,Buchanan DATE Jun 24,2011 DEPTH 9158' PRESENT OPERATION Tripping in hole TIME 24:001)0 YESTERDAY 9158' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160' 13 3/8"@ 2325' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9020.39 82.25 358.19 3412.97 SURVEY DATA 8921.65 82.53 358.51 3399.89 8829.77 82.12 358.47 3357.62 8733.97 82.23 359.73 3374.58 8638.55 82.17 0.87 3361.63 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12 1/4" Hycalog MSX619-A6C E144905 3x14,3x15 9120' 9158' 38' 19.5 2-5-WT-T-X-I-CT PR 4 121/4" Hughes VM3 5187446 308,1x16 9158' - - - - - 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 FLUIDS REPORT DEPTH 915873433' MW 9.3 VIS 55 PV 14 VP 23 FL 4.7 Gels 13/21/24 CL- 1400 FC 1/- SOL 5.5 SD - OIL 3/92 MBT 16 pH 9.5 Ca+ 80 CCI - MWD SUMMARY INTERVAL 2340'TO 9158' TOOLS Gamma,Resistivity,Pressure While Drilling 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 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Calcareous cemented siltstone 60%;Sand/Sandstone 40% DAILY ACTIVITY Circulate bottoms up 1 time and monitor well-static.Pull out of hole from 6505'-3923'on elevators.Fix hose on iron roughneck.Lay down BHA.Clean and clear rig floor.Pick up new BHA. SUMMARY Service rig top drive,draw works,crown,change lube filter and clean V strainer. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4795 REPORT BY Zach Beekman ENI Petroleum Nikadchuq DAILY WELLSITE REPORT RIG OP09-S1 REPORT FOR Cormier,Smith,Buchanan DATE Jun 25,2011 DEPTH 10254' PRESENT OPERATION Drilling ahead TIME 24:00:00 YESTERDAY 9158' 24 HOUR FOOTAGE 1096' CASING INFORMATION 20"@ 160'13 3/8"@ 2325' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10191.81 84.67 0.38 3569.32 SURVEY DATA 10096.27 81.62 0.11 3557.92 10001.03 81.76 0.34 3544.16 9905.46 81.33 .095 3530.1 9809.58 82.03 0.62 3516.23 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 121/2" Hughes VM3 5187446 3x18,1x16 9158' - 1096' 14.5 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 466.2 @ 9989' 0.9 @ 9159' 200.9 3.375 FT/HR SURFACE TORQUE 20602 @ 10188' 10281 @ 9405' 16278.7 15420.157 AMPS WEIGHT ON BIT 43 @ 9375' 2 @ 10090' 28.8 11,866 KLBS ROTARY RPM 136 @ 9312' 64 @ 9160' 128.7 110.443 RPM PUMP PRESSURE 3063 @ 10229' 1817 @ 9161' 2571.4 2787.905 PSI DRILLING FLUIDS REPORT DEPTH 10266/3580 MW 9.3 VIS 52 PV 12 YP 25 FL 4.2 Gels 14/22/26 CL- 1400 FC 1/- SOL 6 SD - OIL 3/91 MBT 17 pH 10.1 Ca+ 80 CCI - MWD SUMMARY INTERVAL 2340'TO 10254' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 16 @ 9944' 0 @ 9911' 6.4 TRIP GAS 0 CUTTING GAS 0 @ 10254' 0 @ 10254' 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 3354 @ 9971' 170 @ 9911' 1302.7 CONNECTION GAS HIGH- ETHANE(C-2) 0 @ 10254' 0 @ 10254' 0.0 AVG- PROPANE(C-3) 0 @ 10254' 0 @ 10254' 0.0 CURRENT 4 BUTANE(C-4) 0 @ 10254' 0 @ 10254' 0.0 CURRENT BACKGROUND/AVG 4/8 PENTANE(C-5) 0 @ 10254' 0 @ 10254' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Sandstone/Siltstone PRESENT LITHOLOGY Sand 50%;Sandstone 30%;Siltstone 20% DAILY ACTIVITY SUMMARY Trip in hole from 6975'-8986'.Fill pipe and ream/wash to 9158'.Rotary drill to 9561'.Service top drive.Drill to 10230'. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4795 REPORT BY Zach Beekman ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT OP09-S1 c1jsJRIG REPORT FOR Cormier,Smith,Buchanan DATE Jun 26,2011 DEPTH 11856' PRESENT OPERATION Drilling ahead TIME 24:00:00 YESTERDAY 10254' 24 HOUR FOOTAGE 1602' CASING INFORMATION 20"@ 160' 13 3/8"@ 2325' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11913.7 83.51 328.6 3791.3 11817.56 83.63 332.12 3780.53 SURVEY DATA 11721.32 82.91 333.88 3769.25 11625.51 81.67 334.5 3756.4 11530.1 83.37 336.53 3743.98 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 121/4" Hughes VM3 5187446 3x18,1x16 9158' - 2698' 31.5 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 474.0 @ 10427 2.3 @ 11328' 166.9 0.00000 FT/HR SURFACE TORQUE 22503 @ 11194' 13162 @ 10267' 18742.1 0.00000 AMPS • WEIGHT ON BIT 42 @ 10995' 3 @ 11657' 29.9 0.00000 KLBS ROTARY RPM 135 @ 10884' 61 @ 10287' 131.9 0.00000 RPM PUMP PRESSURE 3277 @ 11662' 2188 @ 10478' 2963.8 0.00000 PSI DRILLING FLUIDS REPORT DEPTH 11897/3791 MW 9.4 VIS 56 PV 13 YP 28 FL 4.9 Gels 17/29/33 CL- 1800 FC 1/- SOL 7 SD - OIL 3/90 MBT 18 pH 10.1 Ca+ 80 CCI - MWD SUMMARY INTERVAL 2340'TO 11856' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 224 @ 11101' 1 @ 11339' 36.6 TRIP GAS- CUTTING GAS 0 @ 11856' 