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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 22,110' feet N/A feet true vertical 4,003' feet N/A feet Effective Depth measured 22,099' feet 11,871' feet true vertical 4,004' feet 4,037' feet Perforation depth Measured depth 12,784'-22,089' feet True Vertical depth 4,096'-4,004' feet Tubing (size, grade, measured and true vertical depth)2-7/8"6.4# L-80, Tenarus Blue 11,740' 4,020' Packers and SSSV (type, measured and true vertical depth)HAL PHL 11,871' 4,037' 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 Oil Pool 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 Stefano Pierfelici Digital Signature with Date:1/16/2022 Contact Name: Contact Email: Authorized Title:Contact Phone: 322-659 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 184 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379Well Operations Project Manager Gas-Mcf MD 210 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 341 9578 738 227328 147 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 405 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 0391283, 0388571, 0388581, 0388583 Nikaitchuq - Schrader Bluff Oil Pool Eni US Operating CO. Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 219-126 50-629-23639-60-00 3700 Centerpoint Drive Anchorage, AK 99503 3. Address: SP03-NE2 L1 N/A Length 160 2916 158'Conductor Surface Intermediate 16" 13-3/8" Size 158' 9-5/8" Slotted Slotted N/A 5,210 psi 6,890 psi measured TVD Production Liner 12,962 9,420 Casing Structural 6,065' 5-1/2" 10,275' 12,767'-22,099'4,086'-4,003' Plugs Junk measured 3,403'3,121' Burst Collapse N/A 2,480 psi 4,790 psi p k ft t Fra O s 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 Stefano Pierfelici By Samantha Carlisle at 8:02 am, Jan 17, 2023 DSR-1/17/23 RBDMS JSB 012623 HAL 5-½” Oil Swell Packer 13325'SP03-NE2 Schrader Bluff ProducerAs Run 2022-12-162019-11 D&C Main bore/L12022-05 D&C L22022-09 Pull ESP on wireline2022-12 Run Middle Completion & ESPWindow 12767-12784'11820' Bottom of ESP9-5/8" 40# CSG 12962' (4096' TVD) 87º12812' Baker MLXP LTPL1: 8-3/4” OH 22110' (4003' TVD) 90°12759' RAM Seal Bore DiverterDepth (ft MD)Main boreLateral L1#1 13,100 13,100#2 14,210#3 15,320#4 18,300#5 19,800#6 20,9501 x Tracer above LEMResman Tracers Placement8-3/4” TD (2019) 22082' (4024' TVD) 92°12679' Baker SLZXP LTP Lateral Entry Module2916' (2487' TVD) 61º13-3/8" 68# CSG12755' RAM Liner Hanger12626' Baker MLZXP LTPWindow 12567-12584'12789' 3.375" IBP12808' 3.375" IBPL2: 8-3/4” OH 22084' (4041' TVD) 90° 12560' RAM Seal Bore Diverter12555' RAM Liner Hanger5-½” 15.5# L80 TH521 Slotted Liner 22052'Completion: 2-7/8" 6.4# L80 Tenaris Blue ID 2.441Wellhead: Vault MB-247 5KResman Tracer12518' BHI SLZXP LTP Lateral Entry Module11746' Discharge HeadESP cable & 3/8" chemical injection line5-½” 15.5# L80 TH521 Slotted Liner 22099'5-½” 15.5# L80 TH521 Slotted Liner 13553'12560' Bottom of Mule Shoe11905' 2-7/8" 6.4# L80 IBTM11841' BHI Liner Setting Sleeve11871' HAL PHL Packer11889' XN Nipple, 2.205 No-GoMiddle CompletionResman Tracer11693' XN Nipple, 2.205 No-Go64' XO 4-½” TH563x2-7/8" TH Blue Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/2/2022 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 32.5 Wind SW @ 32 MPH Days LTI (days) 1,063.00 Days RI (days) 85.00 POB 74.0 Daily Summary Operations 24h Forecast Finish laying matting boards. Finish preparing units for move. Split pits and sub. Move modules in and rig up. Complete berm and load pits with brine. Perform well kill operations. Nipple down tree and nipple up BOPE. Test BOPE. 24h Summary Prepare and skid rig floor into move position. Move rock washer, mud pump #3 module and Mud man shack. Lay herculite and laying matting boards. Held safety stand down on Zero Tolerance - Violence and harassment in ENI work place. Operation at 07.00 Moving and spotting rig components for SP03. 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 2 P PJSM, review rig floor skid check list. Lay top of beaver slid over. Roll up and secure hydraulic line on BOP landing. Remove skate control cable and unplug lights, secure skate camera cable. Disconnect cement hose, high pressure mud line and choke line. Roll up and secure top drive cables. Blow down steam to rig floor and rock washer. Prepare rock washer for move. Move mud pump #3 module to staging area. Disconnect suit cases from rig to valve house. 05:30 06:30 1.00 6.50 W.O. A 2 P Skid rig floor into move position. 06:30 11:00 4.50 11.00 W.O. A 2 P Continue to rig down rock washer and pull out of way with bed truck. Finish removing suit cases and stack in front of WIF. Disconnect power between complexes. Roll up high line power cable. Remove mud man shack. Start removal of berming around rig. 11:00 12:00 1.00 12.00 W.O. A 1 P Safety stand down. Topic: Zero Tolerance - Violence and harassment in ENI work place. 12:00 18:00 6.00 18.00 W.O. A 2 P Raise stompers. Move rig mats from west side of rig to east side. Clean up west side of rig. Scrape and prepare foot print at SP03 for herculite. Turn pump complex tires for crabbing. Move pump #3 to west side of rig. 18:00 00:00 6.00 24.00 W.O. A 2 P PJSM, lay out herculite and rig mats for SP03 foot print. Change out butterfly valve on suction line in pump room. Clean out obstruction in vacuum line in pits. Clean up in well bay #4. Transfer Tie in, valves, hoses and Gia-tronics for well kill operations to well bay #1. Berm around accumulator unit. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Bob Smejkal ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Viktor Torres Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative Tyler Gochenauer Doyon Drilling HSE tgochenauer@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/3/2022 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 32.0 Wind NW @ 32 MPH Days LTI (days) 1,064.00 Days RI (days) 86.00 POB 69.0 Daily Summary Operations 24h Forecast Move modules in and rig up. Complete berm and load pits with brine. Perform well kill operations. Nipple down tree and nipple up BOPE. Test BOPE. 24h Summary Continue to lay matting boards. Finish laying matting boards. Finish preparing units for move. Split pits and sub. Move down well bay and spot sub and pits. Skid floor into drill position. Lay liner and Start laying matting boards for rock washer and pump #3. Operation at 07.00 Move modules in and rig up 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. A 2 P PJSM, finish laying mats for SP03. 03:00 05:00 2.00 5.00 W.O. A 2 P Move pit and sub complexes off SI43 well bay. Position sub to travel down well bay. 05:00 08:00 3.00 8.00 W.O. A 2 P Lay matting board bridge from SI43 to SP03 for rig travel. 08:00 15:30 7.50 15.50 W.O. A 2 P Move sub base down to SP03 and shim. 15:30 20:30 5.00 20.50 W.O. A 2 P PJSM, crab pit complex from SI43 to SP03. Spot next to sub base. 20:30 22:30 2.00 22.50 W.O. A 2 P PJSM, Lower stompers and skid floor to drill position. 22:30 00:00 1.50 24.00 W.O. A 2 P Lay herculite for pump #3, rock washer and pipe shed ramp area. Start Laying mats for pump #3, rock washer and the ramp. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Bob Smejkal ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Viktor Torres Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative Tyler Gochenauer Doyon Drilling HSE tgochenauer@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/4/2022 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 15.1 Wind E @ 33 MPH Days LTI (days) 1,065.00 Days RI (days) 87.00 POB 68.0 Daily Summary Operations 24h Forecast Finish monitoring well. Install back pressure valve. Nipple down tree and nipple up BOPE. Test BOPE, Witness waived by Brian Bixby of AOGCC. Change out saver sub to TT525. 24h Summary Finish setting mats for Pump #3 and rock washer. Power up VFD house and function test top drive. Move modules in and rig up. Complete burming and load pits with brine. Perform well kill operations, bullheading 8.9 ppg inhibited brine. Start monitoring well for one hour. 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 02:00 2.00 2.00 W.O. A 2 P Finish setting mats for Pump #3, rock washer and pipe shed ramp. Hook up lines and interconnects under rig floor. 02:00 08:30 6.50 8.50 W.O. A 2 P Spot mud pump #3 module. Plug in power cables for top drive. Power up VFD house and test all top drive functions. Continue to hook up lines and interconnects under rig floor. Continue to hook up lines and interconnects under rig floor. Spot mud shack and suit cases to valve house. Layout accumulator hoses. Start berming rig. Hook up lines between pump house and rig. 08:30 15:00 6.50 15.00 W.O. A 2 P Continue berming around rig. Hook up mud pump #3 interconnects and power lines. Spot Halliburton logging shack with crane. Rig up Choke to pit interconnects on roof. Spot rock washer and cuttings tank. Pressure test brine transfer lines. Take on 832 BBLS of 8.9 ppg brine. Change out flow line air boot. Take on water to rig. 15:00 19:00 4.00 19.00 W.O. A 1 P PJSM, rig up lines for bull heading down tubing and A annulus. Rig up service lines on rock washer to rig. Install egress landings around rig. Install blank flanges on primary and secondary kill lines. Spot bleed trailer. On high line power at 16:40. 19:00 20:00 1.00 20.00 W.O. A 1 P Flood high pressure mud line and secondary kill. Flood mud pumps and test controls. Test all mud lines to 3500 psi, good test. 20:00 21:30 1.50 21.50 W.O. M 9 P Bullhead down tubing with 245 BBLS of 8.9 ppg 3% KCL/NaCl inhibited brine at 5 BPM ICP, Tubing pressure at 371 psi, A Annulus =305 psi, B Annulus =210 psi. 6 BPM final circulating pressure=392 psi, A Annulus =305 psi, B Annulus =300 psi. 21:30 23:30 2.00 23.50 W.O. M 9 P Bullhead down 955 BBLS of 8.9 ppg 3% KCL/NaCl inhibited brine at 8 BPM ICP: A Annulus =515 psi, Tubing pressure=163 psi, B Annulus =320 psi. 9 BPM FCP- A Annulus =515 psi, Tubing=598 psi, B Annulus=240 psi. 23:30 00:00 0.50 24.00 W.O. M 1 P Shut in pressures, Tubing=500 psi, A Annulus =495 psi, B Annulus=210 psi. Monitor well. Max Gas = 0 Units 24 hour loss of 8.9 ppg Brine mud = 1225 bbls. Total loss of 8.9 ppg Brine = 1225 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Bob Smejkal ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Viktor Torres Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative Tyler Gochenauer Doyon Drilling HSE tgochenauer@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/5/2022 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 15.3 Wind E @ 33 MPH Days LTI (days) 1,066.00 Days RI (days) 88.00 POB 72.0 Daily Summary Operations 24h Forecast Finish Test BOPE. Rig up and start de-completion. 24h Summary Monitor well after well killing operations. Bleed off pressure and monitor. Install back pressure valve. Nipple down tree and nipple up BOPE. Change out upper pipe ram to 2-7/8” X 5”. Change out saver sub to TT525. Start testing BOPE, Witness waived by Brian Bixby of AOGCC. Operation at 07.00 Rigging up to start de-completion. 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 Monitor well, Pressures trending down. Rig up bleed tank. 01:00 03:30 2.50 3.50 W.O. M 1 P A Annulus =81 psi, Tubing=68 psi, B Annulus =260 psi. Rig up bleed tank, bled off 83 bbls of brine. After bleed back pressure continue to drop, Tubing= -11 psi, A Annulus= -5 psi. 03:30 04:00 0.50 4.00 W.O. M 5 P Rig down hoses. 04:00 06:30 2.50 6.50 W.O. C 5 P Set back pressure valve. Nipple down tree. Prepare and clean hanger. Install high pressure riser. 06:30 15:30 9.00 15.50 W.O. C 5 P Nipple up BOP stack. Install choke and kill valves and hoses. Rig up accumulator hoses. Install flow line and bell nipple. Secure bell nipple. Function test BOPE. Install mouse hole. Mobilize TT525 saver sub and saver sub stand to rig floor. Finish loading 396 joints of TT525 drill pipe in pipe shed. 15:30 19:30 4.00 19.50 W.O. C 5 P PJSM, change out upper pipe rams from 3-1/2” X 6” to 2-7/8” X 5” variable rams. Change out Delta 425 saver sub to TT525 saver sub. 19:30 22:00 2.50 22.00 W.O. C 12 P Rig up test equipment to test BOPE. Flood system and purge air, perform shell test to 3500 psi, good test. 22:00 00:00 2.00 24.00 W.O. C 12 P Test BOPE with 2-7/8” and 5” test joints 250/3500 psi, on test #5 of 10.Test gas alarms. Test PVT and flow alarms. Witness waived by Brian Bixby of AOGCC. Note: Max Gas = 0 Units 24 hour loss of 8.9 ppg Brine mud = 30 bbls. Total loss of 8.9 ppg Brine = 1255 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Bob Smejkal ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Viktor Torres Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative Tyler Gochenauer Doyon Drilling HSE tgochenauer@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/6/2022 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 19.5 Wind NE @ 20 MPH Days LTI (days) 1,067.00 Days RI (days) 89.00 POB 78.0 Daily Summary Operations 24h Forecast Continue de-completion from 8,385’ MD. 24h Summary Finish testing BOPE, Witness waived by Brian Bixby of AOGCC. Rig up and start de-completion from 11,835’ to 8,385’ MD. Operation at 07.00 Pulling out of hole with AccessESP completion at 5485' MD. 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 12 P Finish BOPE test with 2-7/8” and 5” test joints 250/3500 psi. Perform accumulator draw down test. Witness waived by Brian Bixby of AOGCC. 04:00 05:00 1.00 5.00 W.O. C 20 P Rig down BOP test equipment. Blow down choke and kill lines. 05:00 11:00 6.00 11.00 W.O. L 5 P Mobilize equipment for de-completion. Remove beaver slide door and mobilize mobile spooler to rig floor. Hang sheaves for ground spooler, rig up elephant trunk. Stage Baker tool box. Stage thread protectors. 11:00 13:00 2.00 13.00 W.O. L 4 P Pull back pressure valve. Make up landing joint to tubing hanger and top drive. Back out lock down screws and pull tubing hanger to rig floor from 11,835’ to 11800’ MD. Pull free at 164 k, PUW=138 k. 13:00 14:30 1.50 14.50 W.O. L 20 P Dis-connect electrical and control lines. Remove penetrator. Lay down tubing hanger and swivel joint. 14:30 00:00 9.50 24.00 W.O. L 4 P PJSM, Pull out of hole with 4.5”, 12.6 PPF, HYD 563 completion tubing from 11,800’ to 8,385’ MD. Break each connection with GBR power tongs, Superior thread rep here inspecting internal coating and threads. Note: Max Gas = 0 Units 24 hour loss of 8.9 ppg Brine = 220 bbls. Total loss of 8.9 ppg Brine = 1475 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative Johnathan Lettow Doyon Drilling HSE Rig15HSE@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/7/2022 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 12.9 Wind E @ 16 MPH Days LTI (days) 1,068.00 Days RI (days) 90.00 POB 79.0 Daily Summary Operations 24h Forecast Finish rigging down decompletion tools. Clean and clear floor. Install wear ring. Pick up and run in hole with cleanout assembly. Run in hole with cleanout assembly picking up TT525 drill pipe from pipe shed. 24h Summary Continue decompletion from 8,385’ to 176’ MD. Lay down AccessESP permanent completion from 176’ to surface. Start rigging down decompletion equipment. Operation at 07.00 Picking up clean out BHA. 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. L 4 P PJSM, Pull out of hole with 4.5”, 12.6 PPF, HYD 563 completion tubing from 8,385’ to 3,500’ MD. Break each connection with GBR power tongs, Superior thread rep here inspecting internal coating and threads. 12:00 21:00 9.00 21.00 W.O. L 4 P PJSM, Pull out of hole with 4.5”, 12.6 PPF, HYD 563 completion tubing from 3,500’ to 176’ MD. Break each connection with GBR power tongs, Superior thread rep here inspecting internal coating and threads. 21:00 00:00 3.00 24.00 W.O. L 4 P Lay down AccessESP permanent completion from 176’ to surface. Remove discharge gauge line, lay down discharge head and 2 joints from BHA. Terminate ESP and injection line. Lay down motor shroud. Start rig down of decompletion equipment. Note: Max Gas = 0 Units 24 hour loss of 8.9 ppg Brine mud = 272 bbls Total loss of 8.9 ppg Brine = 1747 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative Johnathan Lettow Doyon Drilling HSE Rig15HSE@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/8/2022 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 16.7 Wind SW @ 5 MPH Days LTI (days) 1,069.00 Days RI (days) 91.00 POB 69.0 Daily Summary Operations 24h Forecast Continue to single in hole with cleanout assembly from 10,466’ to 12,518’ MD and perform cleanup cycles. Pull out of hole and lay down cleanout BHA #1. Pick up Vacs liner cleanout BHA #2 and run in hole and perform vacs cleanup cycle. Pull out of hole and lay down Vacs liner cleanout BHA #2. Pick up and make up the 2-7/8” middle string completion and run in hole as per tally. 24h Summary Finish rigging down decompletion tools. Pick up clean out assembly BHA #1 and single in hole to 10,466’ MD. Operation at 07.00 Pulling out of hole with BHA #1 at 9060' MD. 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 5 P Rig down decompletion equipment. Run ESP cable and cap line over sheaves and back to the spooling unit. Remove beaver slide doors and move small spooler off rig floor. Rig down power tongs and lower down beaver slide. 04:30 05:30 1.00 5.50 W.O. M 20 P Clean and clear rig floor, install wear bushing, while adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide to wellbore 05:30 09:00 3.50 9.00 W.O. M 4 P Mobilize BHA #1 to rig floor, make up Baker clean out assembly with liner top polish mill to 157’ MD, while adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide to wellbore. 09:00 12:00 3.00 12.00 W.O. M 4 P Single in hole with clean out assembly with 5" TT525 drill pipe from 157’ to 2,000’ MD while adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide to wellbore UW 100K DW 105K. 12:00 18:00 6.00 18.00 W.O. M 4 P Continue single in hole with cleanout assembly from 2,000’ to 6,003’ MD, while adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide to wellbore. 18:00 00:00 6.00 24.00 W.O. M 4 P Continue single in hole with cleanout assembly from 6,003’ to 10,466’ MD, while adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide to wellbore. Max Gas = 0 Units 24 hour loss of 8.9 ppg Brine mud = 326 bbls. Total loss of 8.9 ppg Brine = 2073 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative Johnathan Lettow Doyon Drilling HSE Rig15HSE@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/9/2022 Report #: 8 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 10.2 Wind WSW @ 18 MPH Days LTI (days) 1,070.00 Days RI (days) 92.00 POB 69.0 Daily Summary Operations 24h Forecast Continue to run in hole with vacs clean out BHA #2 from 4719’ and perform clean out. Pull out of hole and lay down BHA. Pick up and run in hole with middle completion and run in hole and set. 24h Summary Run in hole with clean out BHA #1 assembly to 12,518’. Perform cleanup cycle. Pull out of hole and lay down BHA #1. Pick up vacs cleanout BHA #2 and run in hole to 4719’ MD. Operation at 07.00 Performing Vacs cleanout at 13,368' MD. 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 single in hole with cleanout assembly BHA #1 from 10,466’ to 12,518’, while adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide to wellbore. 03:30 04:30 1.00 4.50 W.O. M 19 P Tagged liner top with 10K down weight at 12,518’. Reciprocate pipe from 12517’ to 12468’, with scrapper worked from 12,456 to 12,407’ at 30 Ft/min, 5 times, while pumping at 3 BPM, 220 psi without rotation. Sting into liner top and set 10K weight and rotate at 20 rpm for 1 minute while continuing to pump. Stop rotation and pumping. Pumped a total of 110 BBL had returns after 25 BBL pumped. 04:30 13:30 9.00 13.50 W.O. M 4 P Pull out of hole from 12,518’, lay down clean out BHA #1, recovered 80# of fine metal from 4 magnets, vacs tool had oily sludge with no visible solids, Polish mill had good indication of contact with liner top. 13:30 16:30 3.00 16.50 W.O. M 1 P Clean and clear rig floor, demobe and remove BHA components that are not required for next run. Mobilize equipment required for Vacs tool run. Stage GBR tongs on rig floor, and prep to pick up vacs tool snorkel pipe. 16:30 22:00 5.50 22.00 W.O. M 4 P Make up 9-5/8” vacs liner run cleanout assembly BHA #2 and run in hole to 986’. Make up mule shoe and snorkel assemble with PH-6 tubing string and vacs tool. Make up Razor back scraper, magnets and oil jars. GBR make up work string with power tongs. Clean and clear floor. 22:00 00:00 2.00 24.00 W.O. M 4 P Run in hole with vacs liner run cleanout assembly BHA #2 on 5" TT525 drill pipe from 986’ to 4719’ MD. PU=125 k, SO=110 k. Note: Max Gas = 0 Units 24 hour loss of 8.9 ppg Brine mud = 283 bbls. Total loss of 8.9 ppg Brine = 2356 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative Johnathan Lettow Doyon Drilling HSE Rig15HSE@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/10/2022 Report #: 9 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 1.8 Wind SW @ 15 MPH Days LTI (days) 1,071.00 Days RI (days) 93.00 POB 78.0 Daily Summary Operations 24h Forecast Run middle completion to depth and set Halliburton packer. Pressure test Annulus A to 2500 psi for 30 minutes charted. Release running tool and pull out of hole laying down TT525 drill pipe. 24h Summary Continue to run in hole with vacs clean out run from 4719’ to 13374’ and perform clean out. Pull out of hole and laydown BHA. Pick up and run in hole with middle completion from surface to 698’. Operation at 07.00 Running in hole with middle completion at 8015' MD. 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. M 4 P Run in hole with vacs liner run cleanout assembly BHA #2 on TT525 drill pipe from 4,719’ to 12,466’ MD, while adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide to wellbore. UW 188K, DW 102K. 04:30 07:00 2.50 7.00 W.O. M 19 P Obtain parameters, UW 188K, DW102K, engage pump 126 GPM 280 PSI, wash down to liner top at 12,518, continue to wash down to 12,582’ and began to take weight, picked up 10’ and washed back down without seeing any additional drag, Continue to wash down to 13374’ without any rotation. Some returns at surface. 07:00 13:30 6.50 13.50 W.O. M 4 P Drop a 3.0” hollow drift with 100’ of wire above down drill pipe and pull out of hole with vacs tool clean out assembly with 2 7/8” snorkel, from 13,374’ to BHA at 986’, while adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide plus metal displacement to wellbore. 13:30 19:30 6.00 19.50 W.O. M 4 P Lay down BHA from 986’ to surface, recovered 35# of fine metal on magnets, recovered primarily brine with some oily sludge in vacs tool. Oily sludge cap with 95% brine in last 3 joints in snorkel, no sand. Clear floor after laying down magnets and Vacs tool assembly. 19:30 21:30 2.00 21.50 W.O. M 20 P Clean and clear floor after lay down snorkel. Pressure wash rig floor and equipment. Pressure wash ST-100. 21:30 00:00 2.50 24.00 W.O. K 4 P Make up middle completion with 2-7/8” IBT tubing and run in hole from surface to 698’ MD. Note: Max Gas = 460 Units 24 hour loss of 8.9 ppg Brine mud = 401 bbls. Total loss of 8.9 ppg Brine = 2757 bbls. 24 Hour metal recovered = 35 lbs. Total metal recovered = 115 lbs. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative Johnathan Lettow Doyon Drilling HSE Rig15HSE@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/11/2022 Report #: 10 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -3.8 Wind E @ 22 MPH Days LTI (days) 1,072.00 Days RI (days) 94.00 POB 70.0 Daily Summary Operations 24h Forecast Continue to pull out of hole with HRDE setting tool from 11801’ to surface, laying down drill pipe and setting tool. Rig up and test BOPE. Rig up and run upper completion. 24h Summary Run in hole with middle completion to 12560' MD set packer, and test to 2500 PSI. Good test. Cut and slip drilling line, pull out of hole with HRDE setting tool from 11,841’ to 4,375’. Operation at 07.00 Rigging up to test BOPs. 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. K 5 P Continue to make up Halliburton Packer and Baker HRDE cup assembly for liner running tool and XO. Adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide to wellbore. 02:30 11:00 8.50 11.00 W.O. K 4 P Run in hole with middle completion on TT525 drill pipe from 730’ to 12487’. Obtain parameters, UW 190K DW 92K, continue to run in hole and set middle completion on depth at 12560’ while adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide to wellbore. 11:00 13:00 2.00 13.00 W.O. K 19 P Break circulation at 3 BPM, drop 1.438” OD ball and pump on seat at 3-4 BPM. With ball on seat pressure up to 1000 PSI and monitor for 1 minute, continue to pressure up to 3500 PSI to set packer, hold 3500 PSI for 10 minutes. Bleed off pressure, blow down top drive, and fluid pack kill and choke lines to test back side. Note: Packer set with 2 7/8” mule shoe at 12560’ and top of HRDE tie back sleeve at 11841'. 13:00 14:30 1.50 14.50 W.O. K 12 P Rig up chart recorder, bleed air out of system close upper rams and pressure test top of packer to 2500 PSI, charting for 30 minutes. Good test. Pressured up drill pipe to 4970 PSI and sheared the ball seat. Blow down choke manifold, along with choke and kill lines. 14:30 16:00 1.50 16.00 W.O. K 25 P Pull out of hole from 11841’ to 11801’ MD, laying down 3 Joints. Cut and slip 106’ of drilling line. Service rig. 16:00 00:00 8.00 24.00 W.O. K 4 P Pull out of hole with HRDE setting tool from 11801’ to 4,375’, while adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide, plus metal displacement to wellbore. Note: Max Gas = 414 Units 24 hour loss of 8.9 ppg Brine mud = 321 bbls. Total loss of 8.9 ppg Brine = 3078 bbs. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative Johnathan Lettow Doyon Drilling HSE Rig15HSE@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/12/2022 Report #: 11 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 8.1 Wind SE @ 9 MPH Days LTI (days) 1,073.00 Days RI (days) 95.00 POB 71.0 Daily Summary Operations 24h Forecast Run ESP completion. 24h Summary Continue to pull out of hole with HRDE setting tool from 4,375’ to surface and lay down HRDE setting tool. Test BOPE, all good no failures. Prepare to run ESP completion. Note: witness waived by AOGCC rep Austin McCloud. Operation at 07.00 Pick up and make up ESP assembly. 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 Pull out of hole laying down drill pipe with HRDE setting tool from 4,375’ to surface while adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide, plus metal displacement to wellbore. 04:30 05:00 0.50 5.00 W.O. K 4 P Lay down and inspect HRDE setting tool. All Good. 05:00 08:00 3.00 8.00 W.O. C 12 P Pull wear bushing and install test plug. Mobilize test equipment, flood BOP stack and perform shell test, good test. 08:00 13:00 5.00 13.00 W.O. C 12 P Test BOPE equipment to 250 PSI Low and 3500 PSI high for 5 minutes each, per sundry, on 5” and 2.875” test joints. Perform accumulator draw down test. Initial accumulator pressure 3050 PSI, after function 2150 PSI. 200 PSI recovery 9 Seconds, full recovery 46 seconds, 10 N2 BTL average 3800 PSI. Test PVT and gas alarms. Note: No failures during testing, test witness was waived by AOGCC Inspector Austin McLeod. 13:00 15:00 2.00 15.00 W.O. K 20 P Load ESP boxes and shroud in pipe shed. Make up BOP stack wash tool, and wash / rinse all BOP cavities and bore, drop down and wash tubing hanger profile. 15:00 22:30 7.50 22.50 W.O. K 20 P Clean and clear floor. Remove subs and X-O’s not required for completion. Pressure wash rig floor, ST-100 and draw works. Spot spooling unit and plug in start heating up. Stage new ESP cable and flat pack double cap tube spools. Work on MP2’s. Hang sheave in derrick. 22:30 00:00 1.50 24.00 W.O. K 20 P Mobilize tubing hanger, swivel joint and cannon clamps to rig floor. Note: Max Gas = 0 Units 24 hour loss of 8.9 ppg Brine mud =240 bbls. Total loss of 8.9 ppg Brine = 3318 bbs. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Mark Hubler ASRC Energy Services HSE mark.hubler@external.eni.com 907-685-0721 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative Johnathan Lettow Doyon Drilling HSE Rig15HSE@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/13/2022 Report #: 12 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 1.9 Wind S @ 7 MPH Days LTI (days) 1,074.00 Days RI (days) 96.00 POB 75.0 Daily Summary Operations 24h Forecast Run ESP completion. 24h Summary Continue to prepare and pick-up ESP completion assembly and run 2-7/8” Tenaris Blue tubing from 139' to 531’ MD. Operation at 07.00 Running in the hole with ESP completion at 2353' MD. 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. K 5 P PJSM - Mobilize cap tube sheave, cannon clamps and pins to rig floor. Hang sheave in derrick. Mobilize GBR large power tongs and die box to rig floor for 7-5/8” shroud. While adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. 03:30 08:00 4.50 8.00 W.O. K 5 P PJSM - Mobilize Baker equipment to the rig floor. Load ESP cable and flat pack capillary line spools in spooler. Rig up and pull ESP cable and capillary lines from spooler house, over sheaves in derrick and back to the rig floor. Adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. 08:00 13:00 5.00 13.00 W.O. K 5 P PJSM - Position 7.625” shroud in rotary table, and make up 7.625” shroud hanger, GBR torque turn connection. Service motor, and seals filling with oil, and make up same ensuring free rotation. Swap flat pack spool with single line capillary spool, and run capillary over sheaves in derrick to rig. Adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. 13:00 20:00 7.00 20.00 W.O. K 5 P PJSM - Make up MLE and perform splice to ESP cable, Note: splice witnessed by ENI electrician Rob Fontain. Make up DGU and XN nipple. Test 1/4” x 3/8” cap line splice, check valve opened @ 4221 psi and closed @ 3340 psi. bleed off to 1077 psi. to monitor while running in hole. Baker tested gauge and ESP cable check (good). Superior rep inspected connection and GBR torque turn all connections. Adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. 20:00 00:00 4.00 24.00 W.O. K 4 P PJSM – Pick-up 2-7/8” (Tenaris Hydril Blue, L-80, 6.4#) from 139’ to 531’. Superior rep inspected threads/monitor connection, GBR torque turn all connections. Adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. Note: Max Gas = 0 Units 24 hour loss of 8.9 ppg Brine mud = 240 bbls. Total loss of 8.9 ppg Brine = 3358 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Pat Ahern ASRC Energy Services HSE Patrick.Ahern@external.eni.com 907-685-0721 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Safety Representative Johnathan Lettow Doyon Drilling HSE Rig15HSE@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/14/2022 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) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -2.7 Wind S @ 21 MPH Days LTI (days) 1,075.00 Days RI (days) 97.00 POB 75.0 Daily Summary Operations 24h Forecast Run ESP completion. 24h Summary Run in hole with ESP completion assembly on 2-7/8” tubing from 531’ to 6,604’ MD. Operation at 07.00 Performing ESP cable splice. (7265' MD) 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 PJSM - Run in hole with 2-7/8” tubing (Tenaris Hydril Blue, L-80, 6.4#) ESP completion from 531’ to 3,024’, GBR torque turn all connections, witnessed by Superior thread rep. Centrilift performing electrical checks on ESP cable every 1000’ and maintaining 1000 PSI on capillary. Continue adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. DW 82K. 09:00 10:00 1.00 10.00 W.O. K 9 P PJSM - Break circulation at 2 BPM rate @ 500 psi. with 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. 10:00 18:00 8.00 18.00 W.O. K 4 P PJSM, Run in hole with 2-7/8” tubing (Tenaris Hydril Blue, L-80, 6.4#) ESP completion from 3,024’ to 5,318’, GBR torque turn all connections, witnessed by Superior thread rep. Centrilift performing electrical checks on ESP cable every 1000’ and maintaining 1000 PSI on capillary. Continue adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. DW 90K. 18:00 19:30 1.50 19.50 W.O. K 5 P PJSM – Change out capillary spool in ESP spooling unit, Test swab-lock connection (good test), and maintain 1000 psi. to monitor while running in hole. 19:30 21:30 2.00 21.50 W.O. K 4 P PJSM, Run in hole with 2-7/8” tubing (Tenaris Hydril Blue, L-80, 6.4#) ESP completion from 5,318’ to 6,025’, GBR torque turn all connections, witnessed by Superior thread rep. Centrilift performing electrical checks on ESP cable every 1000’ and maintaining 1000 PSI on capillary. Continue adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. DW 90K. 21:30 22:30 1.00 22.50 W.O. K 9 P PJSM - Break circulation at 2 BPM rate @ 500 psi. with 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. 22:30 00:00 1.50 24.00 W.O. K 4 P PJSM, Run in hole with 2-7/8” tubing (Tenaris Hydril Blue, L-80, 6.4#) ESP completion from 6,025’ to 6,604’, GBR torque turn all connections, witnessed by Superior thread rep. Centrilift performing electrical checks on ESP cable every 1000’ and maintaining 1000 PSI on capillary. Continue adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. DW 80K. Note: Max Gas = 0 Units 24 hour loss of 8.9 ppg Brine mud =260 bbls. Total loss of 8.9 ppg Brine = 3818 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Pat Ahern ASRC Energy Services HSE Patrick.Ahern@external.eni.com 907-685-0721 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Safety Representative Johnathan Lettow Doyon Drilling HSE Rig15HSE@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/15/2022 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) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) -10.1 Wind WSW @ 9 MPH Days LTI (days) 1,076.00 Days RI (days) 98.00 POB 77.0 Daily Summary Operations 24h Forecast Land completion. Nipple down BOP and nipple up tree. Perform passport test. 24h Summary Run in hole with ESP completion assembly on 2-7/8” tubing from 6,604’ to 11,754’ MD. Operation at 07.00 Prep to install tubing hanger. 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. K 4 P PJSM - Run in hole with 2-7/8” tubing (Tenaris Hydril Blue, L-80, 6.4#) ESP completion from 6,604’ to 7,263, GBR torque turn all connections, witnessed by Superior thread rep. Centrilift performing electrical checks on ESP cable every 1000’ and maintaining 1000 PSI on capillary. Continue adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. DW 80K. 02:30 06:30 4.00 6.50 W.O. K 5 P PJSM - Change out ESP cables pools in spooling unit. Perform ESP cable splice, witnessed by ENI electrician Rob Fontain. Continue adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. 06:30 07:00 0.50 7.00 W.O. K 9 P PJSM - Rig up and pump a tubing volume 42 BBL at 2 BPM 650 PSI. Rig down pumping equipment. 07:00 14:00 7.00 14.00 W.O. K 4 P PJSM - Continue to run in hole with 2-7/8” tubing (Tenaris Hydril Blue, L-80, 6.4#) ESP completion from 7,263’ to 9,378’, GBR torque turn all connections, witnessed by Superior thread rep. Centrilift performing electrical checks on ESP cable every 1000’ and maintaining 1000 PSI on capillary. Continue adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. DW 80K. NOTE: ESP cable splice on joint #247, 4,225’ 14:00 15:00 1.00 15.00 W.O. K 5 P PJSM - Change capillary spool note splice at 2,203’, (5’ above pin on joint #315). 15:00 16:30 1.50 16.50 W.O. K 4 P PJSM - Continue to run in hole with 2-7/8” tubing (Tenaris Hydril Blue, L-80, 6.4#) ESP completion from 9,378’ to 10,061’ MD, GBR torque turn all connections, witnessed by Superior thread rep. Centrilift performing electrical checks on ESP cable every 1000’ and maintaining 1000 PSI on capillary. Continue adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. DW 74K. 16:30 17:00 0.50 17.00 W.O. K 9 P PJSM - Install FOSV break circulation 2 BPM 100 PSI. 17:00 00:00 7.00 24.00 W.O. K 4 P PJSM - Continue to run in hole with 2-7/8” tubing (Tenaris Hydril Blue, L-80, 6.4#) ESP completion from 10,061’ to 11,754’, GBR torque turn all connections, witnessed by Superior thread rep. Centrilift performing electrical checks on ESP cable every 1000’ and maintaining 1000 PSI on capillary. Continue adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. DW 60K. Max Gas = 0 Units 24 hour loss of 8.9 ppg Brine mud =272 bbls. Total loss of 8.9 ppg Brine = 4090 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Pat Ahern ASRC Energy Services HSE Patrick.Ahern@external.eni.com 907-685-0721 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Safety Representative Johnathan Lettow Doyon Drilling HSE Rig15HSE@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/16/2022 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) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) -13.2 Wind SW @ 20 MPH Days LTI (days) 1,077.00 Days RI (days) 99.00 POB 74.0 Daily Summary Operations 24h Forecast Finish Nipple down BOP and nipple up tree. Perform passport test. 24h Summary Pump and spot brine with 1% lube in annulus to regain down weight, pick-up hanger assembly and install capillary line, ESP cable penetrator and land completion. De-mobe GBR and Centrilift. Remove rams from BOPE. Nipple down BOP stack. Operation at 07.00 Tree installation. 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. K 4 U PJSM - Attempt to work ESP completion down from 11,754’, without success, losing string weight and causing buckling of tubing. Decision made to add lube to active brine and spot outside of tubing. 01:30 04:30 3.00 4.50 W.O. K 1 U PJSM - Add 776 lubricant to active brine system to achieve 1% saturation, while bringing on additional brine from plant. Continue adding 10 BPH of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide. 04:30 07:30 3.00 7.50 W.O. K 9 P PJSM - Pump 400 bbls. of 8.9 PPG 3% KCL/ NaCl brine inhibited with biocide and 1% 776 lubricant, at 2.8 bpm rate, 1680 psi. stand pipe pressure, while monitoring down hole gauge to ensure we did not exceed 1500 psi. of differential across pump, per Baker Centrilift. 07:30 12:00 4.50 12.00 W.O. K 5 P PJSM - Make up fast swivel along with tubing hanger and landing joint. Install 3/8” Swagelok check valve on capillary line below tubing hanger. Run capillary through tubing hanger and test void to 5000 psi. (good test). Perform ESP splice to penetrator connector. Note: splice was witnessed by ENI electrician Rob Fontain. Install ESP cable to penetrator, pump through check, with valve opening at 4750 psi. and closing at 2560 psi. Land tubing hanger with bottom of shroud at 11,820’, UW 110K, DW 75K, run in lock down screws and test hanger seals to 5000 psi. for 15 minutes (good test). Perform electrical checks via umbilical after landing hanger (all good). 12:00 18:00 6.00 18.00 W.O. K 5 P PJSM - Demobe ESP running equipment, lower sheaves from derrick, and spool remaining ESP cable back in spooler. Remove landing joint, demobe and remove Baker Centrilift equipment from rig floor. Disconnect GBR tong hoses and lower to ground, demobe tongs and pipe handling equipment, from rig floor. Begin emptying pits and cleaning same. 18:00 20:30 2.50 20.50 W.O. C 5 P PJSM – Remove all rams from BOP stack, clean rig floor drip pan, draw-work linkage. 20:30 00:00 3.50 24.00 W.O. C 5 P PJSM – Nipple down BOP stack, Flow line and bell nipple. Choke and kill lines/valves. SIMOPS: Clean around draw-works brake linkage. Note: Max Gas = 0 Units 24 hour loss of 8.9 ppg Brine mud = 300 bbls. Total loss of 8.9 ppg Brine = 4390 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Pat Ahern ASRC Energy Services HSE Patrick.Ahern@external.eni.com 907-685-0721 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Safety Representative Johnathan Lettow Doyon Drilling HSE Rig15HSE@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Well Name: SP03-NE2 Wellbore Name: Original Hole Well Code: 32079 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/17/2022 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) 53.61 Ground Level (ft) 13.09 First Flange (ft) 16.34 RKB - Base Flange (ft) 37.27 RKB - Tubing Spool (ft) 31.77 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) -11.2 Wind W @ 2 MPH Days LTI (days) 1,078.00 Days RI (days) 100.00 POB 75.0 Daily Summary Operations 24h Forecast Well operations completed on SP03-NE3, transfer to Rig Maintenance. 24h Summary Finish nipple down BOP, nipple up tree and test void to 5000 PSI, good. Baker perform final ESP cable test and gauge reads recorded (good test). Perform passport test per vault procedure, all test good. Note: operations complete on SP03-NE3, rig released 12/17/2022 16:00. Operation at 07.00 Operation complete, no activity. 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. C 5 P PJSM – Nipple down BOPE, stage stack on stump, and clean active pits. Prep for maintenance, rig up water truck to water pumps, and mobilize metal required for water tank repair to pipe shed. 06:00 10:00 4.00 10.00 W.O. C 5 P PJSM – Remove riser from wellhead, terminate capillary line through wellhead, fill void with oil, nipple up tree, and test void to 5000 PSI for 10 minutes (good test). Continue to clean pits and prep BOP for removal from cellar. Remove BOP rams from BOP deck and stage in shop for inspection. Continue to prep for water tank repair/maintenance. 10:00 16:00 6.00 16.00 W.O. C 12 P PJSM – Perform wellhead passport testing, all test good. Remove 1502 flanges from annulus valves and install spools for freeze protection. Continue to clean pits, prep BOP for removal from cellar, and prep for upcoming maintenance. Note Rig released 12/17/2022 16:00. 16:00 00:00 8.00 24.00 W.O. K 1 P End of well transfer to Rig Maintenance. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Pat Ahern ASRC Energy Services HSE Patrick.Ahern@external.eni.com 907-685-0721 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Safety Representative Johnathan Lettow Doyon Drilling HSE Rig15HSE@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 1 Regg, James B (OGC) From:Rig 15 <rig15@doyondrilling.com> Sent:Tuesday, December 13, 2022 12:14 PM To:DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Regg, James B (OGC) Subject:D15 12-12-22 SP03-NE2 Attachments:Doyon 15 12-12-2022 .xlsx Attached is yesterdays bop test report Thank you.. Ryan Pankratz Rig 15 Toolpusher 907 685 0716 office 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.:15 DATE: 12/12/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name: PTD #2191260 Sundry #322-659 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: x Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:1391 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 13.625 5K P Pit Level Indicators P P #1 Rams 1 2-7/8" x 5"P Flow Indicator P P #2 Rams 1 Blind Shear 5K P Meth Gas Detector P P #3 Rams 1 3-1/2" x 6"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 3.125 5K P Time/Pressure Test Result HCR Valves 4 3.125 5K P System Pressure (psi)3000 P Kill Line Valves 2 3.125 5K P Pressure After Closure (psi)2250 P Check Valve 0 NA 200 psi Attained (sec)9 P BOP Misc 0 NA Full Pressure Attained (sec)46 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10 @ 3800 P No. Valves 15 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 15 P #1 Rams 10 P Coiled Tubing Only:#2 Rams 11 P Inside Reel valves 0 NA #3 Rams 10 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 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12-10-22 07:51 Waived By Test Start Date/Time:12/12/2022 8:00 (date) (time)Witness Test Finish Date/Time:12/12/2022 13:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Doyon Tested with 2 7/8" & 5" Test Joint. Tested 1 ea. 2 7/8 Pac FOSV, 1 ea. 2 7/8 Pac Dart Valves. All tests from primary remote station. Preformed draw down on Super choke and Manual choke to 2000 psi. Pankratz / Yochum ENI Petroleum Lawrence / Grub Nikaitchuq SP03-NE2L1 Test Pressure (psi): SIDDrilling@eni.com rig15@doyondrilling.com Form 10-424 (Revised 08/2022) 2022-1212_BOP_Doyon15_Nikaitchuq_SP03-NE2L1 1 Regg, James B (OGC) From:Rig 15 <rig15@doyondrilling.com> Sent:Wednesday, December 7, 2022 7:24 AM To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Subject:Doyon 15 SP03-NE2 L1 12-6-22 Attachments:Doyon 15 12-6-2022 .xlsx AttachedisBOPtestreportfor12Ͳ6Ͳ22 Thankyou.. Ryan Pankratz Rig15Toolpusher 907Ͳ685Ͳ0716office 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. 1LNDLWFKXT631(/ 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:15 DATE: 12/6/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2191260 Sundry #322-659 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:1391 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 13.625 5K P Pit Level Indicators PP #1 Rams 1 2-7/8" x 5"P Flow Indicator PP #2 Rams 1 Blind Shear 5K P Meth Gas Detector PP #3 Rams 1 3-1/2" x 6"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 3.125 5K P Time/Pressure Test Result HCR Valves 4 3.125 5K P System Pressure (psi)3000 P Kill Line Valves 2 3.125 5K P Pressure After Closure (psi)2200 P Check Valve 0NA200 psi Attained (sec)10 P BOP Misc 0NAFull Pressure Attained (sec)49 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10 @ 4100 P No. Valves 15 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 9 P Coiled Tubing Only:#2 Rams 12 P Inside Reel valves 0NA #3 Rams 9 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12-2-22 15:24 Waived By Test Start Date/Time:12/5/2022 22:00 (date) (time)Witness Test Finish Date/Time:12/6/2022 4:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Doyon Tested with 2 7/8" & 5" Test Joint. Tested 1 ea. TT 525 FOSV, 1 ea. TT 525 Dart Valve1 ea. 2 7/8 Pac FOSV, 1 ea. 2 7/8 Pac Dart Valves. All tests from primary remote station. Preformed draw down on Super choke and Manual choke to 2000 psi. Torres / Yochum ENI Petroleum Simonson / Grub Nikaitchuq SP03-NE2L1 Test Pressure (psi): SIDDrilling@eni.com rig15@doyondrilling.com Form 10-424 (Revised 08/2022) 2022-1206_BOP_Doyon15_Nikaitchuq_SP03-NE2L1 9 9 9 9 9 9999 9 9 9 -5HJJ From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Doyon 15 (12-6-2022) Date:Thursday, December 29, 2022 9:54:19 AM Attachments:2022-1206_BOP_Doyon15_Nikaitchuq_SP03-NE2L1.pdf Nikaitchuq SP03-NE2L1 (PTD 2191260) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 7\SHRI5HTXHVW $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHU (63&KDQJHRXWBB 2SHUDWRU1DPH &XUUHQW:HOO&ODVV 3HUPLWWR'ULOO1XPEHU ([SORUDWRU\ 'HYHORSPHQW $GGUHVV 6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU :HOO1DPHDQG1XPEHU :KDW5HJXODWLRQRU&RQVHUYDWLRQ2UGHUJRYHUQVZHOOVSDFLQJLQWKLVSRRO" :LOOSODQQHGSHUIRUDWLRQVUHTXLUHDVSDFLQJH[FHSWLRQ"<HV 1R 3URSHUW\'HVLJQDWLRQ /HDVH1XPEHU )LHOG &XUUHQW3RROV 1LNDLWFKXT 6FKUDGHU%OXII 6FKUDGHUEOXII 7RWDO'HSWK0' IW 7RWDO'HSWK79' IW (IIHFWLYH'HSWK0' (IIHFWLYH'HSWK79' 0363 SVL 3OXJV 0' -XQN 0' 1$ &DVLQJ &ROODSVH 6WUXFWXUDO &RQGXFWRU 1$ 6XUIDFH ,QWHUPHGLDWH 3URGXFWLRQ /LQHU 6ORWWHG 3DFNHUVDQG66697\SH 3DFNHUVDQG66690' IW DQG79' IW $WWDFKPHQWV 3URSRVDO6XPPDU\ :HOOERUHVFKHPDWLF :HOO&ODVVDIWHUSURSRVHGZRUN 'HWDLOHG2SHUDWLRQV3URJUDP %236NHWFK ([SORUDWRU\ 6WUDWLJUDSKLF 'HYHORSPHQW 6HUYLFH (VWLPDWHG'DWHIRU :HOO6WDWXVDIWHUSURSRVHGZRUN &RPPHQFLQJ2SHUDWLRQV 2,/ :,1- :'63/6XVSHQGHG 9HUEDO$SSURYDO 'DWH *$6 :$* *6725 63/8* $2*&&5HSUHVHQWDWLYH *,1-2S6KXWGRZQ $EDQGRQHG &RQWDFW1DPH 6WHIDQR3LHUIHOLFL &RQWDFW(PDLO DPMDGFKDXGKU\#HQLFRP &RQWDFW3KRQH $XWKRUL]HG7LWOH &RQGLWLRQVRIDSSURYDO 1RWLI\$2*&&VRWKDWDUHSUHVHQWDWLYHPD\ZLWQHVV 6XQGU\1XPEHU 3OXJ,QWHJULW\%237HVW 0HFKDQLFDO,QWHJULW\7HVW /RFDWLRQ&OHDUDQFH 2WKHU 3RVW,QLWLDO,QMHFWLRQ0,75HT G"<HV 1R 6SDFLQJ([FHSWLRQ5HTXLUHG"<HV 1R 6XEVHTXHQW)RUP5HTXLUHG $33529('%< $SSURYHGE\ &200,66,21(5 7+($2*&& 'DWH &RPP &RPP 6U3HW(QJ 6U3HW*HR 6U5HV(QJ 3HUIRUDWLRQ'HSWK0' IW 0' 1$ /HQJWK 6L]H 3URSRVHG3RROV 79'%XUVW 1$ 35(6(17:(//&21',7,216800$5< 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& $'/ &HQWHUSRLQW'U6WH$QFKRUDJH$. 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Chmielowski Date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±3URSRVDO6XPPDU\DQG:HOOERUH6FKHPDWLF 37' 6WDWXV :HOO631(/LVFXUUHQWO\ORVWFDSDELOLW\WRSURGXFHIOXLGVDWVXUIDFHEHFDXVHRIDQ HOHFWULFDO(63IDLOXUH 6FRSHRI:RUN 6FRSHRIWKLVZRUNRYHULVWRSXOOH[LVWLQJWKURXJKWXELQJ(63FRPSOHWLRQSHUIRUPDFOHDQ RXWUXQDQGWKHQUXQDPLGGOHFRPSOHWLRQSDFNHUZLWKYHORFLW\VWULQJEHORZLWDQGILQDOO\ UHFRPSOHWH LW ZLWK D FRQYHQWLRQDO (63 V\VWHP DIWHU WKH LQVWDOODWLRQ RI PLGGOH FRPSOHWLRQ *HQHUDO:HOO,QIR 5HVHUYRLU3UHVVXUH79' This well is expected to have a static max bottom hole pressure of approximately 1800 psi (4,088 TVD) during the time of workover 63 0$63 6KXWLQ %+3SVL 'HSWKIW 79' *UDGLHQWSVLIW 0$63 SVL 7,)/0,7,$0,72$ ,QWHUPHGLDWH FVJ ´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�� Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Supry BOPE Test Report for: NIKAITCHUQ SP03-NE21-1 .i Comm Contractor/Rig No.: Doyon 15 - PTD#: 2191260 - DATE: 727/2021 ' Inspector Matt Herrera IInsp Source Operator: Eni US Operating Company Inc. Operator Rep: Lawrence/Grubb Rig Rep: Pankratz/Yochum Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopMFH210727160016 Rams. Annular: Valves: MASP: Type Test: [NIT 321-362 250/3500 250/3500 250/3500" 1122 - Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Upper Kelly - l -- P/F Lower Kelly Visual Alarm Time/Pressure --__ 1 P/F Location Gen.: P Trip Tank P P System Pressure 3000 P Housekeeping: _P" Pit Level Indicators P _ _P _" Pressure After Closure 2150 "-- P - PTD On Location P Flow Indicator P P 200 PSI Attained 17 P Standing Order Posted P Meth Gas Detector P _ P_ Full Pressure Attained __-59 -__ _P Well Sign P H2S Gas Detector P P Blind Switch Covers: Yes P Drl. Rig -P " MS Misc NA_ - _NA Nitgn. Bottles (avg): _Iq*M00-"_ P_ - Hazard Sec. P Check Valve 0 NA ACC Misc 0 NA Mise NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly - l -- P_ - Lower Kelly 1 P Ball Type --__ 1 P'' Inside BOP 1 P FSV Mise 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 NA - No. Valves _ 15 -- _-- P- Annular Preventer 1 13 5/8" FP Manual Chokes 1 P- #1 Rams -1 _ 2 7/8'_x5_" P Hydraulic Chokes __ _l P, #2 Rams 1 Blinds P CH Misc 0 NA #3 Rams l 3 1/2" x 6" NA #4 Rams NA __-0 #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 2 - 3 1/8" P Quantity P/F HCR Valves 4 3 1/8" P Inside Reel Valves --O------NA Kill Line Valves 2 '3 1/8" P Check Valve 0 NA BOP Mise 0 NA Number of Failures: 1 ✓ Test Results Test Time 4.5 Remarks: Lower Pipe Rams not tested well profile exempt Annular failed was retested and passed All Gas Alarms and PVT system tested good —� 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: Tubing Cleanout 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 22,110 N/A Casing Collapse Structural Conductor N/A Surface 2480 Intermediate 4790 Production Liner Slotted 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:7/21/2021 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng N/A SP03-NE2 L1 4,004 1122 N/A Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 COMMISSION USE ONLY Authorized Name: Slotted Tubing Grade:Tubing MD (ft): 4,096'-4,004' N/A Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0391283, 0388571, 0388581, 0388583 219-126 3700 Centerpoint Dr, Ste.500, Anchorage, AK, 99503 50-629-23639-60-00 Eni US Operating Co. Inc Length Size Schrader BluffNikaitchuq 4,003 22,099 L-80 TVD Burst 12,534 MD 6890 N/A 5210 160' 2,487' 4,096' 160' 2,916' 20" 13-3/8" 160 9-5/8"12,962' 2,916' Perforation Depth MD (ft): 12,962' 12,784'-22,099' 5-1/2" Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 7/23/2021 22,099'9,420' 4.5" 4,004' N/A m n P s 66 t annououtoooooooooooooooooo Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 11:28 am, Jul 21, 2021 321-362 Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2021.07.21 11:20:25 -08'00' Stefano Pierfelic i X X BOP test to 3500 psig Annular preventer test to 2500 psig 10-404X DSR-7/21/21DLB 07/21/2021 VTL 7/21/21 dts 7/21/2021 JLC 7/21/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.21 14:14:35 -08'00' RBDMS HEW 7/22/2021 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.perfelici@eni.com July 21, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for SP03-NE2 L1 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP03-NE2 L1. SP03-NE2 L1 is a dual lateral producer well with ESP lift. The well was completed on Spy Island on November 1st, 2019 with a conventional ESP. The well was handovered to Production Department shortly thereafter. A rig workover was performed in April 2021 in which main bore was plugged because of excessive sand production from the main bore and well was put back on production. The well has been operated until July 15th 2021, when it lost capability to produce fluid at surface. The estimated date for beginning this work is July 23rd, 2021. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907- 865-3379. Sincerely, Stefano Pierfelici Well Operations Project Manager Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2021.07.21 11:19:57 -08'00' Stefano Pierfelic i SP03-NE2 L1 Workover – Proposal Summary and Wellbore Schematic PTD#: 219-126 Status Well SP03-NE2 L1 is currently lost capability to produce fluids at surface because of a suspected sand plug inside of production tubing. Scope of Work Scope of this workover is to run in hole with 2-7/8” work string and circulate clean sand plug (if any) inside of production tubing so ESP regain its capability to produce fluid at surface fluid General Well Info Reservoir Pressure/TVD: TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8” was tested to 1500 psi October 25, 2019 Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/VBR/Shear Rams/VBR Well type: Producer Estimated start date: July 23 rd, 2021 Drilling Rig: Doyon 15 Sr. Drilling Engineer: Amjad Chaudhry Amjad.chaudhry@eni.com Work: 907-865-3379 Well Operations Project Manager: Stefano Pierfelici Stefano.pierfelici@eni.com Work: 907-865-3320 Procedure Summary 1. MURU Doyon 15; 2. Set BPV; 3. N/D X-tree; 4. Set Blanking Plug; 5. N/U BOP and test to 250/3500 psi; 24 hour notice to AOGCC to witness; 6. Pull out of hole Blanking Plug and BPV; 7. RIH with 2-7/8” work string to the top of sand plug 8. Circulate clean tubing to the top of the ESP pump. 9. POOH and LD work string 10. Install BPV; 11. N/D BOP; 12. N/U tubing adapter and X-tree; 13. Pull BPV; 14. Install Two Way Check Valve and test X-tree; 15. Circulate Freeze protect through X-tree down IA; 16. RDMO. Below the current schematic of the well: Vetco Gray, MB-247/5000 psi 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: _ESP 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 22,110 feet N/A feet true vertical 4,003 feet N/A feet Effective Depth measured 22,099 feet N/A feet true vertical 4,004 feet N/A feet Perforation depth Measured depth 12,784'-22,099'feet True Vertical depth 4,096'-4,004'feet Tubing (size, grade, measured and true vertical depth)4-1/2"L-80 12,534' 4,023' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Eni US Operating Co. Inc Stefano Pierfelici Well Operations Project Manager Amjad Chaudhry amjad.chaudhry@eni.com 907-865-337929-Apr-21 WINJ WAG 213 Water-Bbl MD 160' 2,916' 82 Oil-Bbl measured true vertical Packer 3700 Centerpoint Dr, Ste.500, Anchorage, AK, 99503 3. Address: 4. Well Class Before Work: 389 Representative Daily Average Production or Injection Data 17041 Casing Pressure Tubing Pressure ADL 0391283, 0388571, 0388581, 0388583 157 120 SP03-NE2-L1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 219-126 50-629-23639-60-00 N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 317 Gas-Mcf measuredPlugs Junk measured 5. Permit to Drill Number: 85 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-116 155 Size Nikaitchuq/Schrader Bluff Oil Pool Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: Liner Length 160 2,916' 12,962' 9,420' Casing Structural 20" 13-3/8" 9-5/8" 5-1/2" 12,962' 22,099' TVD 160' 2,487' 4,096' 4,004'Slotted Burst N/A 5,210 6,890 2. Operator Name Senior Engineer:Senior Res. Engineer: Slotted Collapse N/A 2,480 4,790 t Fra O 219 6. A G L PG , R ut Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 7:14 am, Apr 30, 2021 Digitally signed by: Stefano Pierfelici DN: CN = Stefano Pierfelici C = AD Date: 2021.04.29 10:31:58 -08'00' Stefano Pierfelic i SFD 5/3/2021RBMDS HEW 4/30/2021 VTL 5/5/21 DSR-4/30/21 4-½” 12.6 ppf Production Tubing–Internal CoatedHAL 5-½” Oil Swell Packer–13,325'SP03-NE2Dual Lateral Producerwith ESP LiftNikaitchuq Field–Spy IslandAs Completed04/08/202112,679’MD, 4,084' TVD–L1 - Baker SLXP LinerHanger/PackerCasing Exit Window12,767-12,784' MD4-½” x-cplg cable clamps, for ESP PowerCable, (1) 3/8" Chem Inj Line with 2500psi check valve at bottom12,533.93' MD, 4,023’ TVD -DGU12,566’ MD, +/- 4,024' TVD, 87.0º Inc–Bottom of Motor Centralizer Centrilift, ESP,66 Stage FLEX 47 SXD, 20 stage GINPSHH SXD, 538, 250 HP 562 XP Motor12,606' MD 32# Shroud Assembly with cable and chemicalinjection line feed-thrus, 3.5" perforated gas dispersion tubeSurf. Casing13-3/8", 68 #2,916' MD,2,487' TVD61º Inc.Interm. Casing9-5/8", 40#12,962' MD, 4,096' TVD87º Inc.12,812' MD, 4,091' TVDBaker MLXP LinerHanger/PackerTD 8 3/4” 22,082' MD,4,024' TVD 92º Inc.5-½” 15.5 ppf L80 Slotted /Blank LinerSilver Bullet Ecc. Nose Guide ClosedShoe (w/ Blank Joint)13,553' MD, 4,110' MDSilver Bullet Ecc. Nose GuideClosed Shoe (w/ Blank Joint)22,099' MD, 4,004' TVD, 91º Inc.TD 8 3/4” 22,110' MD,4,003' TVD91º Inc.5-½” 15.5 ppf L80Slotted / Blank LinerSealbore Receptacle4.75" IDRAM Hanger:3.63" ID Drift Mainbore3.65“ ID Lateral4-½” x 9-5/8" RAMSeal Bore Diverterw/ 3.68" Seal BoreDrift 3.65"Bottom of SealAssembly4½” Lateral Entry Module (LEM)w/ 3.68 Seal Bore, drift 3.63"Resman oil+waterTracerResman oil+watertracersResman oil+watertracerDepth (ft MD)Main bore Lateral L1#1 13,100 13,100#2 14,210#3 15,320#4 18,300#5 19,800#6 20,9501 x Tracer above LEMResman Tracers PlacementTwo IBP has been placed belowthe SBD to isolate Main bore#1: @12,808'#2:@ 12,789' :HOO1DPH 631( :HOOERUH1DPH 2ULJLQDO+ROH :HOO&RGH -RE :25.29(5 :&(, /(9(/ 6HOHFWHGWDEOH KDVQRYDOLG DWWDFKPHQWV WKDWFDQEH GLVSOD\HG 'DLO\5HSRUW 'DWH 5HSRUW 3DJH RI :HOO+HDGHU 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH '(9(/230(17:(// 5RWDU\7DEOH(OHYDWLRQ IW *URXQG/HYHO IW )LUVW)ODQJH IW 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*RRGFDWFK 0,6ZDFR 2EVHUYDWLRQ 0,6ZDFR 6WRSZRUN :RUOH\ +D]DUG,' :RUOH\ 2EVHUYDWLRQ *HQHUDO1RWHV &RPPHQW 03/08/2021 By Samantha Carlisle at 11:00 am, Mar 08, 2021 321-116 DSR-3/8/21 SFD 3/8/2021 X SFD 3/8/2021BJM 3/9/21 12,784 BOP Test to 3500 psi, Annular test to 2500 psi. 4,096 10-404 3/10/21 dts 3/9/2021 JLC 3/9/2021 RBDMS HEW 3/11/2021 2 plugs, +/-12,786' and 12,808 md. Planned fluid is 9.4 ppg KCl/NaCl brine 1 Carlisle, Samantha J (CED) From:Chaudhry Amjad <Amjad.Chaudhry@eni.com> Sent:Tuesday, March 9, 2021 1:35 PM To:McLellan, Bryan J (CED) Subject:RE: SP03-NE2 (PTD 219-126) Attachments:SP03-NE2 Multilateral_proposed03-09-2021.pdf HelloBryan, Pleaseseeattachedschematicandproposedplacingdepthoftheplugs,wearestillsourcingoptionsthekindof mechanicalwewilluseandfinaldecisionhasnotbeenmadeyet,couldbeEvoorinflatableplugs,settingdepthwillbe 1Ͳ@+/Ͳ12,786’belowtheNOGOnipple 2Ͳ@+/Ͳ12,808’justbelowtheSBD Fluiddensitywillbe+/Ͳ9.4ppgKCL/NaClbrine Bestregards Amjad From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Tuesday,March9,202111:36AM To:ChaudhryAmjad<Amjad.Chaudhry@eni.com> Cc:Loepp,VictoriaT(CED)<victoria.loepp@alaska.gov> Subject:SP03ͲNE2(PTD219Ͳ126) HiAmjad, IamworkingwithVictoriaonyourSundryApplicationsfortheworkoveronSP03ͲNE2.Thanksforsendingthesecond SundryfortheL1lateral.Wehavejustafewmorequestions: 1. Whatkindofplugdoyouproposesettinginthemainbore?Pleasesendadiagramthatshowstheproposed plugdepthandtype. 2. Whatisthedensityofthefluidyouplantousefortheworkoveroperation? Thankyou. BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 ---------------------------------------------------------------------------------------------------------------------------------------------------- -------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ 4-½” 12.6 ppf Production Tubing–Internal CoatingHAL 5-½” Oil Swell Packer–13,325'SP03-NE2Dual Lateral Producerwith ESP LiftNikaitchuq Field–Spy IslandAs Completed01-Nov-201912,679’MD, 4,084' TVD–L1 - Baker SLXP LinerHanger/PackerCasing Exit Window12,767-12,784' MD4-½” x-cplg cable clamps, for ESP PowerCable, (1) 3/8" Chem Inj Line with 2500psi check valve at bottom12,536' MD, 4,076’ TVD - Discharge Head12,607’ MD,4,080'TVD,87.0ºInc–Bottom of Motor Centralizer Centrilift, ESP, 66Stage FLEX 47 SXD, 20 stage GINPSHH SXD, 538, 250 HP 562 XP Motor12,620' MD 32# Shroud Assembly with cable and chemicalinjection line feed-thrus, 3.5" perforated gas dispersion tubeSurf. Casing13-3/8", 68 #2,916' MD,2,487' TVD61º Inc.Interm. Casing9-5/8", 40#12,962' MD, 4,096' TVD87º Inc.12,812' MD, 4,091' TVDBaker MLXP LinerHanger/PackerTD 8 3/4” 22,082' MD,4,024' TVD 92º Inc.5-½” 15.5 ppf L80 Slotted /Blank LinerSilver Bullet Ecc. Nose Guide ClosedShoe (w/ Blank Joint)13,553' MD, 4,110' MDSilver Bullet Ecc. Nose GuideClosed Shoe (w/ Blank Joint)22,099' MD, 4,004' TVD, 91º Inc.TD 8 3/4” 22,110' MD,4,003' TVD91º Inc.5-½” 15.5 ppf L80Slotted / Blank LinerSealbore Receptacle4.75" IDRAM Hanger:3.63" ID Drift Mainbore3.65“ ID Lateral4-½” x 9-5/8" RAMSeal Bore Diverterw/ 3.68" Seal BoreDrift 3.65"Bottom of SealAssembly4½” Lateral Entry Module (LEM)w/ 3.68 Seal Bore, drift 3.63"Resman oil+waterTracerResman oil+watertracersResman oil+watertracerDepth (ft MD)Main boreLateral L1#1 13,100 13,100#2 14,210#3 15,320#4 18,300#5 19,800#6 20,9501 x Tracer above LEMResman Tracers PlacementTubing wall plugs to isolate Mainbore will be placed in pup jointjust below SBD @ +/- 12,808'and one below the NoGo Nipple@ +/- 12,786' DATA SUBMITTAL COMPLIANCE REPORT 3/25/2020 Permit to Drill 2191260 Well Name/No. NIKAITCHUQ SP03-NE2L1 MD 22110 TVD 4003 REQUIRED INFORMATION Completion Date 11/1/21019 Mud Log NT DATA INFORMATION List of Logs Obtained: GR/RES/DEN/NEU/CALIPER Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 31584 Digital Data ED C 31584 Digital Data ED C 31584 Digital Data ED C 31584 Digital Data ED C 31584 Digital Data ED C 31584 Digital Data ED C 31584 Digital Data ED C 31584 Digital Data ED C 31584 Digital Data ED C 31584 Digital Data ED C 31584 Digital Data AOGCC Operator Eni US Operating Company Inc. API No. 50-629-23639-60-00 Completion Status 1-011- Samples -OIL Samples No`/ Current Status 1-0I1- UIC No Log Log Run Interval OH/ Scale Media No Start Stop CH Received 42 22110 12/5/2019 12/5/2019 12/5/2019 12/5/2019 12/5/2019 12/5/2019 12/5/2019 12/5/2019 12/5/2019 12/5/2019 12/5/2019 Pagel of 4 Directional Survey Yes (from Master Well Data/Logs) Comments Electronic Data Set, Filename: SP03- NE21-1_Scope Service_RM_LAS_42-22110.las Electronic File: SP03-NE2L1_Scope Service RM DLIS.dlis Electronic File: SP03-NE2L1_Scope Service RM DLIS.html Electronic File: SP03- NE2L1_Caliper _Service_5in_RM_MD_12730- 22110.PDF Electronic File: SP03- NE2L1_Scope_lmage_Service_5in_RM_MD_123 75-22110.PDF Electronic File: SP03- N E2L1 _Scope_ Service_2in_RM_MD_42- 22110.PDF Electronic File: SP03- N E2L 1 _Scope_ Service_2in_RM_TVD_42- 22110.PDF Electronic File: SP03- NE2L 1 _Scope_Service_5in_RM_MD_42- 22110.PDF Electronic File: SP03- N E2L 1 _Scope_Service_5in_RM_TVD_42- 22110.PDF Electronic File: ENI_SP03-NE2 L1 Final Surveys.pdf Electronic File: ENI_SP03-NE2 L1 Final Surveys.xlsx Wednesday, March 25, 2020 DATA SUBMITTAL COMPLIANCE REPORT 3/25/2020 Permit to Drill 2191260 Well Name/No. NIKAITCHUQ SP03-NE2L1 MD 22110 TVD 4003 Completion Date 11/1/2019 Log 31584 Log Header Scans ED C 31982 Digital Data ED C 31982 Digital Data ED C 31982 Digital Data ED C 31982 Digital Data ED C 31982 Digital Data ED C 31982 Digital Data ED C 31982 Digital Data ED C 31982 Digital Data ED C 31982 Digital Data ED C 31982 Digital Data ED C 31982 Digital Data Log 31982 Log Header Scans ED C 31982 Digital Data ED C 31982 Digital Data ED C 31982 Digital Data ED C 31982 Digital Data ED C 31982 Digital Data ED C 31982 Digital Data Operator Eni US Operating Company Inc. API No. 50-629-23639-60-00 Completion Status 1 -OIL Current Status 1 -OIL UIC No 0 0 2191260 NIKAITCHUQ SP03-NE21_1 LOG HEADERS 12767 22110 1/28/2020 Electronic Data Set, Filename: SP03-NE2L1.las 1/28/2020 Electronic File: SP03-NE21_1 EOWR.doc 1/28/2020 Electronic File: SP03-NE21_1 21VID DEL FINAL2.pdf 1/28/2020 Electronic File: SP03-NE21_1 21VID DEL f`C FINAL2.pdf.emf 1/28/2020 Electronic File: SP03-NE21_1 21VID DEL V FINAL2.pdf.emf.tif ►t�l� 1/28/2020 Electronic File: SP03-NE21_1 21VID FEL FINAL2.pdf 1/28/2020 Electronic File: SP03-NE21_1 2MD FEL FINAL2.pdf.emf 1/28/2020 Electronic File: SP03-NE21_1 21VID FEL FINAL2.pdf.emf.tif 1/28/2020 Electronic File: SP03-NE21_1 21VID GRL FINAL2.pdf 1/28/2020 Electronic File: SP03-NE21_1 21VID GRL FINAL2.pdf.emf 1/28/2020 Electronic File: SP03-NE21_1 21VID GRL FINAL2.pdf.emf.tif 0 0 2191260 NIKAITCHUQ SP03-NE21_1 LOG HEADERS 12750 22110 3/23/2020 Electronic Data Set, Filename: SP03-NE21_1 3/23/2020 FINAL.Ias Electronic File: SP03-NE21_1 EOWR.doc Y E C 3/23/2020 Electronic File: SP03-NE21_1 21VID DEL FINAL2.emf 3/23/2020 Electronic File: SP03-NE21_1 21VID DEL FINAL2.pdf 3/23/2020 Electronic File: SP03-NE21_1 21VID DEL FINAL2.tif 3/23/2020 Electronic File: SP03-NE21_1 21VID FEL FINAL2.emf AOGCC Page 2 of 4 Wednesday, March 25, 2020 DATA SUBMITTAL COMPLIANCE REPORT 3/25/2020 Permit to Drill 2191260 Well Name/No. NIKAITCHUO SP03-NE2L1 Operator Eni US Operating Company Inc. API No. 50-629-23639-60-00 MD 22110 TVD 4003 Completion Date 11/1/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 31982 Digital Data 3/23/2020 Electronic File: SP03-NE21-1 2MD FEL FINAL2.pdf ED C 31982 Digital Data 3/23/2020 Electronic File: SP03-NE21-1 2MD FEL FINAL2.tif ED C 31982 Digital Data 3/23/2020 Electronic File: SP03-NE21-1 2MD GIRL FINAL2.emf ED C 31982 Digital Data 3/23/2020 Electronic File: SP03-NE21-1 2MD GRL FINAL2.pdf ED C 31982 Digital Data 3/23/2020 Electronic File: SP03-NE21-1 2MD GRIL FINAL2.tif Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report Production Test Informatiolv/ NA Geologic Markers/Tops c COMPLIANCE HISTORY Completion Date: 11/1/2019 Release Date: 9/17/2019 Description Comments: Interval Start Stop Directional / Inclination Data /Y Mechanical Integrity Test Information Y / NA Daily Operations Summary 1 Y Date Comments Sample Set Sent Received Number Comments Mud Logs, Image Files, Digital Data,,Y % NA Core Chips Y /,,NA Composite Logs, Image, Data Files; Y Core Photographs Y / NA Cuttings Samples Y / �A Laboratory Analyses Y SNA AOGCC Page 3 of 4 Wednesday, March 25, 2020 DATA SUBMITTAL COMPLIANCE REPORT 3/25/2020 Permit to Drill 2191260 Well Name/No. NIKAITCHUQ SP03-NE21-1 MD 22110 TVD 4003 Completion Date. 11/1/2019 Compliance Reviewed By: Operator Eni US Operating Company Inc. API No. 50-629-23639-60-00 Completion Status 1-0I1- Current Status 1-0I1-UIC No '., _0 7 Date: - AOGCC Page 4 of 4 Wednesday, March 25, 2020 126 31982 To: Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 SDL Digital Data and Logs — SP03-NE2 Ll Revision AK -XX -0905859517 March 3, 2020 SQL Logs — SP03-NE2 L1 (60-629-23639-60-00) L Nurn Please note 'his, is to revise the original data that had Vic incorrect API ber 2" MD Formation Evaluation Log 1 Digital Log 2" MD Drilling Evaluation Log 1 Digital Log 2" MD Gas Ratio Log I Digital Log Digital Data: CD ROM disk End of the Well Report 1 Disks Digital data LAS v2.0 and DLIS w/verification file Digital graphic logs in EMF, PDF, and TIFF formats PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Daniel Sherwood/Ben Schulze 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-362-3498/907-273-3536 RECEIVED Daniel. sherwood@halliburton.com MAR 2- '2020 Beniamin.Schutze(&halliburton.com AOGC r Date: Z/2,X J Signed:— 2 191 26 HALLI B J RTON j Spix*,ry Drilling 31962 WELL LOG/DATA TRANSMITTAL To: Alaska Oil and Gas Conservation Commission January 27, 2020 333 W. 7"' Ave, Anchorage, AK 99501 SDL Digital Data and Logs - SP 69 NE ' " AK -XX -0905859517 SDL Lo-gs SP 0-629-23639-60-00) 2" MD Formation Evaluation Log 1 Digital Log 2" MD Drilling Evaluation Log 1 Digital Log 2" MD Gas Ratio Log 2" TVD Formation Evaluation Log 1 Digital Log 1 Digital Log Digital Data: CD ROM disk End of the Well Report 1 Disks Digital data LAS v2.0 and DLIS w/verification file Digital graphic logs in EMF, PDF, and TIFF formats PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Daniel Sherwood/Ben Schulze 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-362-3498/907-273-3536 Danielssherwood@halliburton.com Benjamin.Schulze(dhalliburton.com Date: 106 Signed: c�4 0, f)A IV 2 A JAN 2 8 2020 AOGCC Schlumberger Drilling & Measurements Product Delivery Customer: ENI US Operating Co. Inc. Dispatched To.- Well o:Well Name: SP03-NE2 L1 Date Dispatched AP I N#: 50-629-23639-60-00 219126 31584 Transmittal #: 03DEC19-SP02 Logging Date: 17 -Oct -19 AOGCC: Meredith Guhl 3 -Dec -19 Dispatched By: Stephanie Pacillo Product Description Hardcopy Di ital Copy Logging Date LWD Logs LWD EOW N/A Contents on CD 17 -Oct -19 Scope* Service 5" MD Caliper 12730-22110 ft x 5" MD SCOPE Image 12375-22110 ft x 2" MD 42-22110 ft x 2" TVD 42-22110 ft x 5" MD 42-22110 ft x 5" TVD 42-22110 ft x Digital Data N/A Contents on CD RM Data DLIS / LAS Data x Survey 1 Survey Rpt Contents on CD Directional Survey Nad27 x x EOW CD N/A Contents on CD Data: DLIS / LAS x Graphics: PDF x Survey Data: xls / PDF x Please sign and email a copy to: Please sign and email a copy to: Amjad.Chaudhry(a)-eni.com AlaskaPTSPrintCenter(o)slb.com Attn: Amjad Chaudhry Attn: Stephanie Pacillo I Received By: kAA &Ula STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑✓ • Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended[] 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. Well Class: Development Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ENI US Operating Co. Inc. 6. Date Comp., Susp., or Aband.: 11/1/2019 14. Permit to Drill Number/ Sundry: 219-126 ' 3. Address: 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 99503 7. Date Spudded: 10/9/2019 15. API Number: 50-629-23639-60-00 4a. Location of Well (Governmental Section): Surface: 4486 FSL 1186 FEL S19 T14N R9E UM • Top of Productive Interval: 4438, FSL,4042 FEL 7 T14N R9E UM Total Depth: 255 FSL 344 FEL 35 T15N R8E UM 8. Date TD Reached: 10/14/2019 16. Well Name and Number: SP03-NE2 L1 9. Ref Elevations: KB: 54.1 GL: 13.1 • BF: 17. Field / Pool(s): Nikaitchuq/Schrader Bluff r 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: , ADL 0391283, 0388571, 0388581, 0388583 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 511723 y- 6053668 • Zone- 4 TPI: x- 508812.4 y- 6064174.47 Zone- 4 Total Depth: x- 502186.76 y- 6070545.79 Zone- 4 11. Total Depth MD/TVD: • 2211074003' ' 19. DNR Approval Number: ADL 417493 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1,864' MD/ 1,766' TVD 5. Directional or Inclination Survey: Yes l (attached) No H Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 12,767' MD/4,086' 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/RES/DEN/NEU/CALIPER 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20 178.89 X-65 37.04 160 37.04 160 Driven N/A N/A 13.375 68 L-80 36.8 2,624 36.8 2,916 16 11 ppg CRETE :505 bbls 12.5 ppg DeepCRETE: 74 bbls N/A 9.625 40 L-80 35 12,962 35 4,096 12.25 12.5 ppg DeepCrete Lead: 243 bbls 15.8 ppg DeepCrete Tail: 56 bbls 5.5 15.5 L-80 12,679 22,099 4,084 4,003 8.75 slotted 24. Open to production or injection? Yes Q . No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 12,784'-22,099' MD/4,096'-4,004' TVD (slotted Liner in open hole) 10/25/2019 COMPLETION -4jDAT V yzgo -- 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4.5 12,536 N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes Li No E Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 12/5/2019 Method of Operation (Flowing, gas lift, etc.): Flowing Date of Test: 1/5/2020 Hours Tested: 4 hr 16 minutes Production for Test Period Oil -Bbl: 94 Gas -MCF: 38.221 Water -Bbl: 9 Choke Size: 128 Gas -Oil Ratio: 407 Flow Tubing Press. Casinq Press: 339 Calculated 24 -Hour Rate Oil -Bbl: 528.75 Gas -MCF: 214.99 Water -Bbl: 50.6 Oil Gravity - API (corr): 20 Form 10-407 Revised 5/2017 t ri jW I ' CONTINUED ON PAGE 2 M4-P-t4FKB2c RMS JAN 2 9 2020 Submit ORIGINIAL my -L-J z zzx, G -O" 28. CORE DATA Conventional Core(s): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No ❑✓ If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surf Surf Permafrost - Base 1864 1766 Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. Top of Productive Interval: Top OA sand 12,986 4099 Formation at total depth: OA Sand 22110 4000 31. List of Attachments: Directional Survey, As Run Wellbore Schematic, Well Operations Summary Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Stefano Pierfelici Contact Name: Amjad Chaudhry Authorized Title: Well Operations Project Manager Contact Email: ambd.chaudhry(a_eni.com Authorized Contact Phone: 907-865-3379 �__A Signature: _Q l Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange 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 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed ,test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test res Its. Form 10-407 Revised 5/2017 J;111 IU -20 /s,Submit ORIGINAL Only U 4 k.;%.w Y�_ to I ion:. '':STATE OF ALASKA JAN 17 2020 L AND GAS CONSERVATION COMMISSION WE ` L COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil 0 Gas SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 1 b. Well Class: Development Q Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ENI US Operating Co. Inc. 6. Date Comp., Susp., or Aband.: 11/1/2019 14. Permit to Drill Number / Sundry: 219-126 3. Address: 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 99503 7. Date Spudded: 10/9/2019 15. API Number: 50-629-23639-60-00 4a. Location of Well (Governmental Section): Surface: 4486 FSL 1186 FEL S19 T14N R9E UM Top of Productive Interval: 4438, FSL,4042 FEL 7 T14N R9E UM Total Depth: 252 FSL 342 FEL 35 T1 5N R8E UM 8. Date TD Reached: 9/27/2019 16. Well Name and Number: SP03-NE2 L1 9. Ref Elevations: KB: 54.1 GL: 13.1 BF: 17. Field / Pool(s): Nikaitchuq/Schrader Bluff 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 0391283, 0388571, 0388581, 0388583 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 511723 y- 6053668 Zone- 4 TPI: x- 508812.4 y- 6064174.47 Zone- 4 Total Depth: x- 502279.5 y- 6070603.81 Zone- 4 11. Total Depth MD/TVD: 22110'/4003' 19. DNR Approval Number: ADL 417493 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1,864' MD/ 1,766' TVD 5. Directional or Inclination Survey: Yes l (attached) No L Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 12,767' MD/4,086' 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/RES/DEN/N EU/CALI PER 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20 178.89 X-65 37.04 160 37.04 160 Driven N/A N/A 13.375 68 L-80 36.8 2,624 36.8 2,916 16 11 ppg CRETE :505 bbls 12.5 ppg DeepCRETE: 74 bbls N/A 9.625 40 L-80 35 12,962 35 4,096 12.25 12.5 ppg DeepCrete Lead: 243 bbls 15.8 ppg DeepCrete Tail: 56 bbls 5.5 15.5 L-80 12,679 22,099 4,084 4,003 8.75 slotted 24. Open to production or injection? Yes Q No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 12,784'-22,099' MD/4,096'-4,004' TVD (slotted Liner in open hole) 10/25/2019 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4.5 12,536 N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: 1/5/2020 Hours Tested: 4:16 Production for Test Period Oil -Bbl: 94 as-MCF: 8.221 [214.99 Water -Bbl: 9 Choke Size: 128 Gas -Oil Ratio: 407 Flow Tubing Press. Casinq Press: 339 Calculated 24 -Hour Rate Oil -Bbl: 528.75 as -MCF: Water -Bbl: 50.6 Oil Gravitv - API (corr): No Data re or, x Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINIAL only 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No ❑✓ If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Suri Surf Permafrost - Base 1864 1766 Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. Top of Productive Interval: Top OA sand 12,986 4099 Formation at total depth: OA Sand 22110 4000 31. List of Attachments: Directional Survey, As Run Wellbore Schematic, Well Operations Summary Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Stefano Pierfelici Contact Name: Amjad Chaudhry Authorized Title: Well Operations Project Manager Contact Email: amlad.chaudhryt_enl.com Authorized'� t ` /� Contact Phone: 907-865-3379 Signature: `--�_ Date: 1 t INS RUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange 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 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Surf. Casing 13-3/8", 68 # 2,916' MD, 2,487' TVD 61° Inc. � 12,679' MD, 4,084' TVD – L1 - Baker SLXP Liner Hanger/Packer RAM Hanger: \ 3.63" ID Drift Mainbore 3.65 " ID Lateral 4-'/2" x 9-5/8" RAM Seal Bore Diverter w/ 3.68" Seal Bore Drift 3.65" Resman Tracers Placement Depth (ft MD) Main bore Lateral Ll 1 x Tracer above LEM #1 13,100 13,100 #2 14,210 #3 15,320 #4 18,300 #5 19,800 #6 20, 950 Nikaitchuq Field —Spy Island 4-'/2" 12.6 ppf Production Tubing – Internal Coating 4-'/2' x-cplg cable clamps, for ESP Power Cable, (1) 3/8" Chem Inj Line with 2500 psi check valve at bottom 12,536' MD, 4,076' TVD - Discharge Head Cerni n petro® eum SP03-NE2 Dual Lateral Producer with ESP Lift As Completed 01 -Nov -2019 12,607' MD, 4,080' TVD, 87.0° Inc – Bottom of Motor Centralizer Centrilift, ESP, 66 Stage FLEX 47 SXD, 20 stage GINPSHH SXD, 538, 250 HP 562 XP Motor 12,620' MD 32# Shroud Assembly with cable and chemical injection line feed-thrus, 3.5" perforated gas dispersion tube Resman oil+water tracer 4 %" Lateral Entry Module (LEM) �— w/ 3.68 Seal Bore, drift 3.63" 12,812' MD, 4,091'-r Baker MLXP Liner Hanger/Packer' Bottom of Seal Assembly Casing Exit Window Resman oil+water 12,767-12,784' MD tracers Silver Bullet Ecc. Nose Guide Closed Shoe (w/ Blank Joint) 22,099' MD, 4,004' TVD, 911 Inc. 5-'/2' 15.5 ppf L80 Slotted / Blank Liner Resman oil+water Sealbore Receptacle Tracer 4.75" ID Packer HAL Oil Swell – 13,325' TD 8 3/4" 22,110' MD, 4,003' TVD \ 91° Inc. TD 8 3/4" 22,082' MD, 4,024' TVD 921 Inc. Interm. Casing ' , 9-5/8", 40# 5-/2" 15.5 ppf L80 Slotted / Silver Bullet Ecc. Nose Guide Closed 12,962' MD, 4,096' TVD Blank Liner Shoe (w/ Blank Joint) 87° Inc. 13,553' MD, 4,110' MD Selected table Well Name: SP03-NE2 L1 CIR(A) has Daily Report no valid Wellbore Name: SP03-NE2 L1 Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB - ease Flange (ft) RKB -Tubing Spool (ft) attachments that can be Well Code: 32145 Date: 10/9/2019 displayed Job: DRILLING Report #: 1 WCEI Level: 3 Page: 1 of 3 Well Header PermidConcession N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB - ease Flange (ft) RKB -Tubing Spool (ft) 53.60 1310 16.34 37.26 31.76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 9/27/2019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB MD @ Report Time (ft... TVD @ Report Time (it 13,250.0 430.00 7.00 430.0 773.0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Overcast 35.6 NW @ 9 MPH 712.00 712.00 0.00 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause I Lost time? Comment Safety Drills Days Until Next Check I Type #Occur, Last Date Next Date (days) BOP Pressure Test 1 10/9/2019 10123/2019 14 Rig Inspection 1 10/9/2019 10!70/2019 1 Safety Meeting 1 10/912019 10/1012019 1 TT H2S Drill 1 10/9/2019 10/10/2019 1 Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (ft/hr) DRILLING 22,100.0 430.00 100 430.0 Daily Summary Operations 24h Forecast Run in the hole with BHA #17 to -12,580' and wash to 12,820'. Drill Li horizontal 8 3/4" hole per directional/geological plan from 12,820' to 22,103' proposed TD 24h Summary Make-up BHA #17 to 460' per Schlumberger DD/MWD rep. Continue tripping hole from 460' to 11,255', test MWD @ 1,860' and send down link (good test). Fill pipe every 20 stands Operation at 07.00 Drilling Ahead @ 12,985' Lithology ShowsMud Weight (lbigal) 9.40 Time Log Start End Cum Dur End Depth Time Time Dur (hr) (hr) Phase Oar. Act. Plan Oper. Descr. (ftKB) 13:00 1500 2.00 2.00 DRILL E 5 P Pick up and make up BHA #17, 8 %" directional drilling assembly per Schlumberger DD/MWD reps to 460' 12,820.0 15,00 16-00 1 00 3.00 DRILL E 4 P Trip in hole with BHA #17 from 460' to 1,861' on 4 15." 