0 @ 11856' 0.0 WIPER GAS- 1 CHROMATOGRAPHY(ppm) SURVEY- �, METHANE(C-1) 53259 @ 11636' 314 @ 11339' 7938.1 CONNECTION GAS HIGH- ETHANE(C-2) 633 @ 11636' 0 @ 10261' 88.3 AVG- PROPANE(C-3) 177 @ 11120' 0 @ 10261' 37.9 CURRENT 1 BUTANE(C-4) 142 @ 11631' 0 @ 10962' 15,5 CURRENT BACKGROUND/AVG 6/30 PENTANE(C-5) 68 @ 11100' 0 @ 10962' 5.2 HYDROCARBON 11945-11985 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 11945-11985 60%SAND 20% 200u SAND/SANDSTONE(11930-12000)=SAMPLE CONTAINS MOSTLY TRANSLUCENT TO CLEAR,MILKY WHITE,LIGHT GRAY AND LIGHT SANDSTONE 20% GREENISH GRAY HUES;UPPER VERY FINE TO UPPER FINE TO LOWER FINE TO TRACE UPPER FINE;WELL TO VERY WELL SORTED;SUB- SILTSTONE ROUNDED TO SUBANGULAR TRACE ROUNDED;HIGH SPHERICITY;NO ODOR;TRACE TO MODERATE OIL STAINING;60%EVEN DULL YELLOW SAMPLE FLUORESCENCE WITH 40%PATCHY BRIGHT YELLOW;INSTANTANEOUS MILKY WHITE CUT FLUORESCENCE;LIGHT BROWN TO BROWN CUT;DULL YELLOW RESIDUAL FLUORESCENCE. LITHOLOGY Sand/Sandstone/Siltstone • PRESENT LITHOLOGY Sand 70%;Sandstone 20%;Siltstone 10% DAILY ACTIVITY SUMMARY Rotary drilling from 10254'-11320'.Service rig and top drive.Cool motors from overheating issue.Continue drilling to 11856'with no other issues.No losses to formation. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4895 REPORT BY Zach Beekman • • ENI Petroleum • Nikaitchuq DAILY WELLSITE REPORT cJ\iRIG OP09-S1 REPORT FOR Cormier,Smith,Buchanan DATE Jun 27,2011 DEPTH 13220' PRESENT OPERATION Circulate/Backream TIME 24:00:00 YESTERDAY 11856' 24 HOUR FOOTAGE 1364' CASING INFORMATION 20"@ 160' 13 3/8"@ 2325' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13182.76 85.84 309.66 3928.01 13156.61 84.85 309.64 3925.89 SURVEY DATA 13061.92 83.19 309.86 3916.02 12966.32 84.36 310.41 3905.66 12870.44 83.5 309.48 3895.52 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12 1/4" Hughes VM3 5187446 3x18,1x16 9158' 13220' 4062' 40.1 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 307.2 @ 13195' 10.3 @ 12009' 155.6 FT/HR SURFACE TORQUE 23281 @ 13010' 14504 @ 12335' 19749.5 AMPS WEIGHT ON BIT 39 @ 12807' 6 @ 13197' 29.7 KLBS ROTARY RPM 135 @ 12142' 60 @ 12010' 131.4 RPM PUMP PRESSURE 3600 @ 12851' 2577 @ 12021' 3379.7 PSI DRILLING FLUIDS REPORT DEPTH 13220/3940 MW 9.4 VIS 54 PV 12 YP 28 FL 4.8 Gels 16/30/34 CL- 1400 FC 1/- SOL 7.5 SD - OIL 3/90 MBT 18 pH 9.5 Ca+ 80 CCI - MWD SUMMARY INTERVAL 2340'TO 13220' TOOLS Gamma,Resistivity,Pressure While Drilling GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 410 @ 13118' 6 @ 12009' 54.8 TRIP GAS- CUTTING GAS 0 @ 13220' 0 @ 13220' 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 87952 @ 13121' 1510 @ 12733' 12156.3 CONNECTION GAS HIGH- ETHANE(C-2) 1446 @ 13110' 24 @ 12009' 220.2 AVG- PROPANE(C-3) 782 @ 13110' 9 @ 12009' 115.6 CURRENT 23 • BUTANE(C-4) 668 @ 13110' 6 @ 12009' 89.8 CURRENT BACKGROUND/AVG 0/50 PENTANE(C-5) 470 @ 13110' 0 @ 12254' 29.9 HYDROCARBON 12986-13220 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 12986-13220 Sand;Sandstone; 41 Ou SAND/SANDSTONE(13090-13220)=MOSTLY TRANSLUCENT TO CLEAR WITH WHITE,LIGHT GRAY,DARK YELLOWISH ORANGE,LIGHT Siltstone;Claystone GREENISH GRAY,AND VERY PALE BLUE HUES;MOSTLY QUARTZ SAND MATRIX WITH ABUNDANT DARK COLORED LITHIC FRAGMENTS THROUGHOUT SAMPLE;UPPER VERY FINE TO UPPER FINE WITH SOME UPPER AND LOWER MEDIUM GRAIN SAND;MODERATELY SORTED; SUBANGULAR TO SUBROUNDED TO SOME ANGULAR;MODERATE TO HIGH SPHERICITY;FEW GRAINS APPEAR FROSTED;THINNER INTERBEDDED SILTSTONES ARE SLIGHTLY STAINED WITH PETROLEUM HYDRO-CARBONS;APPROXIMATLEY 60%-70%BRIGHT YELLOW SAMPLE FLUORESCENCE;INSTANTANEOUS WHITE TO DULL YELLOW CUT FLUORESCENCE;SLIGHT OIL ODOR;NO FREE OIL IN SAMPLE. LITHOLOGY Sand/Sandstone/Siltstone/Claystone '. PRESENT LITHOLOGY Sand 50%;Siltstone 20%;Claystone 20%;Sandstone 10% DAILY ACTIVITY Rotary Drilled from 11856'-TD @13220'with no issues.MW 9.4 ppg,ECD 11.06 @900 GPM.Circulate and condition 1 bottoms up(16,000 strokes)per stand.Stand back stand on every SUMMARY bottoms up.Circulate and condition 1/2 stand per bottoms up standing back from 12908'-12621'. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4795 REPORT BY Zach Beekman ENI Petroleum Nikai[chuq DAILY WELLSITE REPORT CANRIG OP09-S1 REPORT FOR Keener,Smith,Buchanan DATE Jun 28,2011 DEPTH 13220' PRESENT OPERATION Backreaming TIME 24:00:00 YESTERDAY 13220' 24 HOUR FOOTAGE 0' CASING INFORMATION 20"@ 160' 13 3/8"@ 2325' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13182.76 85.84 309.66 3928.01 13156.61 84.85 309.64 3925.89 SURVEY DATA 13061.92 83.19 309.86 3916.02 12966.32 84.36 310.41 3905.66 12870.44 83.5 309.48 3895.52 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 121/4" Hughes VM3 5187446 3x18,1016 9158' 13220 4062' 40.1 - - 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 FLUIDS REPORT DEPTH 13220/3940 MW 9.45 VIS 49 PV 10 YP 20 FL 4.8 Gels 11/31/33 CL- 1400 FC 1/- SOL 7 SD - OIL 3/90 MBT 20 pH 9.2 Ca+ 80 CCI - MWD SUMMARY INTERVAL 2340'TO 13220' TOOLS Gamma,Resistivity,Pressure While Drilling 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 2 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0/- PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Sand 50%;Siltstone 20%;Claystone 20%;Sandstone 10 DAILY ACTIVITY Backream from 12,621'-12,142'setting back one stand every 8000 strokes.Monitor and confirm well a static.Backream 10 minutes per stand to 9,465'working tight spot @4650-4610. SUMMARY 900 GPM,9.5 ppg MW,9.9 ECD. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4795 REPORT BY Zach Beekman • 1 I ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT OP09-S1 CAlRIG REPORT FOR Keener,Smith,Buchanan DATE Jun 29,2011 DEPTH 13220 PRESENT OPERATION Run 9 5/8"casing TIME 24:00:00 YESTERDAY 13220 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2325' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13182.76 85.84 309.66 3928.01 13156.61 84.85 309.64 3925.89 SURVEY DATA 13061.92 83.19 309.86 3916.02 12966.32 84.36 310.41 3905.66 12870.44 83.5 309.48 3895.52 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 121/4" Hughes VM3 5187446 3x18,1x16 9158 13220 4062 40.1 3-2-WT-A-E-1-FC 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 FLUIDS REPORT DEPTH 13220/3940 MW 9.4 VIS 41 PV 12 YP 13 FL 6 Gels 9/22/28 CL- 1400 FC 1/- SOL 5.5 SD - OIL 3/92 MBT 18 pH 9.2 Ca+ 80 CCI - MWD SUMMARY INTERVAL 2340 TO 13220 TOOLS Gamma,Resistivity,Pressure While Drilling 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 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Backream from 4584-2382'.Circulate and condition standing one stand back every bottoms up from 2382'-1999'.Pull out of hole on elevators.Lay down BHA.Clean rig.Change rams.Test SUMMARY BOP's.Set wear ring for running 9.625"casing.Rig up tools to run casing.Run 9.625"casing to 853'as of midnight. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4795 REPORT BY Zach Beekman ENI Petroleum N9ailchuq DAILY WELLSITE REPORT ciJiRIG OP09-S1 REPORT FOR Keener,Smith,Buchanan DATE Jun 30,2011 DEPTH 13220 PRESENT OPERATION Run 9 5/8"casing TIME 24:00:00 YESTERDAY 13220 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160'13 3/8"@ 2325' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13182.76 85.84 309.66 3928.01 13156.61 84.85 309.64 3925.89 SURVEY DATA 13061.92 83.19 309.86 3916.02 12966.32 84.36 310.41 3905.66 12870.44 83.5 309.48 3895.52 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 FLUIDS REPORT DEPTH 13220/3940 MW 9.4 VIS 42 PV 11 YP 16 FL 5.5 Gels 10/23/28 CL- 1400 FC 1/- SOL 5.5 SD - OIL 3/92 MBT 18 pH 9.2 Ca+ 80 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 2 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE(C-5) @ @ —•", HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY • DAILY ACTIVITY SUMMARY Run 9-5/8 L-80 casing.Started rotating @ 5093'RPM 45/TO 2.3.At 6712'bring RPM's up to 60 TO-3.5.Run casing to 12008'.Rotating @ 75 RPM and 7.9 TQ. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4795 REPORT BY Zach Beekman • II ENI Petroleum DAILY WELLSITE REPORT CANRIG OP09-S1 REPORT FOR Cormier,Goerlich,Buchanan DATE Jun 13,2011 DEPTH 561' PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 160' 24 HOUR FOOTAGE 401' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 201.91 0.08 16.03 201.91 262.65 0.07 36.21 262.65 SURVEY DATA 322.70 0.04 57.52 322.70 382.81 0.31 21.75 382.81 473.14 0.85 3.07 473.14 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #1 16" Hughes MX-1 5191534 3x20,1x16 160' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ 77.32277 FT/HR SURFACE TORQUE @ @ 0.00000 AMPS WEIGHT ON BIT @ @ 13.18331 KLBS ROTARY RPM @ @ 0.00000 RPM PUMP PRESSURE @ @ 691.66058 PSI DRILLING FLUIDS REPORT DEPTH 429' MW 8.95 VIS 105 PV 33 YP 36 FL NA Gels 18/38/47 CL- 2500 FC 1/NA SOL 2 SD OIL 1/98 MBT 16.5 pH 10.0 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) @ @ CONNECTION GAS HIGH NA 