425 Delta drill pipe Fill every 20 stands UW= 97K / 12,820.0 DW= 97K 1600 17-00 1 00 400 DRILL E 9 P Shallow test MWD with 350 GPM at 650 PSI and perform down link with 400 GPM at 780 PSI to ensure proper 12,820.0 tool communication - (good test) 17:00 00-00 700 11.00 DRILL E 4 P Continue tripping on 4 %" 425 Delta drillipe from 1,860'to 11,255' fillip p g pipe every 20 stands Monitoring 12,820.0 displacement via trip tank. UW= 150K / DW= LOOK. Note. Losses to hole last 11 him = 1 BBL, Max gas last 24 him 1 units and average gas 0 units. / 0 his Rotating /0 K -rev's Gas Readings Avg Background Gas I%) Max Background Gas (%) Avg Connection Gas (%) Maz Connection Gas I%) 0.00 2.00 0.00 0.00 Avg Drill Gas I%) Max Drill Gas M Avg Trip Gas I%) Max Trip Gas (% ) 000 0 00 0 00 0.00 Mud Type: LVT - FazePro - 72% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf110... Vis (s/qt) 12,820.0 9.40 46 31 22 16 7 6 15.0 16.007 52 Get (10s) (Ibf/1... Gel (10m) (Ibf/1... Gel (30m) (Ibfl1 ... n K Filtrate (mU30... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 7,003 7.003 0.28 19.417 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (m1JmL) Pf (rrL/mL) Mf (mL/mL) Sand I%) Solids (%) H2O I%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) Titrated 3.000 0.1 13.0 24.5 62.5 71.8/28.2 Brine (Ibfgal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime ib/bbl) 10.60 7.7 2.8 61,500.000 0.000 669.0 3.9 Mud Type: LVT - FazePro - 72% Oil Ratio Depth (ftKB) Density (Ib/gap Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 12,820.0 9.40 47 31 24 17 7 6 16.0 15.006 55 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1... Gel (30m) (Ibf/1 ... n K Filtrate (ml -130... FC (1132") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 T. 7.003 0.297 18.876 0.0 0 4.3 1 150.0 500.0 PH pH Method Pm (mL/mL) Pf (m L/mL) Mf (mL/mL) Sand I%) Solids I%) H2O (%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) Titrated 3.100 0.1 13.1 24.4 62.5 719/28.1 Brine (Ib/gal) LGS I%) HGS (%) Barite (Iblbbp Chlorides (mg/L) Calcium (mglL) Mg (mg/L) Pot mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 8.0 2.6 61,500.000 0.000 681.0 4.0 Daily Mud Volumes Tank7Addition/Loss Type Des Volume (bbl) Hole 902.6 Loss 1.0 Tank 442.8 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl)Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 1,345.4 902.6 0.0 0.0 1.0 1.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Simone Belemmi Ent Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Steve Lawrence Eni Drilling Supv. siddrilling@eni.com 685-0715 Eni representative David Smith Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Wade Thomas Eni Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Eni representative Pat Ahem Eni HSE Eni representative Mark Hubler Eni HSE Drilling Supt. Sam Dye Doyon Drilling Field Superintendent Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig 15@doyondrilling.com Selected table Well Name: SP03-NE2 L1 DR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/9/2019 Report #: 1 Page: 2 of 3 Daily Contacts Position Contact Name Company Title Email Office Mobile Tool Push Einer Fleagle Doyon Drilling Tool Push Tool Push Cliff Owens Doyon Drilling HSE cowens@doyondrilling.com 685-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyondrIling.com 685-0796 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note GBR Casing 12.50 0 Drilling Baker Liner Hanger 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 1250 1 SID Support Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Ent Company Man 12.50 1 Drilling Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) Wal[Head 12.50 1 Drilling K&M ERD 12.50 1 Drilling Rubicon Swivel 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12,50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling RPS Geologist 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB Directional Driller 12.50 2 Drilling SLB MWD 12.50 2 Drilling Competentia Logistic 12.50 4 SID Support MI Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 10 SID Support Worley Truck driver/Crane operator 12.50 21 Drilling Doyon Rig Personnel 12.50 26 Drilling_Totat Drilling Personnel BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 8/7/2019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) ILast Cert Date Annular Hydril GK 50013 5/8 5,000.0 5/12015 3 1/2 "- 6" VBR Hydni MPL 5000 13 5/8 5,000.0 81242018 Blind Shear Ram Hydril MPL 5000 13 5/8 5.000.0 8124/2018 4 112" x 7" VBR Hydril MPL 5000 13 5/8 5,000.0 5!12015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 827/2019 6 0.113 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/9/2019Yes 30 450.0 10!9/2019 Yes 22 300.0 Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 8/27/2019 6 0.113 5,323.0 I Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/9/2019 Yes 30 420.0 10!9/2019 Yes 22 280.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 8/27/2019 6 0.102 4,665.0 Date Depth (ftKB) Slow SpdStrokes (spm) P (psi) I Eff (%) T- O Flow (gpm) 10/9/2019 Yes 39 450.0 10/9/2019 Yes 29 300.0 Last BHA BHA # Bit Run Drill String Name Comment 17 1 Steerable Bit Bit Type Make Model IADC Codes Serial Number Size (in) Bit Dull BIT -PDC NOV TK66-AGt PDC _ A268215 1114 0 ---- Run Parameters Date In Date Out Depth In (ftKB) Depth Out (ftKB) Depth Drilled (ft) Drilling Time (hr) BHA ROP (ft/hr) Nozzles (1132) TFA (nozzles) (in') 10/9/2019 10/10/2019 12,820.0 13,250.0 430.00 1 00 430.0 14114!14114!14!14 0.90 WOS (Min.) ('I 0001bf) WOB (Max.) (10001bt) I Min RPM (rpm) I Max RPM (rpm) Min Flow Rate (gpm) I Max Flow Rate (gpm) I SPP Min (psi) SPP Max (psi) Daily Parameters StartDepth Int Depth Cum Depth Drill Time Cum Drill Int ROP WOB O flow Motor RPM Bit RPM Rot Time Slide Time Start Date (ftKB) (ft) (ft) (hr) Time (hr) (ft/hr) (10001bf) (gpm) RPM (rpm) (rpm) (rpmj SPP (psi) (hrj (hr) 10/9/2019 1 12,820.0 430.001 430.00 1 100 I 1.00 1 4:30.01 1 1 1 1 1 10.00 I1.00 Torque & Drag parameters Start Date Drill Str Wt (10001bf) PU Str Wt (10001bf) SO Str Wt (1 00011o) Drill Tq Off Btm Tq Tq Units 10/9/2019 BHA Components Item Desc. OD (in) I Jts I Len (ft) Cum Len (ft) I End Hrs (hr) Connections 8 75" PDC TK666 1 0.94 12,398.30 1 00 REG x REG Xceed 675 8 5/8" Stab (W dummy float #nosn) 63/41 1 25.01 12,397.36 1 DO FH x FH Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/9/2019 Report #: 1 Page: 3 of 3 8 3/8" Inline Stabilizer 67/8 1 4.99 12,352.90 Telescope 675 NF 6 718 1 25.86 12,347.91 81/4" NM Stabilizer 67/8 1 27.84 12,32205 6 3/4" Flex NM Collar 6 718 1 30.48 12,294 21 Float Sub 6 718 2.51 12,263 73 WCMD w/ Ball Catcher 6 718 1 12.68 12,261 22 XO 6 718 1 3.17 12.24854 Heavy Weight Drill Pipe (3 joints) 67/8 3 92.86 12,245.37 6 112" Drilling Jars 61/2 1 3127 12,152.51 Heavy Weight Drill Pipe (2 joints) 5 2 61.83 12,12124 DACCHAccel. AP 61/2 1 31.63 12,059.41 Heavy Weight Drill Pipe (2 joints) 65/8 2 61.47 12,027 78 Xo 61/2 1 4.29 11,966.31 4-1/2"16.60 DPS, 10% Wear (378 joints) 4112 1 11.956.94 11,962.02 XO 6112 1 4.12 5.08 5" 19.50 DPS, 10% Wear 61/2 1 0.96 100 FHxFH 1 00 FH x FH 1 00 FH x FH 1.00 NC50 (4 1/2 IF) x NICK (4 1/2 IF) 1.00 NC50 (4 12 IF) x NC50 (4 1/2 IF) 1 00 FH x FH 1.00 NC50 (4 12 IF) x NC50 (4 1/2 IF) 1 00 TT525 x NC50 (4 1/2 1.00 TT525 z TT525 1.00 TT525 x TT525 1 00 TT525 z TT525 1 00 TT525 x TT525 1 00 TT525 x TT525 1.00 Delta425 x TT525 1 00 Delta425 x Delta425 1 00 TT525 x Delta425 1.00 TT525 x TT525 supply item uescnpuon: tgtupment fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received 1019/2019 913.0 913.0 Returned Cum Consumed 913.0 Cum Received 913.0 Cum Returned 0.0 Cum On Loc 0.0 Note Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date I Consumed Received 10/9/2019 198.0 198.0 Returned Cum Consumed 198.0 Cum Received 198.0 Cum Returned 0.0 Cum On Loc 0.0 Note Supply Item Description: Rig Fuel Unit Label; gal us Unit Size: 1 Note: Date Consumed Received 10/9/2019 1405.0 16.433.0 Returned Cum Consumed 1,405.0 Cum Received 16,433.0 Cum Returned 0.0 Cum On Loc 15,028.0 Note Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received 10/9/2019 126.0 346.0 Returned Cum Consumed 126.0 I Cum Received 346.0 Cum Returned 0.0 Cum On Loc 220.0 Note Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received 10/9/2019 42.0 42.0 Returned Cum Consumed 42.0 Cum Received 42.0 Cu- Returned . Cum On Loc 0.0 Note Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date lConsumed Received 10/9/2016 0.0 0.0 Returned Cum Consumed 0,0 Cu. Received 0.0 Cum Returned 0.0 Cum On Loc 0.0 Note Last Authority Visit Date Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. Ml Swaco MI Swaco 5 HRWS 12 Safe Cards 5 COW 6 RIR's 4 HARC/JSA Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 Daily Report attachments that can be Well Code: 32145 Date: 10/10/2019 displayed Job: DRILLING Report #: 2 WCEI Level: 3 Page: 1 of 3 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Cc Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RIB - Base Flange (ft) RKB - Tubing Spool (ft) 53.60 13.1 D 16.34 37.26 31.76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 9/27!2019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (fUhr) POB MD @ Report Time (ft... TVD @ Report Time (ft... 14,447.0 4,079.6 1,627.00 17.72 95.0 124.0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Overcast 32.0 SW @ 17 MPH 713.00 713.00 0.00 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) BOP Pressure Test 1 10/9/2019 10/23/2019 13 Camp Evac Drill 1 10/10/2019 1/8/2020 90 Rig Inspection 2 10/10/2019 10/11/2019 1 Safety Meeting 2 10/1012019 10/11/2019 1 TT H2S Drill 1 10/9/2019 10/10/2019 0 Survey Data Date MD(ftKB) Incl I Azm I TVD (RKB) T Vs (ft) I NS (ft) I EW (ft) I DLS (°1100ft) Method 10/10/2019 14,290.339171 375,45 4,084.66 6,601.02 11,382.49 1,556.73 0.86 MWD 10/10/2019 14.383.06 92.00 313.29 4,081.65 6,693.66 11,447.29 1,490.48 2.35 MWD 10/1012019 14,477.02 91.57 313.23 4,078.73 6,787.57 11,511.65 1,422.09 0.46 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (ft)hr) DRILLING 22,100.D 8.255.7 4,054.00 38.67 104.8 Daily Summary Operations 24h Forecast Drill L7 horizontal 8.75" hole per directional/geological plan from 14,447' to 22,103' proposed TD 24h Summary Tripping in the hole from 11,255' to 12,584'. Break circulation, record parameter, Schlumberger survey and down linked to tools while washing from 12,584to 12,820'. Drill U from 12,820' to 14,447, cross fault at 13,864' and back into OA 1 sand at 14,045'. Operation at 07.00 Drilling Ahead @ 15,305' Lithology Shows Mud Weight (Ib/gal) 9.45 Time Log Start End Cum Dur End Depth Time Time our (hr) (hr) Phase Opr. Act. Plan Oper. Descr. (ftKB) 00:00 01 30 1 50 1.50 DRILL E 4 P Continue to trip in the hole from 11,255' to 12,397' on 4.5" 425 Delta drill pipe, filling pipe every 20 stands 12,820.0 UW= 150K. DW= 95K. Change handling equipment to 5" drill pipe,. 01:30 0200 0.50 2.00 DRILL E 4 P Pick-up 6 joints of 5° TT525 drill pipe from 12,397' to 12,584' Service rig, top drive, blocks and draw -works. 12,820.0 02:00 03:00 1 00 3.00 DRILL E 9 P Break circulation with 150 GPM at 450 PSI, wash down from 12,584' to 12,820' and start rotating at 12,811' 12,820.0 with 40 RPM, Schlumberger down inking to tools to establish communication while washing down 03:00 1200 9.00 12.00 DRILL E 3 P Directional drill 8.75" L1 lateral from 12,820' to 13,462' (4,091' TVD) at 520 GPM, SPP 3280 PSI, 10.73 PPG 13,462.0 ECD with 9.4 PPG mud, rotating 120 RPM with 10-12K TO WOB= 2-12K UW= 170K, DW= 75K RTW= 128K. 1200 1800 600 18.00 DRILL E 3 P Directional drill 8.75" L7 lateral from 13,462'to 13,933' (4,083' TVD) at 550 GPM, SPP 3600 PSI, 11.01 PPG 13,933.0 ECD with 9.4 PPG mud, rotating 120 RPM with 10-12K TO. W06= 2-16K. UW= 178K, DW= NIA, RTW= 125K Cross Fault A at 13,864' and back into zone at 14,045' 1800 0000 6.00 24.00 DRILL E 3 P Directional drill 8.75" Lt lateral from 13,933' to 14,447' (4,080' TVD) at 550 GPM, SPP 3660 PSI, 11.08 PPG 14,447.0 ECD with 9.4 PPG mud, rotating 140 RPM with 10-17K TO. WOB= 4-14K UW= 170K. DW= N/A, RTW= 130K Note. Losses to hole last 24 him = 17 BBL, Max gas last 24 hm.= 589 units and average gas 92 units 117,12 hours rotating / 99.7 K -rev's Recovered 4 lbs. metal from ditch magnets, with total 206 lbs recovered Operation from 00:00 to 06:00 Start End Cum our End Depth Time Time our (hr) (hr) Phase Opr. Act. Plan Oper. Descr. (ftKB) 0000 06:00 6.00 30.00 DRILL E 3 P Directional drill 8 314" L7 lateral from 14,447' to 15,206' (4,064' TVD) at 550 GPM, SPP 3750 PSI, 11.2 PPG 15,206.0 ECD with 9.4 PPG mud, rotating 140 RPM with 13-14K TO. WOB= 2-8K. UW= 168K DW= N/A, RTW= 130K Encountered Fault B at 14,986' with 5' throw down did not exit zone Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas (%) Max Connection Gas (% j 92.00 589.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas ( % ) Max Trip Gas M 31.00 589.00 0.00 0.00 Mud Type: LVT - FazePro - 72% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 60orpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc fibf/10... Vis (s/qt) 12,820.0 9.45 47 31 25 18 7 6 16.0 15.006 56 Gel (10s) (Ibf/1... Gel (10m) (Ibfl1.. Gel (30m) Qbf/1... n K Filtrate (mL130... FC (1/32") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 2003 7.003 7.003 0.7 0.8 0.0 0 4.3 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (mL/mL) Mf (mL/mL) Sand (%) Solids (%) H20(%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Titrated 3.100 0.1 12.8 24.5 62.8 71.9/28.1 Brine (Iblgal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime ib/bbl) 10.60 6.0 3.9 69,500.000 0.000 674.0 4.0 Mud Type: LVT - FazePro - 73%Olt Ratio Depth (ftKB) Density (Iblgal) Vis 600rpm Vis 300rpm Vis 2o0rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (CP) YP Calc (Ibf/i0... Vis (slgt) 13,180.0 9 45 46 30 23 16 7 6 16.0 14.006 56 Get (1 Os) (Ibf/1... Gel (10m) (Ibf/1... Gel (30m) (Ibfll... n K Filtrate (mL/30... FC (1132") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.7 0.8 0.0 0 4.3 1 150.0 500.0 pH pH Method Pro (mUmL) Pf (mUmL) Mf (mL/mL) Sand (%) Solids (%) H20(%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Titrated 3.500 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg1L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6 3 3.1 74,000.000 0.000 651.0 4.5 Selected table Well Name: SP03-NE2 L1 CIR(A) has no valid Wellbore Name: SP03-NE2 L1 Daily Report attachments that can be Well Code: 32145 Date: 1 011 0/201 9 displayed Job: DRILLING Report #: 2 WCEI Level: 3 Page: 2 of 3` Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (lb/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 13,6870 9.45 49 32 25 18 7 6 ITT 15.006 56 Gel (10s) (1611'1... Gel (10m) (Ibfl1.. Gel (30m) (Ibf/1... n K Filtrate (mL/30... FC (1132") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.7 0.8 0.0 0 4.3 1 150.0 500.0 PH pH Method Pm (.UmL) Pf (mL/mQ Mf (mL/mL) Sand I%) Solids I%) H2O (%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) Titrated 3.500 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Ib/gal) LGS I%) HGS I%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.3 3.1 74,500.000 0.000 659.0 4.5 Mud Type: LVT - FazePro - 72% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 606rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (CP) YP Calc (1bf110... Vis (s/qt) 14,185.0 9.45 54 36 28 19 7 6 18.0 18.007 56 Gel (10s) (Ibf/1... Gel (10m) (Ibfl1... Gel (30m) (Ibfl1... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 7.003 7.003 7.003 0.7 0.8 0.0 0 4.2 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (mL/mL) Mf (mL/mL) Sand I%) Solids I%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Titrated 3.500 0.1 12.5 24.3 63.3 72,31277 Brine (Ib/gal) LGS (%) HGS I%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 1060 6.5 2.9 73.000.000 0.000 726.0 4.5 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,006.9 Loss 17 0 Tank 500.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 1,506.9 1,006.9 0.0 0.0 17.0 18.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Ent representative Simone Belemmi Ent Drilling Supv. siddrilling@eni.com 907-685-0715 Em representative Steve Lawrence Ent Drilling Supv. siddrilling@eni.com 685-0715 Eni representative David Smith En, Drilling Supv. siddrilltng@eni.com 907-685-0715 Eni representative Wade Thomas Em Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Eni representative Pat Ahern Eni HSE Eni representative Mark Hubler Ent HSE Drilling Supt. Sam Dye Doyon Drilling Field Superintendent Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig 15@doyondrilling.com Tool Push Einer Fleagle Doyon Drilling Tool Push Tool Push Cliff Owens Doyon Drilling HSE cowens@doyondrilling.com 685-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyondrilling.com 685-0796 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) count Note GOR Casing 12.50 0 Drilling Baker Liner Hanger 12.50 0 Drilling Rubicor. Swivel 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Eni Company Man 12.50 1 Drilling Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling K&M ERD 12.50 1 Drilling AGS Enviromental 12,50 2 SID Support ASRC Company Man 1250 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon NSE 12.50 2 Drilling Halliburton Mud Loggers 12 50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling RPS Geologist 1250 2 Drilling SLB Cement 12 50 2 Drilling SLB Directional Driller 12.50 2 Drilling SLB MWD 12.50 2 Drilling Competentia Logistic 12.50 4 SID Support MI Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 10 SID Support Doyon Rig Personnel 12.50 26 Drilling_Total Drilling Personnel Worley Truck driver 7 Crane operator 12.50 33 Drilling BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 8/7/2019 5/1/2015 15,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular Hydril GK 500 13 5/8 5,000.0 5/1/2015 3 1/2 "- 6" VBR Hyddl MPL 5000 13 5l8 5,000.0 8124/2018 Blind Shear Ram Hydril MPL 5000 13 5/8 5,000.0 8/24/2018 4 112" x 7" VBR Hydril MPL 5000 13 5/8 5,000.0 5/1/2015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 8/27/2019 6 0.113 5,323.0 Date Depth (ftKB) Slow SpitStrokes (spm) P (psi) Eff (%) O Flow (gpm) 10!1012019 Yes 22 370.0 10/10/2019 Yes 30 480.0 Pump Number. 2 Maker White Star Model: Quatro 2450 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/10/2019 Report #: 2 Page: 3 of 3 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 8/27/2019 6 0.113 I 5, 323.0 Date Depth (ftKB) Slow Spot Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10!1012019 Yes 22 375.0 1 0/10/2019 Yes 30 470.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 8/27/2019 6 0.102 4,665.0 Date Depth (ftKB) Slow Spot Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10110/2019 Yes 39 460.0 10/10/2019 Yes 29 375.0 1 1 Last BHA BHA # I Bit Run Drill String Name Comment 17 11 Steerable Bit Bit Type Make Model IADC Codes Serial Number Size (in) Bit Dull 81T -PDC NOV TK66-AG1 PDC _ A268215 83/4 0 ----- Run Parameters Date In Date Out Depth In (ftKB) Depth Out (ftKB) Depth Drilled (ft) Drilling Time (hr) BHA ROP (fUhr) Nozzles (1/32") TFA (nozzles) (in') 10/1012019 10/12/2019 12,820.0 16,874.0 4,054.00 38.67 104 8 14114114/74/14/14 0.90 WOB (Min.) (10001bf) WOB (Max.) (10001bt) Min RPM (rpm) Max RPM (rpm) Min Flow Rate (gpm) Max Flow Rate (gpm) SPP Min (psi) SPP Max (psi) B 14 140 I 140 550 550 I 3,660,0 3,820.0 Daily Parameters Start Depth Int Depth Cum Depth Drill Time Cum Drill Int ROP WOB q Flow Motor RPM Bit RPM Rot Time Slide Time Start Date (ftKB) (ft) (ft) (hr Time (hr) (ft/hr) (t0001bf) (gpm) RPM (rpm) (rpm) (rpm) SPP (psi) Ihr) (hr) 10/70/2019 12,820.0 1,627.00 1,627.00 17.12 17.12 95.0 8 550 140 0 140 3,660.0 1712 0.00 70/11/2019 14,447.0 1 2.427.00 4,054.00 21.55 38.67 112.6 14 550 140 0 140 3,820.0 2155 0.00 Torque & Drag parameters Start Date Drill Str Wt (10001bf) PU Str Wt (10001bf) I SO Str Wt (10001bf) Drill Tot Off Stm Tot Tq Units 10/10/2019130 170 75 14.0 10.0 Ibs.ft 10/11/2019 127 172 0 18.0 12.0 Ibs.ft BHA Components Item Desc. OD (in) Jts Len (ft) Cum Len (ft) End Hrs (hr) Connections 8.75" PDC TK66 6 1 0.94 12,398.30 38.67 REG x REG Xceed 675 8 518" Stab (W dummy float #nosn) 6 314 1 25.01 12,397.36 38.67 FH x FH Periscope 675 GR/RES/DHATlDHAP 63/4 1 1945 12,372.35 38.67 FH x FH 8 3/8" Inline Stabilizer 67/8 1 4.99 12,352.90 38.67 FH x FH Telescope 675 NF 67/8 1 25.86 12,347 91 38.67 FH x FH 8 114" NM Stabilizer 6 718 1 27.84 12,322.05 38.67 NC50 (4 1/2 IF) x NC50 (4 112 IF) 6 314" Flex NM Collar 67/8 1 3048 12,294 21 38.67 NC50 (4 112 IF) x NC50 (4 1/2 IF) Float Sub 6718 251 12,263.73 38.67 FH x FH WCMD w/ Ball Catcher 6 718 1 12.68 12,261.22 38.67 NC50 (4 1/2 IF) x NC50 (4 12 IF) XG 67/8 1 3.17 12,248.54 38.67 TT525 x NC50 (4 1/2 Heavy Weight Drill Pipe (3 joints) 67/8 3 92.86 12,245.37 38.67 TT525 x TT525 6 1/2" Drilling Jars 6 112 1 31 27 12,152.51 38.67 TT525 x TT525 Heavy Weight Drill Pipe (2 joints) 5 2 61.83 12,121.24 38.67 TT525 x TT525 DACCH Accei. AP 6 1/2 1 31 63 12,059.41 38.67 TT525 x TT525 Heavy Weight Drill Pipe (2 joints) 65/8 2 61.47 12,027.78 38.67 TT525 x TT525 XO 6112 1 4.29 11,966.31 38.67 Deita425 xTT525 4-12" 16.60 DPS, 10% Wear (378 joints) 4 112 1 11,956.94 11,962.02 38.67 Deita425 x Deita425 XO 61/2 1 4.12 5.08 38.67 TT525 x Deita425 5" 19.50 DPS, 10% Wear 6112 1 0.96 38.67 T7525 x TT525 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date lConsurned Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/1012019 531.0 531.0 1,444.0 1,444.0 0.0 0.0 Supply Item Description: Mud Plant Bolters Unit Label: Gal Unit Size: Note: Date lConsumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc No[e 1011012019 198.0 198.0 396.0 396.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum OFL oc Note 10/10/2019 2,855.0 722.0 4,260.0 77,155.0 O.0 12,895. Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/70/2019 58.0 135.0 184.0 481.0 D.0 12970 Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date 1Zonsumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/10/2019 42.0 42.0 I 84.0 84.0 0.0 0.0 Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10110!2019 0.0 0.0 0.0 0.0 0.0 0.0 Last Authority Visit Date I Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling 8 PJSM'S Doyon Drilling Inc. 8 COW Doyon Drilling Inc. 12 Safe Cards Doyon Drilling Inc. 8 HRWS MI Swaco 6 RIR's Ml Swaco 4 HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/1112019 Report #: 3 Page: 1 of 3 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB - Base Flange (ft) RKB -Tubing Spool fit) 53.60 13.10 16.34 37.26 31.76 Rigs Rig Name ContractorRig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 9/27/2019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (ftthr) POB MD @ Report Time (ft... TVD @ Report Time (ft... 16,874.0 4,044.3 2,427.00 2155 112.6 123.0 WeatherTemperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Overcast 32.0 W @ 23 MPH 714.00 I 714.00 0.00 I Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) BOP Pressure Test 1 10/9/2019 10/2312019 12 Camp Evac Drill 1 10/1012019 1/8/2020 89 Rig Inspection 3 10/11/2019 10/12/2019 1 Safety Meeting 3 10/11/2019 10/12/2019 1 Spill Drill 1 10/11/2019 10/25/2019 14 TT 112S Drill 1 10/9/2019 10/10/2019 -1 TT Kick While Drilling 1 10/1112019 10/18/2019 7 Survey Data Date MD (ftKB)Incl (°) Azm (°) TVD,ftKB) VS (ft) NS (ft) EW (ft) OLS (°1100ft) Method 10/11/2019 16,715.59 90.84 31432 4,046.76 9,023.52 13,08815 -165.33 1.21 MWD 10111/2019 16,808.91 90.89 312.06 4,045.35 9,116.82 13,152.01 -233.35 2.42 MWD 10/11/2019 16,874.00 90.89 312.06 4,044.34 9,161.90 13,195.61 -281.67 0.00 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (ft/hr) DRILLING 22,100.0 8,255.7 4,054 00 38.67 104.8 Daily Summary Operations 24h Forecast Drill L1 horizontal8 3/4" hole section per directionallgeological plan from 16,874 to 22,103' proposed TD 24h Summary Drill Li horizontal 3/4" hole section per directional/geological plan from 14,447 to 16,874' (4,044 TVD) Encountered Fault 6 at 14,986' and Fault C at 15,542 did not exit zone Operation at 07.00 Drilling Ahead @ 17,403' Lithology Shows Mud Weight (Ib/gal) 9.40 Time Log Start End Cu. Our End Depth Time Time Our (hr) (hr) Phase Opr. Act. Plan Oper. Descr. (ftKB) 0000 06:00 6.00 6.00 DRILL E 3 P Directional drill 8 314° L7 lateral from 14,447' to 15,206' (4,064' TVD) at 550 GPM, SPP 3750 PSI, 11.2 PPG 15,206 0 ECD with 9.4 PPG mud, rotating 140 RPM with 13-14K To. WOB= 2-8K UW= 168K, DW= N/A, RTW= 130K. Encountered Fault B at 14,986' with 5' throw down did not exit zone 06.00 1200 6.00 12.00 DRILL E 3 P Directional drill 8 3/4" Li lateral from 15,206' to 15,822' (4,051' TVD) at 550 GPM, SPP 3770 PSI, 11.29 PPG 15,822.0 ECD with 9.4 PPG mud, rotating 140 RPM with 14-19K TO. WOB= 4-14K UW= 169K. DW= N/A, RTW= 125K Encountered Fault C at 15,542' with 24' throw down - did not exit zone 1200 1800 6.00 18.00 DRILL E 3 P Directional drill 8 3/4" Lt lateral from 15,822' to 16.314'(4,043' TVD) at 550 GPM, SPP 3750 PSI, 11.26 PPG 16,314.0 ECD with 9.4 PPG mud, rotating 140 RPM with 14-18K TO, WOB= 2-14K UW= 170K, DW= NIA, RTW= 127K 1800 0000 6.00 24.00 DRILL E 3 P Directional drill 8 3/4" Lt lateral from 16,314' to 16,874'(4,044' TVD) at 550 GPM, SPP 3820 PSI, 11.33 PPG 16,874.0 ECD with 9.4 PPG mud rotating 140 RPM with 15-19K TO W06= 2-14K. UW= 172K, DW= N/A, RTW= 127K Note. Losses to hole lest 24 hrs. = 35 BBLS, Max gas last 24 hrs = 559 units and average gas 67 units t 21.55 hours rotating 1158,21 K -rev's. Recovered 11.2 Ibsmetal from ditch magnets, with total 217.2 lbs. recovered. Gas Readings Avg Background Gas I%) Max Background Gas (%) Avg Connection Gas I%) Max Connection Gas (%) 67.00 559.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas I%) Max Trip Gas M) 67.00 559.00 0.00 0.00 Mud Type: LVT - FazePro - 72% OI/ Ratio Depth (ftKB) Density (Iblgal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 14,883.0 9.40 52 34 27 20 7 6 18.0 16.007 56 Gel (10s) (Ibf/i... Gel (10m) (Ibfl1.. Gel (30m) (Ibf/1... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 7.003 7.003 7.003 0.7 0.7 0.0 0 4,4 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (mL/mL) Mf (m L/m L) Sand (%) Solids (%) H2O (%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) Tirated 3.500 0.1 12.5 24.3 63.3 72.3127.7 Brine (Iblgal) LGS I%) HGS (%) Barite (lblbbp Chlorides (nii Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.5 2.9 73.000.000 0.000 746 0 4.5 Mud Type: LVT - FazePro - 72% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf110... Vis (s/qt) 15,495.0 9.40 55 36 29 20 7 6 19.0 17.007 56 Gel (10s) (Ibf/1... Get (10m) (Ibf11... Gel (30m) (Ibf/1 ... n K Filtrate (ml -130... FC (1132") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 7.003 7.003 7.003 0.7 0.7 0.0 0 4.3 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (mL/mL) Mf (.UmL) Sand I%) Solids I%) H2O (%) Percent Oil (%) Oil Water Ratio MST (Ib/bbl) Titrated 3.300 0.1 12.3 24.5 63.3 72.1/27.9 Brine (Iblgal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mglL) CaC12 (ppm) Electric Stab (V) Ex. Lime (Iblbbl) 10.60 6.5 2.9 70,000.000 0.000 1 1 786.0 4.3 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 Daily Report attachments that can be Well Code: 32145 Date: 10/11/2019 displayed Job: DRILLING Report #: 3 WCEI Level: 3 Page: 2 of 3 Mud Type: LVT - FazePro, - 72% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 16,0910 9.40 55 35 28 20 7 6 20.0 15.006 55 Gel (10s) (Ibflt... Gel (10m) (Ibf/1.. Gel (30m) (Ibf/1... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 7.003 7.003 7.003 0.7 0.7 0.0 0 4.3 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (mUmL) Mf (mUmL) Sand I%) Solids I%) H2O I%) Percent Oil I%) Oil Water Ratio MET (lb/bbl) Titrated 3.300 0.1 12.3 24.5 63.3 72.1/27.9 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.5 2.8 70,500.000 0.000 789.0 4.3 Mud Type: LVT - FazePro - 72% Oil Ratio Depth (ftKB) Density (Ib/gat) Vis 600rpm Vis 30Drpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (eP) YP Calc (Ibf/t0... Vis (slgt) 16,650.0 9.40 54 36 29 21 8 7 18.0 18.007 55 Gel (10s) (Ibfl1... Gel (10m) (Ibf/1.. Gel (30m) (Ibf/1 ... n K Filtrate (ml -130... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 7.003 7.003 8.003 07 07 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (mUmL) Mf (mUmL) Sand (%) Solids (%) H2O I%) Percent Oil (%) Oil Water Ratio MET (Ib/bbl) Tirated 3.100 0.1 12.5 24.5 63.0 72/28 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg1L) Pot (mglL) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 1060 6.6 3.0 70,000.000 0.000 782.0 4.0 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,171.6 Loss 35.0 Tank 683.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 1,854.6 1,171.6 0.0 0.0 35.0 53.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Simone Belemml Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Bmce Simonson Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative David Smith Em Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Wade Thomas Eni Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Eni representative Pat Ahern Eni HSE Eni representative Mark Hubler Eni HSE Drilling Supt. Sam Dye Doyon Drilling Field Superintendent Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig 15@doyondrilling.com Tool Push Einer Fleagle Doyon Drilling Tool Push Tool Push Cliff Owens Doyon Drilling HSE cowens@doyondrilling.com 685-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyondrilling.com 685-0796 Personnel Log (POB) Company Sent. Type Work H (hr) Stand-by H (hr) Count Note GER Casing 12.50 0 Drilling Baker Liner Hanger 12.50 0 Drilling Rubicon Swivel 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Eni Company Man 12,50 1 Drilling Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling K&M ERD 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12 W 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling RPS Geologist 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB Directional Driller 12.50 2 Drilling SLB MWD 12.50 2 Drilling Competentia Logistic 12.50 4 SID Support MI Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 10 SID Support Doyon Rig Personnel 12.50 24 Drilling_Total Drilling Personnel Worley Truck driver / Crane operator 12.50 34 Drilling BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 617/2019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular Hydril 13518 5,000.0 5/1/20753 1/2 "- 6" VBR Hydril TGK 00 13 518 5,000.0 8/24/2018 Blind Shear Ram Hydril 00 13 5/8 5,000.0 8/24/2018 4 1/2" x 7" VBR Hydril 00 13 5/8 5,000.0 5/112015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 6/27/2079 6 0.113 5,323.0 Date Depth (ftKB) Slow Spot Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/11/2019 16,407.0 Yes 30 630.0 10/11/2019 16,407.0 Yes 22 510.0 Pump Number: 2 Make, White Star Model: Quatro 2450 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 1 0/1 112 01 9 Report #: 3 Page: 3 of 3 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 8/2712019 6 0.113 5,3230 Date Depth (ftKB) Slow Spot Strokes (spm) P (psi) Eff 1%) Q Flow (gpm) 10/11/2079 16,407.0 Yes 22 505.0 10/11/2019 16,407.0 Ves 30 640.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 8/27/2019 6 0.102 4,6 65.0 Date Depth (ftKB) Slow Sind Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10111/2019 11,407 1Yes 29 515.0 10/11/2019 16,407.0 Yes 39 640.0 Last BHA BHA # Bit Run Drill String Name Comment 17 t Steerable Bit Bit Type Make Model /ADC Codes Serial Number Size (in) Bit Dull BIT -PDC NOV TK66-AG1 PDC A268215 83/4 0 ---- Run Parameters Date In Date OutDepth In (ftKB) Depth Out (ftKB) Depth Drilled (ft) Drilling Time (hr) BHA ROP (ft/hr) Nozzles (1/32") TFA (nozzles) (in') 10/10/2019 10/12/2019 12,820.0 16,874.0 4,054.00 38.67 104.8 14/14114/14/14/14 0.90 WOB (Min.) (10001bf) WOB (Max.) (10001bf) Min RPM (rpm) Max RPM (rpm) Min Flow Rate (gpm) Max Flow Rate (gpm) SPP Min (psi) SPP Max (psi) 6 14 140 I I 140 550 I 550 3,660.0 3,820.0 Daily Parameters Start Depth Int Depth Cum Depth Drill Time Cu. Drill Int ROP WOB Q Flow Motor RPM Bit RPM Rot Time Slide Time Start Date (ftKB) (ft) (ft) (hr) Time (hr) (It hr) 00001bf) (gpm) RPM (rpm) (rpm) (rpm) SPP (psi) Ihr) (hr) 10/10!2019 12,820.0 1,627.00 1,627.00 77.12 17.12 95.0 8 550 140 0 140 3,660.0 77.12 0.00 10!11!2019 14,447 0 2,427.00 4,054.00 21 55 38.67 112.6 14 550 140 0 740 3,820.0 21.55 0.00 Torque 8 Drag parameters Start Date Drill Str Wt (10001bf) PU Str Wt (10001bf) SO Str Wt (10001bf) Drill Tq Off Btm Tq Tq Units 10/10/2019130 170 75 14.11 10.0 lbs ft 10/11/2019 127 172 0 18.0 12.0 Ibs.ft BHA Components Item Dese. OD (in) Jts Len (ft) Cum Len (ft) End Fire (hr) Connections 8 75" PDC TK66 6 1 0.94 12,398.30 38.67 REG x REG Xceed 675 8 5/8" Stab (W dummy float #nosn) 63/4 1 25.01 12,397.36 38.67 FH x FH Periscope 675 GR/RES/DRAT/DHAP 63/4 1 19.45 12,372.35 38.67 FH x FH 8 3/8" Inline Stabilizer 67/8 1 4.99 12,352.90 38.67 FH x FH Telescope 675 NF 67/8 1 25.86 12,347 91 38.67 FH x FH 8 1/4" NM Stabilizer 6 718 1 27.84 12,322.05 38.67 NC50 (4 12 IF) x NC50 (4 1/2 IF) 6 314" Flex NM Collar 6 718 1 30.48 12,294.21 38.67 NC50 (4 1/2 IF) x NC50 (4 1/2 IF) Float Sub 6 718 2.51 12,263.73 38.67 FH x FH WCMD wl Ball Catcher 67/8 1 12.66 12,261.22 38.67 NC50 (4 112 IF) x NC50 (4 12 IF) XO 6 7/8 1 3.17 12,248.54 38.67 TT525 x NC50 (4 1/2 Heavy Weight Drill Pipe (3 joints) 6 7/8 3 92.86 12,245.37 38.67 TT525 x TT525 6 1/2" Drilling Jars 6112 1 31.27 12,152.51 38.67 TT525 x TT525 Heavy Weight Drill Pipe (2 joints) 5 2 61.83 12,121.24 38.67 TT525 x TT525 DACCH Aces[. AP 6 1/2 1 31 63 12,059.41 38.67 TT525 x 17525 Heavy Weight DNI Pipe (2 joints) 65/8 2 61-47 12,027.78 38-67 TT525 x TT525 XO 61/2 1 4.29 11,966.31 38.67 DeIta425 xTT525 4-1/2" 16.60 DPS, 10% Wear (378 joints) 4 1/2 1 11,956.94 11,962.02 38.67 DeIta425 x DeIta425 X0 61/2 1 4.12 5.08 38.67 TT525 x DeIta425 5" 19.50 DPS. 10% Wear 61/2 1 0.96 38.67 TT525 x TT525 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cu- On Loc Note 10/11/2019 876.0 876.0 2,320.0 2,320.0 0.0 0.0 Supply Item Description: Mud Plant Bollers Unit Label: Gal Unit Size: Note: Date lConsurned Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10111/2019 198.0 198.0 594.0 594.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Dated Received Returned Cum Consumed Cu' Received Cum Returned Cum On Loc Note 10/11/2019 3,720.0 12,686.0 7,980.0 29,8410 0.0 21,861.0 Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/11/2019 69.0 0.0 253.0 481.0 0.0 228.0 Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/10/2019 42.0 42.0 840 84.0 0.0 0.0 Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Not, 10/10/2019 0.0 0.0 0.0 0.0 0.0 0.0 Last Authority Visit Date I Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Driving 5 PJSM'S Doyon Drilling Inc. 5 HRWS Doyon Drilling Inc. 5 COW Doyon Drilling Inc. 15 Safe Cards Ml Swaco 4 HARC/JSA MI Swaco 6 RIR', General Notes Comment: Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 Daily Report attachments thatcan be Well Code: 32145 Date: 10/1212019 displayed Job: DRILLING Report #: 4 WCEI Level: 3 Page: 1 of 3 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (k) RKB -Base Flange (ft) RKB -Tubing Spool (k) 53.60 13.10 16.34 37.26 31.76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 927/2019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft(hr) POB MD @Report Time (k... TVD @Report Time (ft... 19,060.0 4,021.8 2.186.00 14.72 148.5 123.0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Overcast 30.2 SW @ 12 MPH 715.00 715.00 0.00 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) BOP Pressure Test 1 10/912019 10/23/2019 11 Camp Evac Drill 1 10/10/2019 1/8/2020 88 Rig Inspection 4 10/12/2019 10/13/2019 1 Safety Meeting 4 10/12!2019 10/13/2019 1 Spill Drill 2 10/12/2019 1026/2019 14 TT H2S Drill 1 10/9/2019 10/10/2019 -2 TT Kick While Drilling 1 101112019 10118/2019 6 Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD (ftKB) VS (ft) NS (ft) EW (ft) DLS (°1100ft) Method 10/12/2019 18,957.40 89.97 314.95 4,021.53 11,420.34 14,68373 -1,738.35 10112/2019 19,050.43 8974 31518 4,02177 11,513.35 14,749.58 -1,804.06 T145 D 10/1312019 19,144.00 89,94 31487 4,022.03 11,606.90 14,815.77 -1,870.19 D Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (ft/hr) DRILLING 22,100.0 8,255.7 6,240.00 43.55 143.3 Daily Summary Operations 24h Forecast Drill ahead L1 horizontal 8 314" hole per directional/geological plan from 19,060' to 22,103' proposed TD. 24h Summary Drilled Lt horizontal 8 314" hole section per directionallgeological plan from 16,874' MD to 19,060'(4,022 TVD). Operation at 07.00 Drilling Ahead A 19,835' Lithology Shows Mud Weight (Ib/gal) 9.40 Time Log Start End Cum Dur End Depth Time Time Dur (hr) (hr) Phase Oar. Act. Plan Oper. Descr. (ftKB) 0000 0600 6.00 6.00 DRILL E 3 P Directional drill 8 3/4" L1 lateral from 16,874'to 17,266' (4,048' TVD) at 550 GPM, SPP 3800 PSI. 11.32 PPG 17,266.0 ECD with 9.4 PPG mud, rotating 140 RPM with 14-20K TQ WOB= 4-14K UW= 175K, DW= N/A, RTW= 129K 06-00 1200 6.00 12.00 DRILL E 3 P Directional drill 8 314" Ll lateral from 17,266' to 17,952' (4,048' TVD) at 550 GPM, SPP 3950 PSI, 11.50 PPG 17,952.0 ECD with 9.4 PPG mud, rotating 140 RPM with 14-20K TO WOB= 4-16K. UW= 179K, DW= WA, RTW= 128K 1200. 1800 6.00 18.00 DRILL E 3 P Directional drill 8 3/4" Li lateral from 17,952' to 18,554' (4,030' TVD) at 540 GPM, SPP 3900 PSI, 11.51 ECD 18.554 0 with 9.4 PPG mud, rotating 140 RPM with 15-16K TO WOB= 2-14K UW= 182K. OW= N/A, RTW= 126K. 1800 00:00 6.00 24.00 DRILL E 3 P Directional drill 8 314° Li lateral from 18,554' to 19,060' (4,022' TVD) at 540 GPM, SPP 3910 PSI, 11.6 ECD 19,060.0 with 9.4 PPG mud, rotating 140 RPM with 15-17K TQ. WOB= 2-14K UW= 178K, DW= NIA, RTW= 126K. Note Losses to hole last 24 hrs. = 60 BBL Max gas last 24 hrs.= 155 units and average gas 68 units 120 78 hours rotating / 150.39 K -rev's Recovered 9 75 lbsmetal from ditch magnets - Total recovered 215.75 lbs Gas Readings Avg Background Gas I%) Max Background Gas I%) Avg Connection Gas (%) Max Connection Gas I%) 68.00 155.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas I%) Avg Trip Gas I%) Max Trip Gas I%) 68.00 155.00 0.00 0.00 Mud Type: LVT - FazePro - 72% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis IOOrpm Vis 6rpm Vis 3rpm PV Catc (cP) YP Calc (Ibf/10... Vis (s/qt) 17,002.0 9.40 54 36 29 21 8 7 18.0 18.007 55 Gel (10s) (Ibf/1... Gel (1 Om) (11,1`11.. Gel (30m) (Ibf/1 ... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 7.003 8 003 8.003 0 7 0.6 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (mL/.L) Mf (mL/mL) Sand I%) Solids I%) H2O (%) Percent Oil I%) Oil Water Ratio MBT (Iblbbl) Titrated 3.100 0.1 12.5 24.5 63.0 72128 Brine (Ib/gal) LGS I%) HGS I%) Barite (Ib/bbl) Chlorides mg/L) Calcium (mg/L) Mg (mg/L) Pot (mglL) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.5 3.2 69,000.000 0.000 31 756.0 4.0 Mud Type: LVT - FazePro - 72% Oil Ratio Depth (ftKB) Density (Ib/gap Vis 600rpm Vis 300rpm Vis 200rpm Vis t00rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 17,638.0 9.40 55 37 29 21 8 7 18.0 19.008 55 Gel (10s) (Ibf/1... Gel (10m) (Ibflt... Gel (30m) (Ibf/1... in K Filtrate (mL/30... FC (1132") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 7.003 7.003 8.003 0.7 0.6 0.0 0 4 4 1 150.0 500.0 PH pH Method Pm (mL/mL) Pf (mL/mL) Mf (.L/mL) Sand I%) Solids I%) H2O (%) Percent Oil I%) Oil Water Ratio MBT (Iblbbp Titrated 3.000 0.1 12.3 24.5 63.3 72.1/27.9 Brine (Ib/gap LGS I%) HGS (%) Barite Q1,lbbp Chlorides (mglL) Calcium mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 53 3.5 69,500.000 0.000 31 774.0 3.9 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 Daily Report attachments that can be Well Code: 32145 Date: 10/12/2019 displayed Job: DRILLING Report #: 4 WCEI Level: 3 Page: 2 of 3 Mud Type: LVT - FazePro - 72% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 18,290.0 9.40 52 36 29 21 8 7 16.0 20.008 57 Get (10s) (Ibf/1... Gel (10m) (Ibf/l .. Gel (30m) (Ibfl1.. n K Filtrate (mU30... FC (1132") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 8.003 8.003 8.003 0.7 0.6 0.0 0 4,4 1 150.0 500.0 PH pH Method Pm (mUmL) Pf (mLImL) Mf (mUmL) Sand I%) Solids I%) H2O (%) Percent Oil I%) Oil Water Ratio MET (Ib/bbl) Titrated 2.900 0.1 12.0 25.0 63.0 71.6128.4 Brine (Ib/gal) LGS (%) HGS I%) Barite (lb/bbl) Chlorides (mg/L) Calcium (mg1L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (lb/bbl) 10.60 40 5.1 70,000.000 0.000 31 773.0 3.8 Mud Type: LVT - FazePro - 72% Oil Ratio Depth (ftKB) Density (lb/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 18,739.0 9.40 53 35 29 21 8 7 18.0 17.007 55 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1.. Gel(30m) (Ibf11... n K Filtrate (mL/30... FC (1132") HTHP Filtrate (... HTHP FC (1132') T HTHP (°F) P HTHP (psi) 7.003 8.003 8.003 0.7 0.6 0.0 0 4.4 1 150.0 500.0 PH pH Method Pm (mL/mL) Pf (mLImL) Mf (mL/mL) Sand I%) Solids I%) H2O I%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.800 0.1 12.3 25.0 62.8 715/28.5 Brine (Ib/gal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (lb/bbl) 10.60 6.0 3.3 71,000.000 0.000 31 718.0 3.6 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,322.0 Loss 60.0 Tank 563.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) losses (bbl) Cum Losses (bbl) 1,885.0 1,322.0 0.0 0.0 60.0 113.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Simone Belemmi Ent Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Chad Gueco Eni Drilling Sup, 907-685-0726 Eni representative David Smith Em Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Wade Thomas Eni Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Eni representative Pat Ahem Eni HSE Eni representative Mark Hubler Eni HSE Drilling Supt Sam Dye Doyon Drilling Field Superintendent Tool Push Ryan Pankratz Doyon Drilling Tool Pusher ngl5@doyondrilling.com Tool Push Einer Fleagle Doyon Drilling Tool Push Tool Push Cliff Owens Doyon Drilling HSE cowens@doyondrilling.com 685-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyondrilling.com 685-0796 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note GBR Casing 12.50 0 Drilling Baker Liner Hanger 12 50 0 Drilling Rubicon Swivel 1250 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Eni Company Man 12.50 1 Drilling Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco(BHGE) Wel[Head 12.50 1 Drilling K&M ERD 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 1250 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 1250 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling RPS Geologist 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB Directional Driller 12.50 2 Drilling SLB MWD 12.50 2 Drilling Competentia Logistic 12.50 4 SID Support MI Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12,50 8 SID Support ESS Catering 12.50 10 SID Support Doyon Rig Personnel 12.50 24 Drilling -Total Drilling Personnel Worley Truck driver / Crane operator 12.50 34 Drilling BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 817/2019 5/1/2015 5,000.0 Type Make Model to Nom (in) P Range (psi) I Last Cert Date Annular:jHyd,il dril GK 500 13 5/8 5,000.0 5/1/2015 3 1/2 "-6" VBR dril MPL 5000 13 5/8 5,000.0 8/24/2018 Blind Shear Ram dril MPL 5000 �MPI_5000 135/8 5,000.0 8/2422018 4 1/2" x 7" VBR 13 5/8 5,000.0 i 5/1/2015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 8/27/2019 6 0.113 I 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 10/12/2019 18,741.0 Yes 30 700.0 10/12/2019 18,741.0 Yes 22 540.0 Pump Number: 2 Make: White Star Model: Quatro 2450 Selected table Well Name: SP03-NE2 L1 CIR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/12/2019 Report #: 4 Page: 3 of 3 Start Date End Date Liner Size (In) Volume Per Stroke Override (bblistk) Max Pressure (psi) 8/27/2019 6 0.113 I 5,323.0 Date Depth (ftKB) Slow SpdStrokes (spm) P (psi) Eff (%) Q Flow (gpm) 10112/201918,741.0 Yes 22 540.0 10/12/2019 18,741.0 Yes 30 690.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bblistk) Max Pressure (psi) 8/27/2019 6 I 0.102 4,665.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/12/2019 18,741.0 Ves 39 695.0 10/12/2019 18.741.0 Ves 29 550.0 Last BHA BHA #Bit Run Drill String Name Comment 17 1 Steerable Bit Bit Type Make Model IADC Codes Serial Number Size (in) Bit Dull 130___ BIT -PDC NOV TK66-AG1 PDC _ A268215 8314 - Run Parameters Date In Date Out Depth In (ftKB) Depth Out (ftKB) Depth Drilled (ft) Drilling Time (hr) BHA ROP (ft/hr) Nozzles (1132") TFA (nozzles) (in') 10/10/2019 10/13/2019 12,820.0 19,060.0 6,240.00 43.55 143.3 14/14!14114114/74 0.90 WOB (Min.) (11 0001bf) WOB (Max.) (10001bf) Min RPM (rpm) Max RPM (rpm) Min Flow Rate (gpm) Max Flow Rate (gpm) SPP Min (psi) SPP Max (psi) 8 15 140 I I 140 540 I 550 3,660.0 3,910.0 Daily Parameters Start Depth Int Depth Cum Depth Drill Time Cum Drill Int ROP WOB Q Flow Motor RPM Bit RPM Rot Time Slide Time Start Date (ftKB) (ft) (ft) (hr) Time (hr) (ft/hr) If 0001bf) (gpm) RPM (rpm) (rpm) (rpm) SPP (psi) (hr) (hr) 10/10/2019 12,820.0 1,627.00 1,627.00 12.69 12.69 128.2 8 550 140 0 140 3,660.0 12.69 0.00 10/11/2019 14,447.0 2,42700 4,054.00 1614 28.83 150.4 14 550 140 0 140 3,820,0 16.14 0.00 10/12/2019 16,874.0 2,186.00 6,240.00 1472 43.55 148.5 15 540 140 0 140 3,910.0 14.72 0.00 Torque & Drag parameters Start Date Drill Str Wt If 0001bf) PU Str Wt (10001bf) SO Str Wt (1000lbf) Drill Tq Off Btm Tq Tq Units 10/10/2019130 170 75 14.0 10.0 Ibs.ft 10/11/2019 127 172 0 18.0 12.0 Ibs.ft 10/12/2019 126 178 0 19.0 12.0 Ibs.ft BHA Components Item Desc. OD (in) Jts Len (ft) Cum Len (ft) End Hrs (hr) Connections 8.75" PDC TK66 6 1 0.94 12,398.30 43.55 REG x REG Xceed 675 8 518" Stab (W dummy float #nosn) 63/4 1 25.01 12,397.36 43.55 FH x FH Periscope 675 GR/RES/DHAT/DHAP 6 314 1 19.45 12,372.35 43.55 FH x FH 8 3/8" Inline Stabilizer 67/8 1 4.99 12,352.90 43.55 FH x FH Telescope 675 NF 6 718 1 25.86 12,347.91 43.55 FH x FH 8 114" NM Stabilizer 67/8 1 27.84 12,322.05 43.55 NC50 (4 12. IF) x NC50 (4 112 IF) 6 3/4" Flex NM Collar 67/8 1 30.48 12,294.21 4355 NC50 (4 112 IF) x NC50 (4 112 IF) Float Sub 6 718 2.51 12,263,73 43 55 FH x FH WCMD w/ Ball Catcher 6 718 1 12.68 12,261.22 43.55 NC50 (4 1121F) x NC50 (4 1/21F) XO 67/8 1 3 17 12,248.54 4355 TT525 x NC50 (4 1/2 Heavy Weight Drill Pipe (3 joints) 6 718 3 92.86 12,245.37 43.55 TT525 x TT525 6 1/2" Drilling Jars 6 112 1 31.27 12,152.51 43.55 TT525 x TT525 Heavy Weight Drill Pipe (2 joints) 5 2 61.83 12,121 24 43.55 TT525 x TT525 DACCH Accel. AP 61/2 1 31.63 12,059.41 43 55 TT525 x TT525 Heavy Weight Drill Pipe (2 joints) 65/8 2 61.47 12,027.78 43.55 TT525 x T7525 XO 6112 1 4.29 11,966.31 4355 Deha425 xTT525 4-112 " 16.60 DPS, 10% Wear (378 joints) 41/2 1 11,956.94 11,962.02 4355 Delta425 x Delta425 XO 6112 1 4.12 5.08 43 55 TT525 x Delta425 5" 19.50 DPS, 10% Wear 61/2 1 0.96 43.55 TT525 x TT525 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date I Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Noce 10/12/2019 763.0 763.0 3,083.0 3,083.0 0.0 0.0 Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/1212019 198.0 198.0 792.0 792.