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 P/U 5"D.P.and 5"HWDP for drilling.Service the Rig.P/U M/U 16"Bit and Mud Motor.Fill the Conductor and test pumps to 2000 psi.Clean out 160'of Conductor and rack back 1 stand SUMMARY HWDP.P/U M/U BHA#2.Doll F/160'to 252'.Encountered Gyro issues,POOH to replace Gyro.RIH Cont.drilling F/252'to 545'40 RPM,490 gpm,720 psi and 5-25 WOB.Still having hard time obtaining Gyro Surveys while drilling. CANRIG PERSONNEL ON BOARD 2 DAILY COST$3,795 REPORT BY Steve Pike ENI Petroleum ciJ\iRIG Nika4chuq DAILY WELLSITE REPORT REPORT FOR Keener,Smith,Buchanan DATE Jul 1,2011 DEPTH 13220 PRESENT OPERATION Chasing cement TIME 24:00:00 YESTERDAY 13220 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2325'9 5/8"@ 13195' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13182.76 85.84 309.66 3928.01 13156.61 84.85 309.64 3925.89 SURVEY DATA 13061.92 83.19 309.86 3916.02 12966.32 84.36 310.41 3905.66 12870.44 83.5 309.48 3895.52 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 FLUIDS REPORT DEPTH 13220/3940 MW 9.4 VIS 45 PV 9 YP 13 FL 5.8 Gels 9/20/23 CL- 1400 FC 1/- SOL 5.5 SD - OIL 3/92 MBT 18 pH 9.0 Ca+ 80 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 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0/- PENTANE(C-5) @ @ ,• HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Run casing to 13195'rotating @75 RPM w/13.4 TO.Rig down Tesco tools.Fill casing with 9.4 ppg LSND @ 2 bbls/minute.Vent casing load plugs and confirm well is static.Circulate and SUMMARY condition hole @ 6 bbts/min.Increase rate to 8 bbls/min and incurred losses.Reduced rate back to 6 bbls/min for remainder of circulation.Rig up SLB cementers.Test lines to 3700 psi.Pump 65 bbls mud push.Drop plug and pump 356 bbls cement.Drop bottom plug and pump 10bbls water.Chase with rig pump. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4795 REPORT BY Zach Beekman ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT CANRIG OP09-S1 REPORT FOR Keener,Smith,Buchanan DATE Jul 2,2011 DEPTH 13220 PRESENT OPERATION Clean Pits/PU drill pipe TIME 240000 YESTERDAY 13220 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2325'9 5/8"@ 13195' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13182.76 85.84 309.66 3928.01 13156.61 84.85 309.64 3925.89 SURVEY DATA 13061.92 83.19 309.86 3916.02 12966.32 84.36 310.41 3905.66 12870.44 83.5 309.48 3895.52 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 FLUIDS REPORT DEPTH 13220/3940 MW 9.4 VIS 46 PV 8 VP 23 FL 5.8 Gels 11/24/29 CL- 1300 FC 1/- SOL 5.6 SD - OIL 3/91 MBT 18 pH 9.0 Ca+ 80 CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY • DAILY ACTIVITY Displace cement with rig pumps @ 8 bbls/min.6-1300 psi.Bump plug @ 9899 strokes.Pressure up to 1500 psi and check floats-OK.Bullhead 20 bbls down annular.Lay down casing tools. SUMMARY Nipple down BOP's.Set emergency slips.Cut casing joint and install pack off per Vetco Gray.Nipple up BOP's,flow line,catch can,etc.Freeze protect OA w/130 bbls diesel.Change rams I and function test.Tripping/picking up 100 stands of drill pipe. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4795 REPORT BY Zach Beekman • • • ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT OP09-S1 CANRIG REPORT FOR Keener,Smith,Buchanan DATE Jul 3,2011 DEPTH 13220 PRESENT OPERATION Service rig TIME 24:00:00 YESTERDAY 13220 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2325'9 5/8"@ 13195 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13182.76 85.84 309.66 3928.01 13156.61 84.85 309.64 3925.89 SURVEY DATA 13061.92 83.19 309.86 3916.02 12966.32 84.36 310.41 3905.66 12870.44 83.5 309.48 3895.52 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 FLUIDS REPORT DEPTH 13220/3940 MW 9.4 VIS 46 PV 8 YP 23 FL 5.8 Gels 11/24/29 CL- 1300 FC 1/- SOL 5.6 SD - OIL 3/91 MBT 18 pH 9.0 Ca+ 80 CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Trip out of hole with 73 stands of drill pipe installing WEI subs.Pick up test tools,install test plug.Test stack and choke manifold to 3500 psi.4.7-7"variable rams and IBOP tests tailed. SUMMARY Change rams and IBOP insert.Retest.Service Top Drive.Change swivel packing.Electrical work in drilling module. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4875 REPORT BY Zach Beekman • ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT RIG OP09-St REPORT FOR Keener,Musumeci,Buchanan DATE Jul 4,2011 DEPTH 13220 PRESENT OPERATION Run in hole TIME 24:00:00 YESTERDAY 13220 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2325'9 5/8"@ 13195' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13182.76 85.84 309.66 3928.01 13156.61 84.85 309.64 3925.89 SURVEY DATA 13061.92 83.19 309.86 3916.02 12966.32 84.36 310.41 3905.66 12870.44 83.5 309.48 3895.52 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 3/4" Hycalog RSR616M-D1 E144067 6x14 13220' - 0 0 - - 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 FLUIDS REPORT DEPTH 13220/3940 MW 9.4 VIS 47 PV 11 YP 13 FL 10.0 Gels 5/5/5 CL- 89000 FC -/1 SOL 8.29 SD - OIL 65/35 MBT - pH - Ca-, - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Trouble shoot PFD and top drive.Pick up and run in hole with 5"drill pipe and lay down bad joints of hard band.Pick up 5"drill pipe and stand back in derrick with WEI Subs.Pick up 8.75" SUMMARY bit and BHA#7,pick up 4.5"drill pipe to 611'.Work on skate and shallow test BHA.Continue to pick up 4.5"drill pipe and run in hole to 5712'as of midnight. CANRIG PERSONNEL ON BOARD 4 DAILY COST$5875 REPORT BY Zach Beekman ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT OPo9-S1 ,BRAG REPORT FOR Keener,Musumeci,Buchanan DATE Jul 05,2011 DEPTH 13240 PRESENT OPERATION Circulate bottoms up TIME 24:00:00 YESTERDAY 13220 24 HOUR FOOTAGE 20 CASING INFORMATION 23"@ 160'13 3/8"@ 2325'9 5/8"@ 13220' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13182.76 85.84 309.66 3928.01 13156.61 84.85 309.64 3925.89 SURVEY DATA 13061.92 83.19 309.86 3916.02 12966.32 84.36 310.41 3905.66 12870.44 83.5 309.48 3895.52 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 3/4" Hycalog RSR616M-D1 El 44067 6x14 13220 - 20' 1 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 190.4 @ 13220 40.2 @ 13221 157.0 117.075 FT/HR SURFACE TORQUE 10567 @ 13238 9829 @ 13236 10213.9 10148.97 AMPS WEIGHT ON BIT 16 @ 13220 3 @ 13240 8.4 3.624 KLBS ROTARY RPM 58 @ 13228 58 @ 13227 58.7 58.667 RPM PUMP PRESSURE 2966 @ 13236 2947 @ 13221 2958.1 2959.629 PSI DRILLING FLUIDS REPORT DEPTH 13240/3940 • MW 9.4 VIS 53 PV 14 YP 15 FL 11.5 Gels 5/5/6 CL- 96000 FC -/1 SOL 7.48 SD - OIL 64/36 MBT - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 190 @ 13240 24 @ 13220 100.7 TRIP GAS- CUTTING GAS 0 @ 13240 0 @ 13240 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 43377 @ 13240 5147 @ 13220 22259.6 CONNECTION GAS HIGH - ETHANE(C-2) 446 @ 13239 76 @ 13220 258.3 AVG - PROPANE(C-3) 302 @ 13238 88 @ 13221 216.7 CURRENT 1 BUTANE(C-4) 268 @ 13238 79 @ 13221 193.3 CURRENT BACKGROUND/AVG 5/- PENTANE(C-5) 236 @ 13238 72 @ 13221 172.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Sand 60%;Siltstone 20%;Cement 20% DAILY ACTIVITY Continue to pick up 4.5"drill pipe and run in hole to 9615'.Start to run in hole with 5"drill pipe from derrick,wash down from 12,964'to 13,099'and tag cement.Circulate surface to surface till SUMMARY 9.4 ppg was seen in and out.Test 9 5/8"casing and shoe to 3000 psi for 30 min.Displace LSND to 9.4 ppg FazePro.Cut and slip drilling line.Test W EI Equipment to 5000 psi for 10 min.Drill plug and shoe track from 13,099'to 13,220'and 20'new hole to 13,240'.Circulate hole clean for FIT as of midnight. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4875 REPORT BY Zach Beekman ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT OP09-S1 c1i\iRIG REPORT FOR Keener,Musumeci,Buchanan DATE Jul 06,2011 DEPTH 15540 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 13220 24 HOUR FOOTAGE 2320 CASING INFORMATION 20"@ 160'13 3/8"@ 2325'9 5/8"@ 13195' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15555.08 87.65 299.69 3918.41 15457.49 87.91 300.48 3914.63 SURVEY DATA 15358.82 88.79 301.13 3911.79 15260.78 90.02 30124 3910.77 15162.07 90.45 301.8 3911.18 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 83/4" Hycalog RSR616M-D1 E144067 6x14 13220 - 2340 14.6 - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 410.4 @ 14446 10.3 @ 15508 266.9 303.760 FT/HR SURFACE TORQUE 19353 @ 15503 8644 @ 13243 13714.6 17159.052 AMPS WEIGHT ON BIT 34 @ 13259 0 @ 13248 6.1 7.849 KLBS ROTARY RPM 124 @ 15125 39 @ 13242 117.7 122.699 RPM PUMP PRESSURE 3771 @ 15321 1380 @ 15420 3454.0 3713.139 PSI DRILLING FLUIDS REPORT DEPTH 15540/3915 MW 9.4 VIS 52 PV 18 YP 18 FL 8.0 Gels 6/6/7 CL- 85000 FC -/2 SOL 7.53 SD - OIL 63/37 MBT - pH - Ca+ - CC! - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 543 @ 14176 1 @ 13314 266.1 TRIP GAS- CUTTING GAS 0 @ 15540 0 @ 15540 0.0 WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 274129 @ 14542 152 @ 13314 45757.3 CONNECTION GAS HIGH 322 ETHANE(C-2) 2600 @ 14548 2 @ 13260 564.3 AVG 45 PROPANE(C-3) 1546 @ 14548 0 @ 13260 266.0 CURRENT 3 BUTANE(C-4) 1483 @ 14567 0 @ 13260 251.4 CURRENT BACKGROUND/AVG 100/150 PENTANE(C-5) 879 @ 14567 0 @ 13264 153.