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/12/2019 3,748.0 1,226.0 71,728.0 31,067.0 0.0 19,339.0 Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10112/2019 109.0 135.0 362.0 616.0 0.0 254.0 Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: DateConsumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 1011212019 42.0 42.0 168.0 168.0 0.0 0.0 Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/12/2019 0.0 0.0 0.0 0.0 0.0 0.0 Last Authority Visit Date I Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling 4 PJSM'S Doyon Drilling Inc. 4 HRWS Doyon Drilling Inc. 4 COW Doyon Drilling Inc. 11 Safe Cards MI Swaco 6 RIR's Ml Swaco 4 HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 1011312019 displayed Job: DRILLING Report #: 5 WCEI Level: 3 Page: 1 of 4 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code AOL -392938 ENI PETROLEUM ENI Petroleum Co Inc. DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB as. Flange (ft) RKB -Tubing Spool (ft) 53.60 13.10 16.34 37.26 31 76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON I LAND RIG 0723 9/27/2019 Daily Information End Depth (ftKB) End Depth (TVD) (RKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB MD @ Report Time (ft... TVD @ Report Time (ft... 27,169.0 4,025.1 2109.00 72.54 168.2 725.0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Cloudy 24.8 S @ 19 MPH 716.00 716.00 0.00 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) BOP Pressure Test 1 10/9/2019 10/2312019 10 Camp Evac Drill 1 10110/2019 1/8/2020 87 Rig Inspection 5 10/13/2019 10/14/2019 1 Safety Meeting 5 10/13/2019 10/14/2019 1 Spill Drill 3 10113/2019 10127/2019 14 TT H2S Drill 1 1019/2019 10/10/2019 -3 TT Kick While Drilling 1 10111/2019 10/18/2019 5 Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD(ftKB) VS (it) I NS (ft) EW (ft) DLS (°I100ft) Method 10/13/2019 21,010.86 91.31 31131 4.025.90 17446 06 16,1.42 -8,74792 2.80 MWD 10/13/2019 21,103.24 89.54 312.90 4,02521 17,541.59.1 0 16,168.35 -8,876.45 2.58 MWD 10/14/2019 21,197.13 91.23 311.87 4,024.58 17.635.36 16,231.64 -8,885.80 2.11 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) ITarget Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg OF (ft/hr) DRILLING 22,100.0 3,992.7 8,349.00 56.09 148.9 Daily Summary Operations 24h Forecast Drill Lt horizontal 8 314" hole per directional/geological plan from 21,169' to 22,104' proposed TD Circulate bottoms and back reaming out of the hole per schedule. 24h Summary Drill L1 horizontal 8 314" hole per directional/geological plan from 19,060' MD to 21,169MD (4,022' TVD). Fault D at 20,590' and back into zone at 20,837' (out of zone 247'). Operation at 07.00 Drilling Ahead @ 21,726' Lithology Shows Mud Weight (Ib/gal) 9.40 Time Log Start End Cum Dur End Depth Time Time our (hr) (hr) Phase Opr. Act. Plan Oper. Descr. (ftKB) 0000 05:30 5 50 5.50 DRILL E 3 P Directional drill 8 314" L1 lateral section from 19,060' to 19,768' (4,034' TVD) at 540 GPM, SPP 4020 PSI, 19,768,0 11.74 PPG EGD with 9.4 PPG mud, rotating 140 RPM with 15-17K TO WOB= 2-10K. UW= 190K, DW= N/A, RTW= 125K 05'30 06:00 0 50 6.00 DRILL E 11 P Monitor well -flow check due to lose rate while drilling stand down and increase flow back volume on 19,768.0 connection (breathing)- well trend down and final static 06:00 12:00 600 1200. DRILL E 3 P Directional drill 8 3/4" L1 lateral section from 19,768' to 20,466' (4.033' TVD) at 530 GPM, SPP 3940 PSI, 20,466.0 11.99 PPG ECD with 9.4 PPG mud, rotating 140 RPM with 15-19K TO WOB= 4-12K. UW= 198K, DW= NIA, RTW= 128K. 1200 18.00 6.00 18.00 DRILL E 3 P Directional drill 8 314" Lt lateral section from 20,466' to 20,832' (4,033' TVD) at 530 GPM, SPP 3900 PSI, 11.7 20,832.0 ECD with 9.4 PPG mud, rotating 140 RPM with 16-19K TO. WOB= 2-14K UW= 200K, DW= WA, RTW= 130K Observed another Fault D at 20,590 and back into zone at 20,837' (out of zone 247' in shale) 1800 0000 6,00 24.00 DRILL E 3 P Directional drill 8 3/4" L7 lateral section from 20,832' to 21,169' (4,022' TVD) at 530 GPM, SPP 3980 PSI, 21.169.0 11.72 ECD with 9 4 PPG mud, rotating 100 to 140 RPM with 16-19K TO. WOB= 2-14K. UW= 198K, DW= N/A, RTW= 128K Note Losses to hole last 24 his = -84 BBL Max gas last 24 his = 207 units and average gas 32 units 7 20.6 hours rotating / 145.4 K -rev's. Recovered 18 lbs. metal from ditch magnets - Total recovered 233.75 lbs Gas Readings Avg Background Gas I%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas I%) 32.00 207.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas M Avg Trip Gas I%) Max Trip Gas I%) 32.00 207.00 0.00 0.00 Mud Type: LVT - FazePro - 72% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis I00rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc fbf/10... Vis (s/qt) 19,478.0 9.40 53 35 28 20 8 7 18.0 17.007 55 Gel (10s) (Ibf/1... Gel (10m) (Ibf11 ... G"(30.) (Ibf/1 ... n K Filtrate (mU30... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 7.003 7.003 8.003 0.7 0.5 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (mUmL) Mf (mL/mL) Sand I%) Solids I%) H2O I%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) TOated 2.800 0.1 12.3 25.0 62.8 71.5128.5 Brine (Ib/gal) LGSM HGS I%) Barite (Ib/bbl) Chlorides (mg1L) Calcium (mg/L) Mg (mglL) Pot (mg1L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 5.8 36 69,000.000 0.000 702.0 3.6 Mud Type: LVT - FazePro - 72% OI/ Ratio Depth (ftKB) Density (lb/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibfl10... Vis (s/qt) 20,1170 9.40 53 35 28 20 8 7 18.0 17.007 56 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1 _.. Gel (30m) (Ibfl1 ... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 7.003 7.003 8.003 0.7 0.5 0.0 0 44 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (mL/mL) Mf (mUmL) Sand I%) Solids I%) H2O (%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.800 0.1 12.3 25.0 62.8 71.5/28.5 Brine (Ib/gal) LGS (%) HGS I%) Barite (Ib/bbl) Chlorides (mg1L) Calcium (mg/L) Mg (mg1L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime ib/bbl) 10.60 5.6 3.9 67,000.000 0.000 767.0 3.6 Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10/13/2019 displayed Job: DRILLING Report #: 5 WCEI Level: 3 Page: 2 of 4 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Iblgal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 20,684.0 9.40 46 31 25 17 7 6 15.0 16.007 53 Gel (10s) (Ibf/t.. Gel (10m) (Ibf/1 ... Gel (30m) (Ibf/1.. n K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.7 0.5 0.0 0 4.3 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (mL/mL) Mf (mL/mL) Sand I%) Solids (%) H2O I%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.800 0.1 12.0 24.0 64.0 72.7/27.3 Brine (Iblgal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Iblbbq 10.60 5.5 3.7 67 000.000 0.000 737.0 3.6 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Iblgal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (eP) YP Calc (Ibf/10... Vis (s/qt) 21.032.0 9.40 51 33 26 18 7 6 18.0 15.006 53 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1.. Gel (30m) (Ibfl1... n K Filtrate (mL/30... FC (1132") HTHP Filtrate I_ HTHP FC (1132") T HTHP (°F) P HTHP (psi) 7.003 7.003 7.003 0.7 0.5 0.0 0 4.4 1 150.0 500.0 PH pH Method Pm (mUmL) Pf (mUmL) Mf (mL/mL) Sand (%) Solids (%) H2O (%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) Titrated 3.100 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Ib/gal) LGS I%) HGS I%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaCl2 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.3 3.5 67.000.000 0.000 708.0 4.0 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,466.0 Loss 84.0 Tank 615.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 2,081.0 11,4660 0.0 0.0 84.0 197.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Simone Belemmi Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Ent representative Chad Gueco Eni Drilling Supv. 907-685-0726 Eni representative David Smith Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Wade Thomas Eni Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Eni representative Pat Ahern Eni HSE Eni representative Mark Hubler Eni HSE Drilling Supt Sam Dye Doyon Drilling Field Superintendent Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig 15@doyondrilling.com Tool Push Einer Fieagle Doyon Drilling Tool Push Tool Push Cliff Owens Doyon Drilling HSE cowens@doyondrilling.com 685-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyondriiling.com 685-0796 Personnel Log (POS) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note GBR Casing 12.50 0 Drilling Baker Liner Hanger 12 50 0 Drilling Rubicon Swivel 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 1250 1 SID Support Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Eni Company Man 12.50 1 Drilling Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling K&M ERD 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12 50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 1250 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling RPS Geologist 12.50 2 Drilling SLB Cement 1250 2 Drilling SLB Directional Driller 12.50 2 Drilling SLB MWD 12.50 2 Drilling Competentia Logistic 12.50 4 SID Support MI Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 10 SID Support Doyon Rig Personnel 12.50 27 Drilling_Total Drilling Personnel Worley Truck driver / Crane operator 12.50 33 Drilling BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 8/7/2019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular Hydril GK 500 13 5/8 5,000.0 5!1/2015 3 1/2 "- 6" VBR Hydril MPL 5000 13 5/8 5,000.0 8/24/2018 Blind Shear Ram Hydril MPL 5000 13 518 5,000.0 8/24!2018 4 1/2'x T' VBR Hydril MPL 5000 13 518 5,000.0 5/1!2015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 8/27/2019 6 0.113 5,323.0 Date Depth (ftKB) Slow Spit Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 10/1312019 20,981.0 Yes 22 520.0 10/13/2019 20,981.0 Yes 30 655.0 Pump Number: 2 Makes While Star Model: Quatro 2450 Selected table Well Name: SP03-NE2 L1 OR(A) Dail Report has no valid Wellbore Name: SP03-NE2 L1 y p attachments that can be Well Code: 32145 Date: 10/13/2019 displayed Job: DRILLING Report #: 5 WCEI Level: 3 Page: 3 of 4 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 8/27/2019 6 0.113 I 5.323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff I%) O Flow (gpm) 10/13/2019 20,981.0 Yes 30 TO 10/13/2019 20,981.0 Yes 22 52 Pump Number: 3 Make. National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 8/27/2019 I 6 0.102 I 4,665.0 Date Depth (ftKB) Slow Steel Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 10!13/2019 20,961.0 Yes 29 530.0 10/13/2019 20,981.0 Yes 39 660.0 Last BHA BHA # it Ran Drill String Name Comment 17 1 Steerable Bit Bit Type Make Model /ADC Codes Serial Number Size (in) Bit Dull BIT -PDC NOV TK66-AGt PDC _ A268215 8314 0 ---- Run Parameters Date In Date Out Depth In (ftKB) Depth Out (ftKB) Depth Drilled (ft) Drilling Time (hr) BHA ROP (ft1hr) Nozzles (1132") TFA (nozzles) (in') 10/10/2019 10/14/2019 12,820.0 21,169.0 8,349.00 56.09 148.9 14114/14/14/14114 0.90 WOB (Min.) (10001be) WOB (Max.) (10001bf) Min RPM (rpm) Max RPM (rpm) Min Flow Rate (gpm) Max Flow Rate (gpm) SPP Min (psi) SPP Max (psi) a 15 140 140 530 550 3,660.0 3,980.0 Daily Parameters Start Depth Int Depth Cum Depth Drill Time Cum Drill Int ROP WOB Q Flow Motor RPM Bit RPM Rot Time Slide Time Start Date (ftKB) (ft) I (ft) (hr) I Time (hr) (ftlhr) (10001bf) (gpm) RPM (rpm) (rpm) (rpm) SPP (psi) (hr) (hr) 10110/2019 12,820.0 1.627.00 1,627.00 12.69 12.69 128.2 8 550 140 0 140 3,660.0 12.69 0.00 10/11/2019 14,447 0 2.427 00 4,054.00 16.14 28.83 150.4 14 550 140 0 140 3,820.0 16.14 0.00 10/12/2019 16,874.0 2,186.00 6,240.00 14.72 43.55 148.5 15 540 140 0 140 3,910.0 1472 0.00 10/13/2019 19,0600 2,109.00 8,349.00 12.54 56.09 168.2 14 530 140 0 140 3,980.0 12.54 0.00 Torque & Drag parameters Start Date Drill Str Wt If 0001bf) PU Sh Wt (10001bf) SO Str Wt (10001bf) Drill Tq Off Burt Tq Tq Units 10/10/2019 130 170 75 14.0 10.0 Ibs.ft 10/11/2019 127 172 0 18.0 12.0 IbsM 10/12/2019 126 178 0 19.0 12.0 Ibs.it 10/13/2019 128 198 0 19.0 13.5 Ibs.ft BHA Components Item Desc. OD (in) Jts Len (ft) Cum Len (ft) End Hrs (hr) Connections 8 75" POC TK66 6 1 0.94 12,398.30 56.09 REG x REG Xceed 675 8 5/8" Stab (W dummy float #nosn) 63/4 1 25.01 12,397.36 56.09 FH x FH Periscope 675 GR/RES/DHAT/DHAP 63/4 1 19.45 12,372.35 56.09 FH x FH 8 3/8" Inline Stabilizer 6718 1 4.99 12,352.90 56.09 FH x FH Telescope 675 NF 6 718 1 25.86 12,347.91 56.09 FH x FH 8 114" NM Stabilizer 6 718 1 27.84 12,322.05 5609 NC50 (4 1/2 IF) x NC50 (4 112 IF) 6 3/4" Flex NM Collar 67/8 1 30.48 12,294.21 5609 NC50 (4 1/2 IF) x NC50 (4 1/2 IF) Float Sub 67/8 2.51 12,263.73 56.09 FH x FH WCMD wl Ball Catcher 67/8 1 12.68 12,261.22 56.09 NC50 (4 112 IF) x NC50 (4 1/2 IF) XO 6 718 1 3.17 12,248.54 5609 TT525 x NC50 (4 1/2 Heavy Weight Drill Pipe (3 joints) 67/8 3 92.86 12,245.37 56.09 TT525 x TT525 6 112"Drilling Jars 6 112 1 31.27 12,152.51 5609 TT525 x TT525 Heavy Weight Drill Pipe (2 joints) 5 2 61.83 12,121.24 56.09 TT525 x TI -525 DACCH Accel. AP 61/2 1 31.63 12,059.41 56.09 TT525 x TT525 Heavy Weight Drill Pipe (2 joints) 65/8 2 61 47 12,027.78 56.09 TT525 x TT525 XO 6112 1 4.29 11,966.31 56.09 Deita425 xTT525 4-1/2"16.60 DPS, 101Y. Wear (378 joints) 41/2 1 11,956.94 11,962.02 56.09 Delta425 x Delta425 XO 61/2 1 4 12 5.08 56.09 TT525 x Detta425 5" 19.50 DPS, 10% Wear 6 112 1 0.96 56.09 TT525 x TT525 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/13/2019 1,041.0 1,041.0 4,124.0 4,124.0 0.0 0.0 Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cu. Received Cum Returned Cum On Loc Note 10/13/2019 198.0 1980. 990.0 990.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/13/2019 3,631.0 1,240.0 15,359.0 32,307.0 0.0 16,948.0 Supply Item Description: Rig Water Unit Label: bbl .Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/1312019 66.0 135.0 428.0 751.0 0.0 323.0 Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date lConsurned Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10113/2019 42.0 42.0 210.0 210.0 0.0 0.0 Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/13/2019 0.0 0.0 0.0 0.0 0.0 0.0 Last Authority Visit Date Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling 2 PJSM'S Doyon Drilling Inc. 13 Safe Cards Doyon Drilling Inc. 2 COW Doyon Drilling Inc. 2 HRWS MI Swaco 8 RIR's Ml Swaco 6 HARC/JSA Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/13/2019 Report #: 5 Page: 4 of 4 Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10/14/2019 displayed Job: DRILLING Report #: 6 WCEI Level: 3 Page: 1 of 4 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) Firs[ Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.60 13.10 16.34 37.26 31 76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 9/27/2019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (fUhr) POB MD @Report Time (ft... TVD @Report Time (k... 22,110.0 4,000.4 941.00 6.45 145.9 107.0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Clear 32.0 E @ 15 MPH 717.00 717.00 0.00 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause I Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) BOP Pressure Test 1 10/9/2019 1OM/2019 9 Camp Evac Drill 1 10/10/2019 1/8/2020 86 Fire Drill 1 10/14/2019 10/28/2019 14 Rig Inspection 6 10/14/2019 10/15/2019 1 Safety Meeting 6 101102019 1011512019 1 Spill Drill 3 10/13/2019 10/27/2019 13 TT Camp Evac Drill 1 10/14/2019 1/12/2020 90 TT H2S Drill 1 10/9/2019 10/10/2019 -4 TT Kick While Drilling 1 10/11/2019 10/18/2019 4 Survey Data Date MD (ftK8) Incl (°) Azm (°) TVD (ftK8) VS (ft) NS (ft) EW (ft) DLS (°/100ft) Method 10114/2019 21,94377 90.68 319.96 4,001.65 18,408.55 16,76779 -9,403.36 1.74 MWD 10/14/2019 22,037.07 90.32 319.65 4,000.84 18,50136 16,839.05 -9,463.57 0.51 MWD 10/14/2019 22,11000 90.32 319.65 4,000.43 18,573.93 16,894.63 -9,510.79 0.00 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft... Depth Dc (MD) (ft) Drilling Time (hr) Avg ROP (fUhr) DRILLING 22,100.0 3,992.7 9,290.00 62.54 148.5 Daily Summary Operations 24h Forecast Back ream out of hole as per schedule. 24h Summary Drill L1 horizontal 8 3/4" hole per directional/geological plan from 21,169' MD to well TD at 22,110' MD (4,000' ND) Cross Fault E at 20,837 Performed clean-up cycle of two bottoms -up from 22,110' to 21,851 , continue back ream at 15-20 k./min or as condition allowed to 20,339' Operation at 07.00 BROOH @ 19,432' Lithology Shows Mud Weight (Iblgal) 9.40 Time Log Start End Cum Dur End Depth Time Time Dur (hr) (hr) Phase Opr. Act. Plan Oper. Descr. (ftKB) 0000 06.00 6.00 6.00 DRILL E 3 P Directional drill 8 314" L1 lateral section from 21,169' to 21,635' (4,009' TVD) at 530 GPM, SPP 4080 PSI. 21,635.0 11.93 PPG ECD with 9.4 PPG mud, rotating 140 RPM with 16-19K TO WOB= 4-14K UW= 198K, DW= N/A, RTW= 127K 0600 1030 4.50 10.50 DRILL E 3 P Directional drill 8 3/4" L1 lateral section from 21,635' to well TD at 21,110' (4,000' TVD) at 530 GPM, SPP 22.110.0 4000 PSI, 11.85 PPG ECD with 9.4 PPG mud, rotating 140 RPM with 17-19K TO WOB= 4-T1K. UW= 192K, DW= WA, RTW= 125K 10:30 11'00 0.50 11.00 DRILL E 9 PEstablish slow pump rates and flow check - static. 22,110.0 11'00 14,30 3.50 14.50 DRILL E 4 P Circulate clean-up cycle while back reaming 1-2 ft./min. (one stand per hour) from 22,110' to 21,851' (4,004 22,110.0 TVD) at 530 GPM, SPP 3900 PSI, 11.57 ECD with 9.4 PPG mud, rotating 120 RPM with 14-16K TO RTW= 130K 1430 18:00 3.50 18.00 DRILL E 4 P Back ream speed of 15-20 Ill from 21.851' 19 20,905' (4,027' TVD) at 530 GPM, SPP 3900 PSI, 11.8 ECD 22,110.0 with 9.4 PPG mud, rotating 120 RPM with 14-16K TO. RTW= 130K 1800 0000 6.00 24.00 DRILL E 4 P Back ream speed of 15-20 ft /min from 20,905' to 20,339 (4,031' TVD) at 530 GPM, SPP 3900 PSI, 11.77 22,110.0 ECD with 9.4 PPG mud, rotating 120 RPM with 14-16K TO RTW= 130K Speed as hole condition allow to prevent pack -off. Note Losses to hole last 24 him = -100 BBL Max gas last 24 hrs: 150 units and average gas 16 units 121.2 hours rotating / 140.4 K -rev's Recovered 6 lbs metal from ditch magnets - Total recovered 239 75 lbs Gas Readings Avg Background Gas I%) Max Background Gas I%) Avg connection Gas (%)Max Connection Gas I%) 16.00 1 150.00 10.00 lom Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas I%) 16.00 150.00 0.00 0.00 Mud Type: LVT - FazePro - 73% 011 Ratio Depth (ftKB) Density (lb/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Catc (Ibf/10.-, Vis (s/qt) 21,351.0 9.40 53 35 27 19 7 6 18.0 17.007 53 Gel (10s) (Ibf/1 ... Gel (10m) (Ibf/1 .. Gel (30m) (Ibf/1 _. n K Filtrate (mL/30... FC (1132") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 7.003 7.003 7.003 0.7 0.5 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (.UmL) Pf (mL/mL) Mf (mL/m L) Sand (%) Solids (%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Tirated 3.100 0.1 12.5 24.0 63.5 72.6127.4 Brine (Ib/gal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (1b/bbl) 10.60 6.3 3.4 67,500.000 0.000 30 712.0 4.0 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf110... Vis (s/qt) 21,950.0 9.40 52 34 25 18 7 6 18.0 16.007 53 Gel (10s) (Ibf/1. Gel (tom) (Ibfil... Gel (30m) (Ibf11 ... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 7.003 7.003 7.003 0.7 0.5 0.0 0 4,4 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (m L/mL) Mf (mL/mL) Sand I%) Solids (%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (Iblbbl) Tirated 3.000 0.1 12.5 24.0 63.5 72 6127.4 Brine (Ib/gal) L G S (%) HGS I%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/l.) Mg (mg1L) Pot (mglL) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.3 3.5 67,000.000 0.000 30 717.0 19 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/1412019 Report #: 6 Page: 2 of 4 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (I1:4/10... Vis (s/qt) 22,110.0 9.40 49 32 23 17 7 6 170 15.006 53 Gel (10s) (Ibflt... Gel (10m) (I1,411 .. Gel (30m) (Ibf/1... n K Filtrate (ml/30... FC (1132') HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6 002 6.002 7.003 0.7 0.5 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (mLlm L) Mf (mL/mL) Sand (%) Solids I%) H2O I%) Percent Oil I%) Oil Water Ratio MET (Ib/bbl) Titrated 2.900 0.1 12.5 24.0 63.5 72.6127.4 Brine (Ib/gal) LGS I%) HGS (%) Barite (blbbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg1L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Iblbbl) 10.60 6.2 3.6 66,000.000 0.000 30 712.0 3.8 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibfl10... Vis (s/qt) 22,110.0 9.40 49 32 25 17 7 6 17.0 15.006 52 Gel (10s) (Ibf/1... Gel (10m) (Ibfl1... Gel (3om) (IIA/l... n K Filtrate (mU30... FC (1132') HTHP Filtrate (... HTHP FC (1/32') T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.7 0.5 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (mL/mL) Mf (mL/mL) Sand I%) Solids I%) H2O I%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.800 0.1 12.5 24.0 63.5 72.6127.4 Brine (Ib/gal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg1L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Iblbbl) 10.60 6.3 3.5 67,000.000 0.000 30 702.0 3.6 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,542.6 Loss 100.0 Tank 705.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 2,247,6 1,542.6 0.0 0.0 100.0 297.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Ent representative Simone Belemmi Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Chad Gueco Eni Drilling Supv. 907-685-0726 Eni representative David Smith Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Wade Thomas Eni Rig Clerk AKRigClerksDoyonl 5@eni.com 907-685-0722 Eni representative Pat Ahern Eni HSE Ent representative Mark Hubler Eni HSE Drilling Supt Sam Dye Doyon Drilling Field Superintendent Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com Toot Push Einer Fleagle Doyon Drilling Tool Push Tool Push Cliff Owens Doyon Drilling HSE cowens@doyondrilling.com 665-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyondrilling.com 685-0796 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note GBR Casing 12.50 0 Drilling Baker Liner Hanger 12.50 0 Drilling Rubicon Swivel 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Eni Company Man 12.50 1 Drilling Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling K&M ERD 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swam Mud Engineer 12.50 2 Drilling RPS Geologist 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB Directional Driller 12.50 2 Drilling SLB MWD 12.50 2 Drilling Competentia Logistic 12 50 4 SID Support MI Swam Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swam WIF 12.50 8 SID Support ESS Catering 12.50 10 SID Support Worley Truck driver 7 Crane operator 12.50 18 Drilling Doyon Rig Personnel 12.50 24 Drilling_Total Drilling Personnel BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 8/7/2019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi)r Cert Date Annular Hydril 500 13 516 5,000.0 3 112 "- 6"VBR Hydril MPL 5000 13 518 5,000.0 Blind Shear Ram Hydril �GK MPL 5000 13 518 5,000.04 112' x T' VBR Hydril MPL 5000 13 5/8 5,000.0 Slow Circulation Rates Pump Number- 1 Make: White Star Model: Quatro 2450 Start Date End DateLiner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 8/27/2019 6 0.113 5, 323.0 Date Depth (ftKB) Slow Spit Strokes (spm) P (psi) Eff I%) O Flow (gpm) 10/14/2019 22,110.0 Ves 22 450.0 10/74/2019 22,110.0 Yes 30 590.0 Pump Number: 2 Make- White Star Model: Quatro 2450 Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10/14/2019 displayed Job: DRILLING Report #: 6 WCEI Level: 3 Page: 3 of 4 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 8/27/2019 6 0.113 5,323.0 Date Depth (ftKB) Slow Sled Strokes (spm) P (psi) Eff 1%) Q Flow (gpm) 10/14/2019 22,110.0 Yes 22 460.0 10/1412019 22,110.0 Yes 30 600-0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 827/2019 6 0.102 4,665.0 Date Depth (ftKB) Slow Sind Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 1011412019 22,110.0 Yes 29 450.0 10/1412019 Yes 39 600.0 Last BHA BHA # Bit Run Drill String Name Comment 17 1 Steerable I Bit Bit TypeMake Model /ADC Codes Serial Number Size (in) Bit Dull BIT -PDC NOV TK66-AG1 PDC _ A268215 83/4 0--- Run Parameters Date to Date Out Depth In (ftKB) Depth Out (ftKB) Depth Drilled (ft) Drilling Time (hr) BHA ROP (ftfhr) Nozzles (1132") TFA (nozzles) (int) 10/10/2019 10/15/2079 12,820.0 22,1100 9,290.00 62.54 148.5 74/14/14714/14/14 0.90 WOB (Min.) (10001bf) WO13(Max.) (10001bf) Min RPM (rpm) Max RPM (rpm) Min Flow Rate (gpmj Max Flow Rate (gpm) 5PP Min (psi) SPP Max (psi) 8 15 140 140 530 550 I 3,660.0 4,080.0 Daily Parameters Start Depth Int Depth Cum Depth Drill Time Cum Drill Int ROP WOB Q Flow Motor RPM Bit RPMRot Time Slide Time Start Date (ftKB) (ft) (ft) (hr) Time (hr) (ft/hr) (10001bf) (gpm) RPM (rpm) (rpm) (rpm) SPP (psi) (hr) (hr) 10/10/2019 12,820.0 1,627.00 1,627.00 12.69 12.69 128.2 8 550 140 0 140 3,660.0 12.69 000 1011112019 14,447.0 2,427.00 4,054.00 16.14 2883 150.4 14 550 140 0 140 3,820.0 1614 0,00 10/12/2019 16,874.0 2,186.00 6,240.00 14.72 4355 148.5 15 540 140 0 140 3,910.0 14.72 0.00 10/1312019 19,060.0 2,109.00 8,349.00 12.54 56.09 168.2 14 530 140 0 140 3,980.0 12.54 0.00 10/14/2019 21,169.0 941.00 9,290.00 6.45 62.54 145.9 12 530 140 0 140 4,080.0 6.45 0.00 Torque & Drag parameters Start Date Drill Str Wt (10001bf) PU Sir Wt (10001bf) SO Sir Wt (10001bf) Drill Tq Off Bt. Tq Tq Units 10/10/2019 130 170 75 14.0 10.0 Ibs.ft 10/11/2019 127 172 0 18.0 12.0 Ibs.ft 10/12/2019 126 178 0 19.0 12.0 Ibs.ft 10113/2019 128 198 0 19.0 13.5 Ibs.ft 10/14/2019 125 192 0 19.0 14.0 Ibs.ft BHA Components Item Des.. OD (in) Jts Len (ft) Cum Len (ft) End Hrs (hr) Connections 8,75" PDC TK66 6 1 0.94 12.398.30 62.54 REG x REG XCeed 675 8 5/8" Stab (W dummy float #nosn) 63/4 1 25.01 12,397.36 62.54 FH x FH Periscope 675 GR/RES/DRAT/DHAP 63/4 1 19.45 12,372.35 62.54 FH x FH 8 318" Inline Stabilizer 67/8 1 499 12,352.90 62.54 FH x FH Telescope 675 NF 67/8 1 25.86 12,347.91 62.54 FH x FH 8 114" NM Stabilizer 67/8 1 2784 12,322.05 62.54 NC50 (4 112 IF) x NG50 (4 1/2 IF) 6 3/4" Flex NM Collar 67/8 1 30.48 12,294.21 62.54 NC50 (4 1/2 IF) x NC50 (4 12 IF) Float Sub 6 7/8 2.51 12,263.73 6254 FH x FH WCMD w/ Ball Catcher 67/8 1 12.68 12,2612-2 62,54 NC50 (4 1/2 IF) x NC50 (4 12 IF) XO 67/8 1 3.17 12,248.54 62.54 TT525 x NC50 (4 12 Heavy Weight Drill Pipe (3 Joints) 67/8 3 92.86 12,245.37 62.54 TT525 x TT525 6 1/2" Drilling Jars 61/2 1 31.27 12,152.51 62.54 TT525 xTT525 Heavy Weight Drill Pipe (2 joints) 5 2 61 83 12,121.24 6254 TT525 x TT525 DACCH Accel AP 61/2 1 31.63 12,059.41 62.54 TT525 x2"2"525 Heavy Weight Drill Pipe (2 joints) 6 518 2 61.47 12,027 78 62.54 TT525 x TT525 X0 61/2 1 4.29 11,966.31 62.54 Delta425 x TT525 4-1/2" 16.60 DPS, 10% Wear (378 joints) 41/2 1 11,956.94 11,962.02 62.54 Delta425 x Delta425 XO 6 112 1 4 12 5.08 62.54 TT525 x Delta425 5" 19.50 DPS, 10% Wear 61/2 1 0.96 62.54 TT525 x TT525 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/14/2019 1.403.0 1,403.0 5,527.0 5,5270 0.0 0.0 Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10114/2019 798.0 198.0 1,186.0 1,188.