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Siltstone PRESENT LITHOLOGY Sand 90%;Siltstone 10% DAILY ACTIVITY SUMMARY Perform FIT,780 psi Max.13.0 ppg EMW.Drill ahead from 13,240'to 15,540'120 RPM,553 gpm,3740 psi,8K WOB,15K TIRO and 11.4 ppg. CANRIG PERSONNEL ON BOARD 4 DAILY COST$4875 REPORT BY Zach Beekman ENI Petroleum DAILY WELLSITE REPORT CANIRIG OP09-St REPORT FOR Keener/Musumeci/Buchanan DATE Jul 07,2011 DEPTH 18040 PRESENT OPERATION Drilling Ahead TIME 24130130 YESTERDAY 15540 24 HOUR FOOTAGE 2500 CASING INFORMATION 20"@ 160' 13 3/8"@ 2325'9 5/8"@ 13195' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 18213.89 88.05 296.11 3916.30 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.75 Hycalog RSR616M-D1 E144067 6x14 13220 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 380.9 @ 17078.00000 7.7 @ 16333.00000 278.7 221.22609 FT/HR SURFACE TORQUE 22287 @ 17039.00000 10981 @ 15620.00000 17249.5 19352.31836 AMPS WEIGHT ON BIT 31 @ 16701.00000 0 @ 16210.00000 6.8 7.72224 KLBS ROTARY RPM 125 @ 18033.00000 51 @ 15914.00000 119.7 124.13831 RPM PUMP PRESSURE 4161 @ 18001.00000 2693 @ 16081.00000 3763.9 4059.44580 PSI DRILLING FLUIDS REPORT DEPTH 17624 MW 9.4 VIS 50 PV 15 YP 18 FL 6.0 Gels 6/7/7 CL- 75000 FC -/2 SOL 7.99 SD - OIL 64/36 MBT - pH - Ca+ 2.08 CCI - MWD SUMMARY INTERVAL 15540 TO 18040 TOOLS Xceed 675;Periscope 675;Telescope 675;LWD-ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 513 @ 16265.00000 1 @ 15673.00000 293.3 TRIP GAS CUTTING GAS 0 @ 18040.00000 0 @ 18040.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 93423 @ 16740.00000 240 @ 15672.00000 47297.3 CONNECTION GAS HIGH ETHANE(C-2) 2627 @ 16103.00000 4 @ 15673.00000 588.7 AVG PROPANE(C-3) 1532 @ 16103.00000 2 @ 15673.00000 287.5 CURRENT BUTANE(C-4) 1338 @ 17018.00000 1 @ 15673.00000 312.7 CURRENT BACKGROUND/AVG 40 PENTANE(C-5) 999 @ 17018.00000 1 @ 15673.00000 215.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 15540-18040 Primarily Unconsolidated Sands and Sandstone MAX 513u OA Sands LITHOLOGY Unconsolidated Sand,Sandstone,Siltstone PRESENT LITHOLOGY 90%Unconsolidated Sand,10%Sandstone DAILY ACTIVITY SUMMARY Rotary Drilling ahead from 15540'to 18040'MD. CANRIG PERSONNEL ON BOARD 5 DAILY COST DML-$3695; Rigwatch-$1250 REPORT BY E.Opitz ENI Petroleum DAILY WELLSITE REPORT c .4IiRIG OP09-S1 REPORT FOR Cormier/Lamarina/Buchanan DATE Jul 08,2011 DEPTH 19847 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 18040 24 HOUR FOOTAGE 1807 CASING INFORMATION 20"@ 160' 13 3/8"@ 2325'9 5/8"@ 13195' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 19785.13 92.62 300.38 3876.48 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.75 Hycalog RSR616M-D1 E144067 6014 13220 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 382.9 @ 19555.00000 4.7 @ 18321.00000 253.9 289.81253 FT/HR SURFACE TORQUE 26025 @ 19284.00000 15851 @ 18571.00000 19175.6 20277.38867 AMPS WEIGHT ON BIT 39 @ 18867.00000 0 @ 19357.00000 7.5 4.40590 KLBS ROTARY RPM 124 @ 18053.00000 76 @ 19371.00000 116.4 118.32666 RPM PUMP PRESSURE 4159 @ 19533.00000 3155 @ 18670.00000 3995.7 4106.12305 PSI DRILLING FLUIDS REPORT DEPTH 19574 MW 9.4 VIS 50 PV 16 YP 19 FL 4.6 Gels 7/7/8 CL- 79000 FC -/2 SOL 8.27 SD - OIL 66/34 MBT - pH - Ca+ 2.34 CCI - MWD SUMMARY INTERVAL 18040 TO 19847 TOOLS Xceed 675;Periscope 675;Telescope 675;LWD-ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 453 @ 18735.00000 13 @ 19362.00000 252.3 TRIP GAS CUTTING GAS 0 @ 19847.00000 0 @ 19847.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 79121 @ 18735.00000 2173 @ 19460.00000 36185.9 CONNECTION GAS HIGH ETHANE(C-2) 653 @ 18613.00000 19 @ 19362.00000 318.2 AVG PROPANE(C-3) 512 @ 19412.00000 7 @ 19362.00000 156.5 CURRENT BUTANE(C-4) 473 @ 19028.00000 10 @ 19362.00000 204.9 CURRENT BACKGROUND/AVG 29 PENTANE(C-5) 394 @ 19491.00000 9 @ 19362.00000 142.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 18040-19847 Primarily Unconsolidated Sands and Sandstone MAX 453u OA Sands LITHOLOGY Unconsolidated Sand,Sandstone,Siltstone PRESENT LITHOLOGY 90%Unconsolidated Sand;10%Sandstone DAILY ACTIVITY SUMMARY Rotary drilling from 18040'to 19847'MD, CANRIG PERSONNEL ON BOARD 4 DAILY COST DML-$3765; Rigwatch-$1250 REPORT BY E.Opitz ENI Petroleum DAILY WELLSITE REPORT OP09-S1 CANIRIG REPORT FOR Cormier/Lamarin a/Buchanan DATE Jul 9,2011 DEPTH 21085 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 19847 24 HOUR FOOTAGE 1238 CASING INFORMATION 20"@ 160' 13 3/8"@ 2325 9 5/8"@ 13195' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 21160.98 91.45 299.92 3869.4 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.75 Hycalog RSR616M-D1 E144067 6x14 13320 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 446.0 @ 20538.00000 10.2 @ 21046.00000 210.5 50.10557 FT/HR SURFACE TORQUE 26086 @ 2040830000 18184 @ 2080030000 20044.9 2225734961 AMPS WEIGHT ON BIT 18 @ 20479.00000 0 @ 20972.00000 5.3 12.45835 KLBS ROTARY RPM 121 @ 20044.00000 77 @ 20864.00000 1173 80.46096 RPM PUMP PRESSURE 4279 @ 20961.00000 1857 @ 21043.00000 4111.9 4035.85596 PSI DRILLING FLUIDS REPORT DEPTH 20929 MW 9.4 VIS 51 PV 16 YP 19 FL 5.0 Gels 7/8/8 CL- 82500 FC -/2 SOL 8.59 SD - OIL 66/34 MBT - pH - Ca-, 2.47 CCI - MWD SUMMARY INTERVAL 19847 TO 21085 TOOLS Xceed 675;Periscope 675;Telescope 675;LWD-ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 462 @ 20390.00000 9 @ 20699.00000 233.5 TRIP GAS CUTTING GAS 0 @ 21085.00000 0 @ 21085.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 78371 @ 20530.00000 979 @ 20475.00000 37702.5 CONNECTION GAS HIGH ETHANE(C-2) 659 @ 20530.00000 9 @ 20475.00000 302.7 AVG PROPANE(C-3) 391 @ 20464.00000 4 @ 20699.00000 124.5 CURRENT BUTANE(C-4) 502 @ 20466.00000 7 @ 20699.00000 169.8 CURRENT BACKGROUND/AVG 17 PENTANE(C-5) 325 @ 20466.00000 4 @ 20699.00000 108.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 19847-21085 Primarily Unconsolidated Sands and Sandstone MAX 462u OA Sands LITHOLOGY Unconsolidated Sand;Sandstone;Siltstone PRESENT LITHOLOGY 80%Unconsolidated Sand;10%Sandstone;10%Siltstone DAILY ACTIVITY SUMMARY Rotary drill from 19847 to 20440'MD.Troubleshoot communication issues with Xceed tool.Resume drilling to 21085'MD. CANRIG PERSONNEL ON BOARD 5 DAILY COST DML-$3695;Rigwatch-$1250 REPORT BY E. Opitz ENI Petroleum DAILY WELLSITE REPORT CAJIRiG OP09-S1 REPORT FOR Cormier/Lamarina/Buchanan DATE Jul 10,2011 DEPTH 22370 PRESENT OPERATION Circulating Hole Clean TIME 24:00:00 YESTERDAY 21085 24 HOUR FOOTAGE 1285 CASING INFORMATION 20"@ 160'13 3/8"@ 2325'9 5/8"@ 13195' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 22305.86 99.37 298.14 3791.50 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.75 Hycalog RSR616M-D1 E144067 6x14 13220 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 243.8 @ 22149.00000 6.8 @ 21364.00000 147.0 109.53794 FT/HR SURFACE TORQUE 25633 @ 21445.00000 18784 @ 21743.00000 212012 21714.80078 AMPS WEIGHT ON BIT 19 @ 21339.00000 0 @ 22369.00000 4.6 0.36743 KLBS • ROTARY RPM 121 @ 21603.00000 71 @ 22253.00000 114.8 118.35574 RPM PUMP PRESSURE 4247 @ 21528.00000 3520 @ 22145.00000 4126.6 4033.11963 PSI DRILLING FLUIDS REPORT DEPTH 22222 MW 9.4 VIS 51 PV 16 VP 18 FL 4.4 Gels 7/7/8 Cl.- 82500 FC -/2 SOL 8,69 SD - OIL 67/33 MBT - pH - Car- - CCI - MWD SUMMARY INTERVAL 21085 TO 22370 TOOLS Xceed 675,Periscope 675,Telescope 675,LWD-ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 165 @ 21555.00000 2 @ 22012.00000 72.4 TRIP GAS CUTTING GAS 0 @ 22370.00000 0 @ 22370.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 27967 @ 21644.00000 377 @ 22012,00000 9362.8 CONNECTION GAS HIGH ETHANE(C-2) 952 @ 21589.00000 2 @ 22012.00000 102.6 AVG I PROPANE(C-3) 409 @ 21589.00000 3 @ 22012.00000 54.2 CURRENT BUTANE(C-4) 338 @ 21355.00000 6 @ 22012.00000 71.9 CURRENT BACKGROUND/AVG 12 PENTANE(C-5) 358 @ 21355.00000 6 @ 22012.00000 54.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 21085-21750,22220-22370 Primarily Unconsolidated Sands and Sandstone MAX 165u OA Sands LITHOLOGY Unconsolidated Sand,Sandstone,Siltstone PRESENT LITHOLOGY 80%Unconsolidated Sand,10%Siltstone,10%Sandstone DAILY ACTIVITY SUMMARY Rotary doll from 21085'to 22370'MD TD.Circulating hole clean. CANRIG PERSONNEL ON BOARD 5 DAILY COST DML-$3695;Rigwatch-$1250 REPORT BY E.Opitz • • ENI Petroleum DAILY WELLSITE REPORT CArIRiG OP09-S1 REPORT FOR Cormier,Goerlich,Buchanan DATE Jun 14,2011 DEPTH 2205' PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 561' 24 HOUR FOOTAGE 1644' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1745.37 25.82 7.99 1676.97 1841.25 27.15 8.78 1762.78 SURVEY DATA 1936.26 30.5 6.97 1846.01 2032.39 32.39 6.33 1928.02 2127.04 36.54 6.86 2006.