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date lConsumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/14/2019 3,614.0 1,299.0 18,973.0 33,606.0 0.0 14,633.0 Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/14/2019 77.0 0.0 505.0 751.0 0.0 246.0 Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/14/2019 42.0 42.0 252.0 252.0 0.0 1 0.0 Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 70/1412019 0.0 0.0 0.0 0.0 0.0 0.0 Last Authority Visit Date Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling 2 SMIS Doyon Drilling Inc. 2 HWS Doyon Drilling Inc. �Pj 2 COW Doyon Drilling Inc. 13 Safe Cards Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/14/2019 Report M 6 Page: 4 of 4 STOP Cards Submitted Company # Rpts Com MI Swaco Ml Swaco 8 6 RIR's HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/1512019 Report #: 7 Page: 1 of 4 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.60 1310 16.34 37.26 31 76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON I LAND RIG 0723 9/272019 Daily Information End Depth (ftKB)End Depth (TVD) (RKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB MD @ Report Time (ft... TVD @ Report Time (ft... 22.110 0 4,000.4 0.00 107.0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Overcast 32.0 NE @ 38 MPH 718.00 I 718.00 0.00 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause I Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) BOP Pressure Test 1 10/9/2019 10/2312019 8 Camp Evac Drill 1 10/102019 1/8/2020 85 Fire Drill 1 10/142019 102812019 13 Rig Inspection 7 10/15/2019 10/16/2019 1 Safely Meeting 7 10/1512019 10/16/2019 1 Spill Drill 3 10/1312019 1027/2019 12 TT Camp Evac Drill 1 10/1412019 1/12/2020 89 TT H2S Drill 1 10/9/2019 10/1012019 -5 TT Kick While Drilling 1 10/11/2019 10/18/2019 3 TT Kick While Tripping 1 10/15/2019 10/22/2019 7 Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD (RKB) VS (ft) I NS (ft) EW (ft) DLS (°/100ft) Method 70!15/2019 21,943.77 90.66 319.96 4,W1.65 18,408.55 16,767.79 -9,403.36 1.74 MWD 10/15/2019 22,037.07 90.32 319.65 4,000.84 i8,50t36 16,839.05 -9,463.57 0.51 MWD 10/15/2019 22,110.00 90.32 319.65 400043 18,573.93 16,894.63 -9,51079 0.00 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (ftlhr) DRILLING I 22,100.0 3,992.7 9,290.00 62.54 148.5 Daily Summary Operations 24h Forecast Back ream out 14,735' to 13 360' and circulate bottoms -up, stop rotation and pump through window section Start back ream to 12,400' and change saver sub to 4-1/2° Delta 425, continue back ream to 1,900' and pull out of hole on elevators L/D BHA #17. 24h Summary Back ream out of the L1 horizontal 8 314° hole section per schedule of 2-20 ft./min while continuously monitoring pump pressure, ECD's and torque levels for hole condition from 20,339' to 14,735'. Operation at 07.00 BROOH @ 13.938' Lithology Shows Mud Weight (lb/gal) 9.40 Time Log Start End Cum our End Depth Time Time Dur (hr) (hr) Phase Opr. Act. Plan Oper. Descr. (RKB) 00:00 0600 6.00 6.00 DRILL E 4 P Back ream speed of 1-10 ft./min from 20,339' to 19,640' (4,027' TVD) at 540 GPM, SPP 4000 PSI, ECD rated 22,110.0 from 11 42 to 11.89 ppg with 9.4 PPG mud, rotating 120 RPM with 14-18K TO RTW= 120K Back reaming speed varied as hole condition allow to prevent pack -off - 06:00 1200 6.00 12.00 DRILL E 4 P Back ream speed of 2-15t./min from 19,640' to 18,330'(4,036' TVD) at 550 GPM, SPP 3950 PSI, ECD rated 22,110.0 from 11.23 to 11 68 ppg with 9.4 PPG mud, rotating 120 RPM with 13-15K To. RTW= 115K. 12:00 1800 6.00 18.00 DRILL E 4 P Back ream speed of 2-15t./min from 18,330'to 16,907' (4,045' TVD) at 550 GPM, SPP 3800 PSI, ECD rated 22,110.0 from 11.04 to 11.59 ppg with 9 4 PPG mud. rotating 120 RPM with 11-13K TO. RTW= 120K 1800 0000 6.00 24.00 DRILL E 4 P Back ream speed of 4-18 ft.rmin from 16,907' to 14,735' (4,069 TVD) at 550 GPM, SPP 3550 PSI, ECD rated 22,110.0 from 10.66 to 10.89 ppg with 9.4 PPG mud, rotating 120 RPM with 11 K TO. RTW= 120K Note Losses to hole last 24 his. = -105 BBL. Max gas last 24 hrs = 26 units and average gas 10 units 120.1 hours rotating 1116 7 K -rev's. Recovered 10 lbs. metal from ditch magnets - Total recovered 249.75 lbs. Gas Readings Avg Background Gas I%) Max Background Gas (%) Avg Connection Gas I%) Max Connection Gas (%) 10.00 26.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas I%) Max Trip Gas I%) 0.00 0.00 0.00 0.00 Mud Type_ LVT - FazePRo - 72% Oil Ratio Depth (RKB) Density (ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (CP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.40 50 32 26 18 7 6 18.0 14.006 52 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1 .. Gel (30m) (Ibf/1... n K Filtrate (mL/30.., FC (1/32") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.7 0A 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (mL/mL) Mf (mVmL) Sand I%) Solids I%) H2O (%) Percent Oil I%) oil Water Ratio MBT (Ib/bbl) Titrated 3.000 0.1 12.3 24.3 63.5 72.4127.6 Brine (Ib/gal) LGS I%) HGS I%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.4 3.1 1 66,000.000 0.000 30 688.0 3.9 Mud Type: LVT - FazePro - 73%01IRatio Depth (RKB) Density (ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (CP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.40 48 31 24 17 7 6 17.0 14.006 52 Gel (10s) (Ibf/1... Get (tom) (I1of/1.. Gel (30m) (Ibf/1.. n K Filtrate (m-130... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 07 0.4 0.0 0 4.3 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (mL/mL) Mf (mUmt-) Sand (%) Solids (%) H20(%) Percent Oil I%) Oil Water Ratio MBT (lb/bbl) Titrated 3.000 0.1 12.0 24.0 64.0 72.7/27.3 Brine (Ib/gap LGS M HGS (%) Barite ftblbbp Chlorides mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime fb/bbl) 10.60 16.1 3.2 66,200.000 0.000 30 1741.0 19 Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10/15/2019 displayed Job: DRILLING Report #: 7 WCEI Level: 3 Page: 2 of 4 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftK6) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (lbf110... Vis (s/qt) 22,110.0 9.40 49 32 25 18 7 6 170 15.006 53 Gel (10s) (Ibf/1... Gel (10m) (74f/1... Gel (30m) (Ibf11... n K Filtrate (mL/30... FC (1132") HTHP Filtrate (... HTHP FC (1/32") T HTHP ("F) P HTHP (psi) 6.002 6.002 7.003 0.7 0.4 0.0 0 4.3 1 150.0 500.0 FH pH Method Pm (mL/mL) Pf (mLlmL) Mf (m L/m L) Sand (%) Solids I%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (Iblbbl) Titrated 3.000 0.1 12.0 24.0 64.0 72.7/27.3 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Iblbbl) 10.60 6.1 3.2 66,500.000 0.000 30 739.0 3.9 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftK6) Density (Ibigat) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (lbf/10... Vis (s/qt) 22,110.0 9.40 50 32 25 17 7 6 18.0 14,006 52 Gel (10s) (Ibf/1... Gel (10m) (Ibftt... Gel (30m) (Ibf/1... in K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0 7 0.4 0.0 0 4.4 1 150.0 500.0 PH pH Method Pm (mL/mL) Pf (mL/mL) Mf (mL/mL) Sand (%) Solids (%) H2O (%) Percent Oil I%) Oil Water Ratio MST (Ib/bbl) Titrated 2.900 0.1 12.3 24.0 63.8 72.6/27.4 Brine (Ib/gal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mglL) Pot (mglL) CaC12 (ppm) Electric Stab (V) Ex. Lime (Iblbbl) 10.60 6.2 3.3 67,000.000 0.000 30 684.0 3.8 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,579-3 Loss 105.0 Tank 750.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 2,329.3 1,579.3 0.0 0.0 105.0 402.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Simone Belemmi Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Chad Gueco Eni Drilling Supv. 907-685-0726 Ent representative David Smith Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Wade Thomas Eni Rig Clerk AKRigClerksDoyonl 5@eni.com 907-685-0722 Eni representative Pat Ahem Em HSE Eni representative Robert Gonzolez Em HSE Drilling Supt Sam Dye Doyon Drilling Field Superintendent Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rigl5@doyondrilling.com Tool Push Einer Fleagle Doyon Drilling Tool Push Tool Push Cliff Owens Doyon Drilling HSE cowens@doyondrilling.com 685-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyondrilling.com 685-0796 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note GBR Casing 12.50 0 Drilling Baker Liner Hanger 12.50 0 Drilling Rubicon Swivel 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Em Company Man 12.50 1 Drilling Northern 011feild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling K&M ERD 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling RPS Geologist 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB Directional Driller 12.50 2 Drilling SLB MWD 12.50 2 Drilling Competentia Logistic 12.50 4 SID Support MI Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 10 SID Support Worley Truck driver / Crane operator 12.50 18 Drilling Doyon Rig Personnel 12.50 24 Drilling_Tolal Drilling Personnel BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 8/7/2019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) 11 Last Cert Date Annular Hydril GK 500 13 518 5,000.0 511/2015 3 112 "- 6" VBR Hydril MPL 5000 13 5/8 5,000.0 8/2412018 Blind Shear Ram Hydrii MPL 5000 13 5/8 5,000.0 8/24/2018 4 1/2" x 7" VBR Hydril MPL 5000 13 5/8 5,000.0 5/1/2015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End DateLiner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 8/27/2019 6 0.113 5,323.0 Date Depth (ftK6) Slow Spd Strokes (spm) P (psi) Eff (%) O Flow (gpm) 10/1412019 22,110.0 Yes 22 450.0 10/14/2019 22.110.0 Yes 30 590.0 Pump Number: 2 Make: White Star Model: Quatro 2450 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 Daily Report attachments that can be Well Code: 32145 Date: 10/15/2019 displayed Job: DRILLING Report #: 7 WCEI Level: 3 Page: 3 of 4 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 8/27/2019 6 0.113 I 5, 323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff 1%) 0 Flow (gpm) 10/14/2019 22,110.0 Yes 22 460.0 10/14/2019 22,110.0 Yes 30 600.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 8/27/2019 6 0.102 4,665.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (!) Q Flow (gpm) 10/14/2019 22,110.0 Yes 29 450.0 10/14/2019 Yes 39 600.0 Last BHA BHA # Bi[ Run Drill String Name Comment 17 i Steerable I Bit Bit Type Make Model IADC Codes Serial Number Size (in) Bit Dull BIT -PDC NOV TK66-AGI PDC _ A268215 8 3!4 0 --- Run Parameters Date In Date Out Depth In (ftKB) Depth Out (ftKB) Depth Drilled (ft) Drilling Time (hr) BHA ROP (ft/hr) Nozzles (1132") TFA (nozzles) (in') 10/10/2019 10/15/2019 12,820.0 22,110.0 9,290.00 62 54 148.5 14114/14/14114/14 0.90 WOB (Min.) (10001bf) WOB (Max.) (t0001bf) Min RPM (rpm) Max RPM (rpm) Min Flow Rate (gpm) Max Flow Rate (gpm) SPP Min (psi) SPP Max (psi) 8 15 140 140 530 I 550 3,660.0 4,080.0 Daily Parameters Start Depth Int Depth Cum Depth Drill Time Cum Drill Int ROP WOB 0 Flow Motor RPM Bit RPM Rot Time Slide Time Start Date (ftKB) (ft) (ft) (hr) Time (hr) (ft/hr) (10001bf) (gpm) RPM (rpm) (rpm) (rpm) SPP (psi) (hr) (hr) 10/10/2019 12,820.0 1,627.00 1,627.00 12.69 12.69 128.2 8 550 140 0 140 3,660.0 12.69 0.00 10/11/2019 14,447.0 2,42700 4,054.00 16.14 28.83 150.4 14 550 140 0 140 3,820.0 16.14 0.00 10/12/2019 16,8740 2,186.00 6,240.00 14.72 43.55 148.5 15 540 140 0 140 3,910.0 14.72 0.00 10/13/2019 19,060.0 2,109.00 8,349.00 12.54 56.09 168.2 14 530 140 0 140 3,980.0 12.54 0.00 10/14/2019 21,169.0 941.00 9,290.00 6.45 62.54 145.9 12 530 140 0 140 4,060.0 6.45 0.00 Torque & Drag parameters Start Date Drill Str Wt (10001bf) PU Str Wt (10001bf) SO Str Wt (10001bf) Drill Tq Off Born Tq Tq Units 10/10/2019 130 170 75 14.0 10.0 Ibs.ft 10/1112019 127 172 0 18.0 12.0 Ibs.ft 10/12/2019 126 178 0 19.0 12.0 Ibs.ft 10/13/2019 128 198 0 19.0 13.5 Ibs.ft 10/14/2019 125 192 0 19.0 14.0 lbs If BHA Components Item Desc. OD (in) Jts Len (ft) Cum Len (ft) End Firs (hr) Connections 8 75" PDC TK66 6 1 094 12,398.30 62 54 REG x REG Xceed 675 8 518" Stab (W dummy float #nosn) 6 314 1 25.01 12,397.36 62.54 FH x FH Pedscope 675 GR/RES/DRAT/DHAP 6 314 1 19.45 12,372.35 62.54 FH x FH 8 318" Inline Stabilizer 67/8 1 4.99 12,352.90 62.54 FH x FH Telescope 675 NF 67/8 1 25.86 12,347.91 6264 FH x FH 8 114" NM Stabilizer 6 718 1 27.84 12,322.05 62.54 NC50 (4 1/2 IF) x NC50 (4 112 IF) 6 3/4" Flex NM Collar 67/8 1 30.48 12,294.21 6254 NC50 (4 1/2 IF) x NG50 (4 112 IF) Float Sub 67/8 2.51 12,263.73 62.54 FH x FH WCMD wl Ball Catcher 67/8 1 12.68 12,261 22 62.54 NC50 (4 112 IF) x NC50 (4 1/2 IF) X0 67/8 1 3.17 12,248.54 62.54 TT525 x NC50 (4 1/2 Heavy Weight Drill Pipe (3 joints) 6 718 3 92.86 12,245.37 62.54 TT525 x TT525 6 1/2" Drilling Jars 61/2 1 31.27 12,152.51 62.54 TT525 x TT525 Heavy Weight Drill Pipe (2 joints) 5 2 61.83 12,121.24 6254 TT525 x TT525 DACCH AcceI. AP 61/2 1 31.63 12,059.41 62.54 TT525 xTf525 Heavy Weight Drill Pipe (2 joints) 65/8 2 61 47 12,027.78 62.54 TT525 x TT525 X0 61/2 1 4.29 11,966.31 62.54 Delta425 x TT525 4-1/2" 16.60 DPS, 10% Wear (378 joints) 41/2 1 11,956.94 11,962.02 6254 Delta425 x Delta425 X0 61/2 1 4.12 5.08 62.54 TT525 x Delta425 5" 19.50 DPS, 10% Wear 6 12 1 0.96 62.54 TT525 x TT525 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Gum Received Cum Returned Cum On Loc Note 10/15/2019 1,185.0 1,185.0 6,712.0 6,712.0 0.0 0.0 Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date lConsurned Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/15/2019 198.0 198.0 1,386.0 1,386.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/15/2019 3.428.0 1,086.0 I 22,401.0 34,692.0 0.0 12,291.0 Supply Item Description: Rig Water Unit Label: bbi Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed CUm Received Cum Returned Cum On Loc Note 10/1512019 84.0 135.0 589.0 886.0 0.0 297.0 Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/15/2019 42.0 42.0 294.0 294.0 0.0 0.0 Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/15/2019 0.0 0.0 0.0 0.0 0.0 0.0 Last Authority Visit Date I Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling 3 PJSM'S Doyon Drilling Inc. 9 Safe Cards Doyon Drilling Inc. 3 Cow Doyon Drilling Inc. 3 1 HRWS Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments Date: 10/15/2019 that can be Well Code: 32145 displayed Job: DRILLING Report #: 7 WCEI Level: 3 Page: 4 of 4 STOP Cards Submitted Company # Rpts Com MI Swaco Ml Swaco 8 6 RIR's HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 L1 DR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/16/2019 Report #: 8 Page: 1 of 3 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RI - Base Flange (ft) RKB -Tubing Spool (ft) 53.60 13.10 16.34 37.26 31.76 Rigs Rig Name ContractorRig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 9/2712019 Daily Information End Depth (ftKB) I End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB MD @ Report Time (ft... TVD @ Report Time (ft... 22,110.0 4,000.4 I 0.00 111.0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Cloudy 336 ENE @ 40 MPH 719.00 719.00 0.00 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Accumulator Drill 1 10/16/2019 10/30/2019 14 BOP Pressure Test 1 10/9/2019 1023/2019 7 Camp Evac Drill 1 10/10/2019 1/812020 84 Fire Drill 1 10/14/2019 10/28/2019 12 Rig Inspection 8 10/16/2019 10/17/2019 1 Safety Meeting 8 10/16/2019 10/17/2019 1 Spill Drill 4 10/162019 10/30/2019 14 TT Camp Evac Drill 1 10/142019 1/122020 88 TT H2S Drill 1 10/9/2019 10/10/2019 -6 TT Kick While Drilling 1 10/11/2019 10/18/2019 2 TT Kick While Tripping 1 10/15/2019 10/22/2019 6 Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD (ftKB) VS (ft) I NS (ft) EW (ft) DLS (°/100ft) Method 10/1512019 21,943 77 90.68 319.96 4,001.65 18,408 55 16,767.79 -9,403 36 1.74 MWD 10/15/2019 22,03707 90.32 319.65 4,00084 18,501.36 16,839.05 -9,463.57 0.51 MWD 10/15/2019 22,110.00 90.32 319.65 4,000.43 18,573.93 16,894.63 -9,510.79 0.00 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft.., Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (ft/hr) DRILLING I 22,100.0 3,992.7 9,290.00 62.54 148,5 Daily Summary Operations 24h Forecast Back ream out from 10,775' to 5,000' (final two stands circulate bottoms -up). Pull out of hole on elevators, monitor for swabbing. Lay down BHA #17 and down load data from tools Pick-up BHA #18 Baker retrieving hook and trip in hole to 12,767' and pull whip stock. 24h Summary Back ream out of the L1 horizontal 8 3/4" hole section 14,735 to 13,271' Pump out of hole from 13,271' to 13,077'. Work on top drive shot pin and replace component Continue pumping out from 13,077' to 12 702'. Perform weekly BOP function test Change out top drive saver sub to 4-12" Delta 425 Continue back reaming out of hole from 12,702' to 11,641 Service rig - repair air compressor Back ream out of hole 11,641'to 10,775'. Operation at 07.00 Back reaming out of hole at 7,749' MD Lithology ShowsMud Weight (Ib/gal) 9.40 Time Log Start End Cum Dur End Depth Time Time our(hr) (hr) Phase Opr. Act. Plan Oper. Descr. (ftKB) 0000 11'00 11 00 11 00 DRILL E 4 P Back ream speed of 2-18 ft./min from 14,735'to 13,271' at 550 GPM, SPP 3380 PSI, ECD rate 10.7 ppg with 22,110.0 9.4 PPG mud, rotating 120 RPM with 11 K TO. RTW= 115K. Reduce pulling speed due to hole condition in shale section below Fault A from 14,045' to 13,864'. 11:00 11 30 0.50 11.50 DRILL E 4 P Pump out of hole from 13,271'to 13,077' at 100 GPM, SPP 280 PSI with no rotation, UW= 158K. 22,110.0 11:30 1330 2.00 13.50 DRILL E 25 TR04 Change out shot pin unit on top drive for new and function tested - (good test). Monitor well via trip tank - i 22,110.0 bbl /hr. static loss rate 13:30 15:00 1 50 15.00 DRILL E 4 P Continue pumping out of hole from 13,077' to 12,702' at 100 GPM, SPP 280 PSI with no rotation. At 13,015' 22,110.0 observed 20K over pull without rotation, go down and repeat several attempts to work through. Break rotation at 20 RPM with 10K torque and pulled through section observing 2-3K torque spikes UW= 158K / RTW= 130K 1500 1600 1.00 16.00 DRILL E 4 P Continue back reaming 20 ft./min from 12,702'to 12,393' at 550 GPM, SPP 3350 PSI. rotating 120 RPM with 22,110.0 9-10K TO RTW= 120K 16:00 1630 0.50 16.50 DRILL E 12 P Perform weekly BOP function test from secondary remote station on 4-1/2" drill string, (annular, upper and low 22,110.0 rams). Unable to function blindlshear rams due to string in hole 16:30 1900 2.50 19.00 DRILL E 5 P PJSM - Change out saver on top drive from 5" TT525 to 4-112" Delta 425 Change out die blocks and stabbing 22,110.0 guide Service and inspect top drive - replace stand Jump compensator Grease and inspect crown sheaves Monitor well - static lose rate 1.4 bbls /hr. 1900 21'00 2.00 21 00 DRILL E4 P Continue back reaming 20 ft /min from 12,393' to 11,641' at 550 GPM, SPP 3300 PSI, rotating 120 RPM with 22,110.0 I i K TO. RTW= 120K. 21:00 2130 0501 21,50 1 DRILL I E 125 1 P I Service rig- repair air compressors and air dryer 22,110.0 21:30 00'00 2.50 24.00 DRILL E 4 P Back ream 20 ft./min from 11,641 to 10,775' at 550 GPM, SPP 3150 PSI, rotation 120 RPM with 8-9K TO. 22,110.D j 1 I 1 Note Losses to hole last 24 his. = -21 BBL. Max gas last 24 hrs.= 12 units and average gas 6 units 114.8 I hours rotating 181.2 K -rev's Recovered 8 Ins metal from ditch magnets - Total recovered 257.75 Ins Gas Readings Avg Background Gas I%) Max Background Gas I%) Avg Connection Gas (%) Max Connection Gas I%) 6.00 12.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (% ) 0.00 0.00 0.00 0.00 Mud Type: LVT - FazePro - 73% Oi/ Ratio Depth (ftKB) Density (lb/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (CP) YP Calc (Ibfl10... Vis (siqt) 22,110.0 9.40 51 33 25 18 7 6 18.0 15.006 53 Get (10s) (Ibfi1... Gel (10m) (Ibf/1... Gel (30m) (Ibf/1... n K Filtrate (mL130... FC (1132") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 2003 7.003 7.003 0.7 0.4 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mUrnQ Pf (mL/m L) Mf (mUmL) Sand I%) Solids (%) H2O (%) Percent Oil I%) Oil Water Ratio MBT (lblbbl) Titrated 2.900 0.1 12.3 24.0 63.8 72.6/27.4 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (fri Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.4 66,500.000 0.000 30 678.0 3.8 Selected table Well Name: SP03-NE2 L1 DR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10/16/2019 displayed Job: DRILLING Report #: 8 WCEI Level: 3 Page: 2 of 3 Mud Type: LVT - FazePro, - 73% Oil Ratio Depth (ftKB) Density (Iblgal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.40 50 32 24 17 7 6 18.0 14.006 53 Get (10s) (Ibf/1... Gel (10m) (Ibfl1 .. Gel (30m) Qbf/1... n K Filtrate (mL130... FC (1132") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.7 0.4 0.0 0 4.4 1 150.0 500.0 PH pH Method Pm (mLImL) Pf (mUmL) Mf (mLImL) Sand t%) Solids (%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Titrated 3.000 0.1 12.3 24.0 63.8 72.6/27.4 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mglL) Calcium (mg/L) Mg (mg/L) Pot (mg1L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.3 167,000000 0.000 1 30 706.0 3.9 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (CP) YP Calc 1I1of/10... Vis (s/qt) 22,110.0 9.40 51 32 24 17 7 6 19.0 13.005 54 Gel (10s) (I1of/1... Gel (10m) (Ibf/1.. Gel (30m) (Ibf/1.., n K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.7 0.4 0.0 0 4.3 1 150.0 500.0 PH pH Method Pm (mL/mL) Pf (mUmL) Mf (mL/mL) Sand l%) Solids (%) H2O(%) Percent Oil (%) Oil Water Ratio MBT (lb/bbl) Titrated 3.000 0.1 12.3 24.0 63.8 72.6127.4 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mglL) Calcium (mg/L) Mg (mg/L) Pot (mglL) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.4 66,500.000 0.000 30 696.0 3.9 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc top) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.40 50 32 25 18 7 6 18.0 14.006 54 Gel (10s) (Ibf/1... Get (10m) (Ibf/1... Gel (30m) (Ibf/1... in K Filtrate (mL130... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.7 0.4 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (mUmL) Mf (mUmL) Sand (%) Solids I%) H2O (%) Percent Oil (%) bit Water Ratio MBT (Ib/bbl) Titrated 2.900 0.1 12.3 24.0 63.8 72.6/27.4 Brine (Ib/gal) LGS (%) HGS I%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (lb/bbl) 10.60 6.2 3.3 67,000.000 0.000 30 712.0 3.8 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (boll Hole 1,603.2 Loss 21.0 Tank 719.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 2,322.2 1,603.2 0.0 0.0 21.0 423.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Simone Belemmi Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Chad Gueco Eni Drilling Supv. 907-685-0726 Ent representative David Smith Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington 'Eni Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Eni representative Cory Houghton Eni HSE Eni representative Robert Gonzolez Eni HSE Drilling Supt. Sam Dye Doyon Drilling Field Superintendent Tool Push Einer Fleagle Doyon Drilling Tool Push Tool Push Ted Kruger Doyon Drilling Tour Pusher rigl5@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyondrilling.com 685-0796 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note G8R Casing 12.50 0 Drilling Rubicon Swivel 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Baker Liner Hanger 12.50 1 Drilling Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Eni Company Man 12.50 1 Drilling Northern 011feild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling RPS Geologist 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB Directional Driller 12.50 2 Drilling K&M ERD 12.50 2 Drilling SLB MWD 12.50 3 Drilling Competentia Logistic 12.50 4 SID Support MI Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 11 SID Support Worley Truck driver / Crane operator 12.50 18 Drilling Doyon Rig Personnel 12.50 24 Drilling -Total Drilling Personnel BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 8/7/2019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) I Last Cert Date Annular Hydril 500 13 5/8 5,000.0 5/1/2015 3 1/2 "- 6" VBR Hydril MPL 5000 135/8 5,000.0 8/24/2018 Blind Shear Ram Hydril �GIK MPL 5000 13 5/8 5,000.0 8124!2018 4 1/2" x 7" VBR Hydril MPL 5000 13 5/8 5,000.0 5/1/2015 Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10/16/2019 displayed Job: DRILLING Report #: 8 WCEI Level: 3 Page: 3 of 3 Slow Circulation Rates Pump Number. 1 Make: White Star Model: Quatro 2450 Start Date End Date 8/27/2019 Liner Size 6 (in) Volume Per Stroke Override (bbl/stk) I Max Pressure (psi) 0.113 5,323.0 Date Depth (ftKB) Slow Spit Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 10/14/2019 22,110.0 10/14/2019 22,110.0 Yes Yes 22 30 450.0 590.0 Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date 8/27/2019 liner Size 6 (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 0.113 5.323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff 1%) Q Flow (gpm) 10/14/2019 10/1412019 22.110.0 22,110.0 Yes Yes 22 460.0 30 600.