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #1 16" Hughes MX-1 5191534 3x20,10 16 160' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 436.0 @ 2134' 27.5 @ 965' 142.1 141.86346 FT/HR SURFACE TORQUE 21870 @ 2208' 0 @ 1536' 1645.3 0.00000 AMPS WEIGHT ON BIT 41 @ 959' 0 @ 1372' 16.8 18.63880 KLBS ROTARY RPM 75 @ 705' 0 @ 1155' 15.7 0.00000 RPM PUMP PRESSURE 1463 @ 1979' 622 @ 676' 1040.6 1260.47510 PSI DRILLING FLUIDS REPORT DEPTH 194771859' MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 97 @ 2206' 0 @ 1600' 2.0 TRIP GAS NA CUTTING GAS 0 @ 2210' 0 @ 2210' 0.0 WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) 18250 @ 2206' 42 @ 1600' 355.2 CONNECTION GAS HIGH NA ETHANE(C-2) 34 @ 1803' 0 @ 1933' 1.4 AVG 2 PROPANE(C-3) 15 @ 1803' 0 @ 1933' 0.6 CURRENT 31 • BUTANE(C-4) 0 @ 2210' 0 @ 2210' 0.0 CURRENT BACKGROUND/AVG 30 PENTANE(C-5) 0 @ 2210' 0 @ 2210' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to drill and slide from 545'to 2205',WOB 10-30K,40 RPM,596 gpm and 1200 psi as of midnight. CANRIG PERSONNEL ON BOARD 2 DAILY COST$3,795 REPORT BY Steve Pike ENI Petroleum DAILY WELLSITE REPORT OP09-S1 CANRIG REPORT FOR Cormier/Lamarina/Buchanan DATE Jul 11,2011 DEPTH 22370 PRESENT OPERATION BROOH TIME 24:00:00 YESTERDAY 22370 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2325'9 5/8"@ 13195' 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 5 8.75 Hycalog RSR616M-D1 E144067 6x14 13220 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 FLUIDS REPORT DEPTH 22370 MW 9.35 VIS 51 PV 16 YP 18 FL - Gels 7/7/8 CL- 91000 FC -/- SOL 9.17 SD - OIL 66/34 MBT - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Backreaming out of hole,circulating one BU per stand from 22370'to 21820';one BU per two stands from 21820'to 20732'.5-10 min per stand from 20732'to 19258'as of midnight. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML-$3625; Rigwatch-$1250 REPORT BY E.Opitz ENI Petroleum DAILY WELLSITE REPORT CANRIG OP09-S1 REPORT FOR Cormier/Lamarina/Buchanan DATE Jul 12,2011 DEPTH 22370 PRESENT OPERATION BROOH TIME 24:00:00 YESTERDAY 22370 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160'13 3/8"@ 2325'9 5/8"@ 13195' 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 5 8.75 Hycalog RSR616M-D1 E144067 6x14 13220 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 FLUIDS REPORT DEPTH 22370 MW 9.35 VIS 50 PV 16 YP 16 FL 5.4 Gels 6/7/7 CL- 91000 FC -/1 SOL 8.7 SD - OIL 64/36 MBT - pH - Ca-I- - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Backream from 19258'to 16370'MD.No tight spots encountered.Stand Pipe hammer union seal needed to be repaired;rig serviced during downtime.Continue to backream from SUMMARY 16370'to 12390'MD;no tight spots encountered. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML-$3625;Rigwatch-$1250 REPORT BY E.Opitz ENI Petroleum DAILY WELLSITE REPORT OP09-S1 CANRIG REPORT FOR Cormier/Lamarina/Buchanan DATE Jul13,2011 DEPTH 22370 PRESENT OPERATION Run Casing TIME 24:00:00 YESTERDAY 22370 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2325'9 5/8"@ 13195' 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 FLUIDS REPORT DEPTH 22370 MW 9.35 VIS 50 PV 15 YP 19 FL - Gels 5/5/6 CL- 87000 FC - SOL 8.36 SD - OIL - MBT - pH - Ca-, - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue BROOH to 10000'MD.Circulate 2x BU,then continue to POOH on elevators.LD BHA.RU casing to RIH 5.5"slotted liner CANRIG PERSONNEL ON BOARD 2 DAILY COST DML-$2685; Rigwatch-$1250 REPORT BY E.Opitz ENI Petroleum DAILY WELLSITE REPORT OP09-S1 CANRIG REPORT FOR Cormier/Lamarina/Buchanan DATE Jul 14,2011 DEPTH 22370 PRESENT OPERATION RIH casing TIME 24:00:00 YESTERDAY 22370 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2325'9 5/8"@ 13195' 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 5 8.75 Hycalog RSR616M-D1 E144067 6x14 13220 22370 9150 66.4 2-2-WT-T-X-I-CT 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 FLUIDS REPORT DEPTH 22370 MW 9.4 VIS 60 PV 15 YP 17 FL - Gels 6/6/7 CL- 90000 FC - SOL 8.26 SD - OIL 64/36 MBT - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to RIH with 5.5"slotted liner to 8718'.PU hanger and continue to RIH with DP filling every 10 stands. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML-$2685;Rigwatch-$1250 REPORT BY E.Opitz 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.