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date 8/27/2019 Liner Size 6 (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 0.102 4,665.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff I%) T Q Flow (gpm) 10/14/2019 10/14/2019 22,110.0 Yes Yes 29 39 450.0 600.0 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed 10/16/2019 952.0 952.0 7,664.0 Cum Received 7,664 0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed 10/16/2019 198.0 1980. 1,584.0 Cum Received 1,584.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed 10(16/2019 2,985.0 815.0 25,386.0 Cum Received 35,5070 Cum Returned Cum On Loc 0.0 10,1210 Note Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed 10/16/2019 60.0 0.0 649.0 Cum Received 886.0 Cum Returned Cum On Loc 00 237.0 Note Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed 10/16/2019 42.0 42.0 336.0 Cum Received 336.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description; WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed 10/16/2019 0.0 0.0 0.0 Cum Received 0.0 Cum Returned Cum On Loc OA 0.0 Note Last Authority Visit Date I Tot insp. Nb, Total I.N.C. number Comment STOP Cards Submitted Company C Rpts Com Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. MI Swaco MI Swaco 5 5 5 7 8 6 PJSMs HRWS COW Safe Cards RIR',, HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 L1 DR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/17/2019 Report #: 9 Page: 1 of 3 Well Header Permit/Concession N° Operator Subsidiary Initial Lanes Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB -Base Flange (ft) RKB -Tubing Spool (ft) 53.60 13.10 16.34 37.26 31.76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 9/272019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB MD @ Report Time (ft... TVD @Report Time (ft... 22110.0 4,000.4 0.00 111.0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Cloudy 33.2 ENE @ 41 MPH Gusting to 48 MPH 720.00 720.00 0.00 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause I Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Accumulator Drill 1 10/16/2019 10/30/2019 13 BOP Pressure Test 1 10/9/2019 1023/2019 6 Camp Evac Drill 1 10/10/2019 1/812020 83 Fire Drill 1 10/14/2019 1028/2019 11 Rig Inspection 9 10/17/2019 10/1812019 1 Safety Meeting 9 10/17/2019 10/18/2019 1 Spill Drill 4 10/162019 10/30/2019 13 TT Camp Evac Drill 1 10/14/2019 1/122020 87 TT H2S Drill 1 10192019 10/10/2019 -7 TT Kick While Drilling 1 10/11/2019 10/182019 1 TT Kick While Tripping 1 10/15/2019 1022/2019 5 Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD (ftKB) VS (ft) I NS (ft) EW (ft) DLS (°1100ft) Method 10/7512019 21,943 77 90.68 379.96 4,001.65 18408.55 16.767 79 -9,403.36 1 74 MWD 10/15/2019 22,037.07 90.32 319.65 4,000.84 18,50136 16,839.05 -9,463.57 0.51 MWD 10/15/2019 22,110,00 90.32 319.65 4,000.43 18,573.93 16,894.63 -9,510.79 0.00 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (ft/hr) DRILLING 22,100.0 3,992.7 9,290.00 62.54 148.5 Daily Summary Operations 24h Forecast Pick-up BHA #18 Baker retrieving hook and Schlumberger MWD tool. Trip in hole (shallow test at 2,000'), change saver sub at 3,400'. Continue to 12,660' above window Slip and cut drill line and service. Orientate Baker retrieval tool, latch onto whip stock pull free Pump out of the hole per schedule to 5,500' Continue pulling on elevators from 5,500 to BHA and lay down Clear and clean floor of components Prep to pick-up Ram seal bore diverter assembly, R/U GBR. 24h Summary Back ream out from 10,775to 5,086'. Reduce speed to 1 5 ft /min from 5,086' to 4,991' to circulate bottoms -up. Pull out of hole on elevators from 4,991 to 626' Lay down 6 joints 4-1/2" drill pipe and BHA #17. Clear and clean floor- mob Baker whip slack BHA #18 to rig floor Operation at 07.00 Running in the hole with whipstock retrieval tool @ 4,890' MD Lithology Shows Mud Weight (Ib/gal) 9.40 Time Log Start End Cum Dur End Depth Time Time Dur ihr) (hr) Phase Opr. Act. Plan Oper. Descr. (ftKB) 0000 0600 6.00 6.00 DRILL E 4 P Back ream speed of 20 ft./min from 10,775' to 8,000' at 550 GPM, SPP 2500 PSI, ECD rate 10 16 ppg with 9.4 22,110.0 PPG mud, rotating 120 RPM with 6K TQ. RTW= 1 tOK 0600 1430 6 50 14.50 DRILL E 4 P Back ream speed of 20 ft./min from 8,000' to 4,991' at 550 GPM, SPP 2000 PSI, ECD rate 10,02 ppg with 9.4 22,110.0 PPG mud, rotating 120 RPM with 4-5K TO Reduce pulling speed of 1,5 ft./min from 5,086'to 4,991'to circulate bottoms -up RTW= 98K. 1430 2000 5.50 20.00 DRILL E 4 P Pull out of the hole on elevator from 4,991' to 626' Pump dry job at 4,526' UW= 85K Lay down 6 joints of 4- 22,110.0 1/2" Delta 425 drill pipe from 626' to 436' 2000 23.30 3 50 23.50 DRILL E 5 P Lay down BHA #17 per Schlumberger DO & MWD, clear and clean floor of components Bit grade 1 -1 -BT -G -X 22,110.0 -I -CT -TD 23.30 0000 0.50 24.00 DRILL E i P Mob Baker whip stock components and string magnets to rig floor- prep to pick-up. 22,110.0 Note: Losses to hole last 44 him = -21 BBL Max gas last 24 hrs.= 4 units and average gas 2 units / 9,9 hours rotating 149.5 K -rev's. Recovered 12 lbs metal from ditch magnets - Total recovered 269.75 lbs Gas Readings Avg Background Gas I%)Max Background Gas (%) Avg Connection Gas I%) Max Connection Gas (%) 2.00 4.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas I%) Avg Trip Gas (%) Max Trip Gas (%) 0.00 0.00 0.00 0.00 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.40 50 32 25 17 7 6 18.0 14.006 52 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1... Gel (30m) (Ibf/1... in K Filtrate (mU30... FC (1/32") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 7.003 T003 0.297 18.876 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mIJmL) Pf (mL/mL) Mf (mUmL) Sand I%) Solids I%) H2O i%) Percent Oil (%) Oil Water Ratio MST (Ib/bbl) Titrated 2.900 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Ib/gal) LGS (%) HGS I%) Barite (Iblbbl) Chlorides (mglL) Calcium (mg/L) Mg (mg1L) Pot (mglL) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.6 66,000.000 0.000 30 696.0 3.8 Mud Type: <Mud Base?> - FazePro - 73% Oil Ratio Depth (ftKB) Density (Iblgal) Vis 600rpm Vis 300rpm Vis 200 rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (slgt) 22,110.0 9.40 51 32 25 17 7 6 19.0 13.005 53 Get (10s) flbUll... Gel (10m) (of/I... Gel (30m) (Ibf/1... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate I_. HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.297 18.876 0.0 0 4.4 1 150.0 500.0 PH pH Method Pm (mL/mL) Pf (mumL) Mf (mL/m L) Sand I%) Solids (%) H2O I%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.900 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Ib/gal) LGS I%) H G S I%) Barite (Ib/bbl) Chlorides (mg1L) Calcium (mg1L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.5 66,500.000 0.000 30 688.0 3.8 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/1712019 Repoli #: 9 Page: 2 of 3 Mud Type_ <Mud Base?> - FazePro - 73% Oil Ratio Depth (ftKB) Density (Iblgal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (0) YP Calc Qbf110... Vis (s/qt) 22,110.0 9.40 51 33 25 17 7 6 18.0 15.006 53 Gel (10s) (Ibfl1... Gel (10m) (lbfl1... Gel (30m) (lbfll ... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1132') T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.297 18.876 0.0 0 4,4 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (mL/m L) Mf (mL/mL) Sand (%) Solids (%) H2O I%) Percent Oil I%) Oil Water Ratio MST (Ib/bbl) Titrated 2.900 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Ib/gal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (Int CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.5 66,500.000 0.000 30 672.0 3.8 Mud Type: <Mud Base?> - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (0) YP Calc (Ibf110... Vis (s/qt) 22,110.0 9.40 51 33 25 17 7 6 18.0 15.006 53 Gel (10s) (Ibf/1... Gel (10m) (I1of/1... Gel (30m) (Ibfl1... n K Filtrate (ml -130... FC (1132") HTHP Filtrate (... HTHP FC (1/32') T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.297 18.876 0.0 0 4.4 1 150.0 500.0 FH pH Method Pm (mUmL) Pf (mL/m L) Mf (mUmL) Sand (%) Solids (%) H2O (%) Percent Oil (% Oil Water Ratio MET (Ib/bbl) Titrated 2.900 0.1 12.5 24.0 63.5 72.6127.4 Brine (Ib/gal) LGS (%) FIGS (%) Barite (Iblbbl) Chlorides (ri Calcium (mgll-) Mg (ri Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.3 3.5 67,000.000 0.000 30 682.0 3.8 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,670.1 Loss 44.0 Tank 612.3 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbi) Cum Additions (bbi) Losses (bblj Cum Losses (bbl) 2,282.4 1,670.1 0.0 0.0 44.0 467.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Simone Belemmi Ent Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Chad Gueco Eni Drilling Supv. 907-685-0726 Eni representative David Smith Em Drilling Supv. siddrilling@eni.com 907-685-0715 Ent representative Mitch Billington Eni Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Eni representative Cory Houghton Eni HSE Ent representative Robert Gonzalez Eni HSE Drilling Supt. Sam Dye Doyon Drilling Field Superintendent Tool Push Einer Fleagle Doyon Drilling Taal Push Ton[ Push Ted Kruger Doyon Drilling Tour Pusher rig 15@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyondrilling.com 685-0796 Personnel Log (POB) Company Serv, Type Work H (hr) Stand-by H (hr) Count Note Rubicon Swivel 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Baker Liner Hanger 12.50 1 Drilling Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Ent Company Man 12.50 1 Drilling Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling GBR Casing 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling RPS Geologist 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB Directional Driller 12.50 2 Drilling K&M ERD 12.50 2 Drilling Competentia Logistic 12.50 3 SID Support SLB MWD 12.50 3 Drilling MI Swaco Mud Plant 12.50 5 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12.50 7 SID Support ESS Catering 12.50 11 SID Support Wodey Truck driver / Crane operator 12.50 18 Drilling Doyon Rig Personnel 12.50 25 Drilling_Total Drilling Personnel BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 8/712019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) I Last Cert Date Annular GK 500 13 5/8 5,000.0 5/112015 JHric 3 1/2 "- 6" VBR ril MPL 5000 13 5/8 5,000.0 8124!2018 Blind Shear Ramril MPL 5000 1358 5,000.0 8/24/2018 41/2"x7"VBR ril MPL 5000 135/8 5,000.0 511/2015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start DateEnd Date Liner Size (in) Volume Per Stroke Override (bb[/stk) Max Pressure (psi) 8/27/2019 6 0.113 5,3230 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10114)2019 22.110.0 Yes 22 450.0 10/14/2019 22.110.0 Yes 30 590.0 FirniaNumber: 2 Make: White Star Model: Quatro 2450 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/17/2019 Report #: 9 Page: 3 of 3 Start Date End Date 8/27/2019 Liner Size 6 (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 0.113 5,323.0 Date Depth (ftKB) Slow Sod Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/14/2019 10/1412019 22,110.0 22,110.0 Yes Yes 22 30 460.0 600.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date 8/27/2019 Liner Size 6 (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 0.102 4,665.0 Date Depth (ftKB) Slow Sod Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/14/201922.110.0 1 011 4/2 01 9 Yes Yes 29 39 450.0 600.0 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received 10/17/2019 1,328.0 1.328.0 Returned Cum Consumed 8,992.0 Cum Received 8,992.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received 10/17/2019 198.0 198.0 Returned Cum Consumed 1,782.0 Cum Received 1,782.0 Cum 0.0 Returned Cum On Loc 0.0 Note Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received 10/17/2019 2,634.0 7,045.0 Returned Cum Consumed 28,020.0 Cum Received 42,552.0 Cum 0.0 Returned Cum On Loc 14,532.0 Note Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received 10/17/2019 66.0 135.0 Returned Cum Consumed 715.0 Cum Received .1,021 .0 Cum 0.0 Returned Cum On Loc 306.0 Note Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received 10/17/2019 42.0 42.0 Returned Cum Consumed 378.0 Cum Received 378.0 Cum 0.0 Returned Cum On Loc 0.0 Note Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date lConsurned Received 10/17/2019 210.0 210.0 Returned Cum Consumed 210.0 Cum Received 21D.0 Cum Returned Cum On Loc 0.0 0.0 Note Last Authority Visit Date Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpt. Com Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. MI Swaco Ml Swaco 13 13 13 8 8 6 PJSM'S HRWS COW Safe Cards RIR's HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 1011812019 Report #: 10 Page: 1 of 3 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB -Base Flange (k) RKB -Tubing Spool (ft) 53.60 130 16.34 3726 31 76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON I LAND RIG 0723 9/27/2019 Daily Information End Depth (RKB) End Depth (TVD) (filDepth Progress (k) Drilling Hours (hr) Avg ROP fthr) POB MD @ Report Time (ft... TVD @ Report Time (ft... 22,110.0 4,000.4 0 00 111 0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Cloudy 32.5 E @ 49 to 55 MPH 721.00 721.00 0.00 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Accumulator Drill 1 10/16/2019 10/30/2019 12 BOP Pressure Test 1 10/9/2019 10/23/2019 5 Camp Evac Drill 1 10/10/2019 1/812020 82 Fire Drill 1 10/14/2019 10/28/2019 10 Kick While Tripping Drill 1 10/1812019 10/25/2019 7 Rig Inspection 10 10/18/2019 10/19/2019 1 Safety Meeting 10 10/18/2019 10/1912019 1 Spill Drill 4 10/16/2019 10/30/2019 12 TT Camp Evac Drill 1 10/14!2019 1/12/2020 86 TT l Drill 1 10/9/2019 10/10/2019 -8 TT Kick While Drilling 1 10111!2019 10/18/2019 0 TT Kick While Tripping 1 10/15/2019 10/22/2019 4 Survey Data Date MD (fill Incl (°) A.. (°) TVD (RKB) VS (ft) I NS (ft) EW (ft) DLS (°I100ft) Method 10/15/2019 21,943.77 90.68 319.96 4.001 65 18,408.55 16,767 79 -9,403.36 1.74 MWD 10/15/2019 22,037.07 90.32 319.65 4,000.84 18,501.36 16,839.05 -9,463.57 0.51 MWD 10/15/2019 22,110.00 90.32 319.65 4000.43 18,573.93 16,894.63 -9,510.79 0.00 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft... Depth Or. (MD) (ft) Drilling Time (hr) Avg ROP (f l DRILLING 22,100.0 3,992.7 9,290.00 62.54 148.5 Daily Summary Operations 24h Forecast Pull out of hole with whipstock BHA, lay down BHA, Pick-up BHA #19 Ram Seal Bore assembly and trip in hole stab/latch in set/test Disconnect and pull out of hole per schedule, lay down BHA Pick-up Ram liner/ hanger assembly and trip in hole 24h Summary Pick-up BHA #18 Baker retrieving hook and Schlumberger MWD tool. Trip in hole from 113 to 3,325' (shallow test at 2,000'), change save sub. Continue to 12,675' Slip and cut drill line. Pick-up single and make- up stand, record parameters - Orientate 50L and wash to 12,785' latch onto whip stock Stage up over pull intervals - free at 80K over, pull to 12,705' pumping. Pump out of hole from 12,709'to 7,075' Operation at 07.00 Pulling out of hole with whipstock Lithology Shows Mud Weight (Ib/gap I 9.40 Time Log Start End Cum our End Depth Time Time our (hr) (hr) Phase Opr. Act. Plan Oper. Descr. (RKB) 0000 0130 1 50 1.50 DRILL E 5 P Pick-up BHA #18 Baker whip stock retrieving assembly and Schlumberger MWD tool to 113'. DW= 78K 22.110.0 01:30 0330 2..00 3.50 DRILL E 4 P Run in the hole with Baker whip stock retrieval BHA from 113' to 3,435'- Perform shallow test at 2,000' 22,110.0 pumping 450 GPM at 950 PSI (good test). Fill pipe every 20 stands DW= 90K 03:30 0530 2.00 5.50 DRILL E 5 P Change out saver sub from 4-1/2" Delta 425 to 5" TT 525 thread Change handling equipment to 5". 22,110.0 05:30 08 00 2.50 8.00 DRILL E 4 P Run in the hole with Baker whip stock retrieval BHA from 3,435' to 7,260'- Fill pipe every 20 stands UW= 22,1100 130K / DW= 90K. 08:00 108 30 1 0.50 8.50 1 DRILL E 25 P Service rig - top drive and draw -works swap power and generators for service 22,110.0 08:30 11-30 3.00 11.50 DRILL E 4 P Run in the hole with Baker whip stock retrieval BHA from 7,260' l0 12,675'- Fill pipe every 20 stands UW= 22,110.0 160K/ DW= 110K 11:30 1330 2.00 13.50 DRILL E 25 P Cut and slip drilling line (130'). Change out bleeder choker on mud manifold Monitor well via trip tank. 22,110.0 13M 15 00 1.50 15.00 DRILL E 9 TWO( P/U single of 5" drill pipe and run from 12,675' to 12,705' - make-up stand and establish parameters -400 22,110.0 GPM at 1500 PSI. and 300 GPM at 1040 PSI. UW=158K / DW= 11 OK. Orientate to 50L and wash down from 12,705' to 12,785'- repeat washing from 12,775' to 12,785' three times Engage hook into slot of whip stock, worked three times - set down with 10K. Stage up weight intervals with 20k, 50K and 80K over pull, observed jars bleeding off and anchor shear free UW= 162K, a 4K Increase. Pull out from 12,785' to 12,705' pumping 100 GPM at 250 psi at 10 ft./min. - (free). Note: Operations were slowed due to high wind conditions. 1500 OD 00 9.00 24.00 DRILL E 4 TW01 Pullout hole pumping from 12,705' to 7,075' with rate of 300 GPM at 900 PSI with 50 ft./min, Lay down 5" drill 22,110.0 pipe single and continue pumping/pulling out of the hole. Note: Losses to hole last 24 hrs. = 38 BBL. Max gas last 24 hrs.= 4 units and average gas 2 units 12.6 hours rotating / 1.4 K -rev's Recovered 0lbs. metal from ditch magnets -Total recovered 269.75 lbs. Note Operations were slowed due to high wind conditions Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas I%) Max Connection Gas (%) 2.00 4.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas I%) Max Trip Gas (%) 0.00 0.00 0.00 0.00 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (RKB) Density (Ib/gap Vis 600rpm Vis 300rpm Vis 200rpm Vis 1100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (slgt) 22.110.0 9.40 51 33 25 17 7 6 18.0 15.006 53 Gel (10s) (Ibfit... Gel (10m) (IbfH... Gel 130m) (Ibfl1... n K Filtrate (mL/30... FC (1132") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.297 18.876 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (ml Pf (mL/mL) Mf (mL/ml) Sand I%) Solids (%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.900 0.1 12.5 24.0 63.5 72.6127.4 Brine Ill LGS (%) HGS I%) Barite pblbbp Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime ill 10.60 6.3 3.5 67,000.000 0.000 30 682.0 3.8 Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 1 011 8/2 01 9 displayed Job: DRILLING Report #: 10 WCEI Level: 3 Page: 2 of 3 Mud Type: LVT - FazePro - 73% 011 Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (clo) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.40 51 33 25 17 7 6 18.0 15.006 53 Gel (10s) (Ibf/1 Gel (10m) (Ibfl1 ... Gel (30m) (Ibf/1... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate I- HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.297 18.876 0.0 0 4.3 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (mL/mL) Mf (.1 -ml Sand I%) Solids I%) H2O I%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Tirated 2.900 0.1 12.5 24.0 63.5 72.627.4 Brine (Ib/gal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides (ii Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.5 66,500.000 0.000 1 30 691.0 3.8 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (eP) YP Calc (Ibf/10... Vis (slgt) 22110.0 9.40 51 33 25 17 7 6 18.0 15.006 53 Gel (10s) (lbf11... Gel (10m) (Ibfll.. Gel (30m) (bill ... in K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.297 18.876 0.0 0 4.3 1 150.0 500.0 PH pH Method Pm (mL/mL) Pf (mL/ri Mf (mUmL) Sand I%) Solids I%) H2O I%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) Tirated 2.900 0.1 12.5 24.0 63.5 72.6/274 Brine (Ib/gal) LGS I%) HGS I%) Barite (Ib/bbl) Chlorides hrri Calcium (mg/L) Mg (mg1L) Pot (mglL) CaC12 (ppm) Electric Stab (V) Ex. Lime (Iblbbl) 10.60 6.2 3.5 66,500.000 0.000 30 676.0 3.8 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (lb/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (CP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 940 52 34 26 17 7 6 18.0 16.007 54 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1.. Gel (30m) (Ibf/1... n K Filtrate (mLJ30... FC (1132") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 7003 7.003 0.297 18.876 0.0 0 4.4 1 150.0 500.0 PH pH Method Pm (mL/mL) Pf (mUmL) Mf (mL/mL) Sand I%) Solids I%) H2O I%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.800 0.1 12.5 24.0 63.5 72,6/274 Brine (Ib/gal) LGS I%) HGS I%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg ril Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.3 3.5 67.000.000 0.000 30 670.0 3.6 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,6222 Loss 38.0 Tank 586 2 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cu. Additions (bbl) Losses (bbl) Cum Losses (bbl) 2,208.4 1,622.2 0.0 0.0 38.0 505.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Simone Belemmi Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Chad Gueco Em Drilling Supv. 907-685-0726 Eni representative David Smith Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington Eni Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Eni representative Cory Houghton Eni HSE Eni representative Robert Gonzolez Eni HSE Drilling Supt. Sam Dye Doyon Drilling Field Superintendent Tool Push Einer Fleagle Doyon Drilling Tool Push Tool Push Ted Kruger Doyon Drilling Tour Pusher rig 15@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyondrilling.com 685-0796 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note Rubicon Swivel 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Baker Liner Hanger 12.50 1 Drilling Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Em Company Man 12.50 1 Drilling Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 1250 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling GBR Casing 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling RPS Geologist 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB Directional Driller 1250 2 Drilling K&M ERD 12.50 2 Drilling Competentia Logistic 12.50 3 SID Support SLB MWD 12.50 3 Drilling MI Swaco Mud Plant 12.50 5 Drilling Purcell Security 12.50 6 SID Support MI Swaco WE 12.50 7 SID Support ESS Catering 12.50 11 SID Support Worley Truck driver / Crane operator 12.50 18 Drilling Doyon Rig Personnel 12.50 25 Drilling_Total Drilling Personnel BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 8/7/2019 5/112015 5,000.0 Type Make Model to Nom (in) P Range (psi) Last Cert Date Annular Hydril GK 500 13 518 5,000 0 5!112015 3 1/2 "-6" VBR Hydril MPL 5000 13 518 5,000.0 8/242018 Blind Shear Ram Hydril MPL 5000 13 5/8 5,000.0 8/24/2018 4 1/2" x 7" VBR Hydril MPL 5000 13 518 5.000.0 5/1/2015 Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10/18/2019 displayed Job: DRILLING Report #: 10 WCEI Level: 3 Page: 3 of 3 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 8/27/2019 6 0.113 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/14/2019 22,110.0 Yes 22 450.0 10/14/2019 22.110.0 Yes 30 590.0 Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 8/27/2019 6 0.113 5.323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 10/14/2019 22,110.0 Yes 22 460.0 10/14/2019 22,110.0 Yes 30 600.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 8/27/2019 I I 6 0.102 4,665.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 10/14/2019 22,110.0 Yes 29 4500 10/14/2019 Yes 39 600-0 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date lConsurned Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/18/2019 1288.0 1,288.0 10,280.0 10,280,0 0.0 0.0 supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Dale Consumed Received Returned Cu. Consumed Cum Received Cum Returned Cum On Loc Note 10/18/2019 198.0 1980. 1,980.0 1.980.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/18/2019 1,889.0 200.0 29,909.0 42,752.0 0.0 12,843.0 Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 1011812019 69.0 0.0 784.0 I 1,021.0 0.0 237.0 Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cu- Consumed Cum Received Cum Returned Cum On Loc Note 10/18/2019 42.0 42.0 420.0 420.0 0.0 0.0 Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/18/2019 0.0 0.0 210.0 210.0 0.0 0.0 Last Authority Visit Date Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling 9 PJSM'S Doyon Drilling Inc. 7 Safe Cards Doyon Drilling Inc. 9 COW Doyon Drilling Inc. 9 HRWS Ml Swaco 8 HARC/JSA MI Swaco 8 RIR's General Notes Comment: Whipstock Retrieval BHA Hook ------------------ - ---------7.47 5" HWDP--------------30.89 Oil Jar ---------------------13.15 Float Sub --------- --------MWD__-_______-_--___________29.06 MWD ------------ - - - - - -------- 29.06 Pump Out Sub -------------1.99 Magnostar Magnet -----------11.81 Magnostar Magnet -----------12.13 4.13 Total length ------------ --------113.14' Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/19/2019 Report #: 11 Page: 1 of 3 Well Header Permit/Concession W Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Cc Inc. DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) Firsc Flange (ft) RKB - Base Flange (ft) RKB -Tubing Spool (ft) 53.60 13.10 16.34 37.26 31 76 Rigs Rig Name Contractor Rig Tpe Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAN)YR IG 0723 9/2712019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB MD @ Report Time (ft... TVD @ Report Time (ft... 22,110.0 14,0004 0.00 114.0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Cloudy 32.0 E @ 35 to 50 MPH 722.00 722.00 0.00 Safety Incidents - Near Miss Date I Category Type I Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Accumulator Drill 1 10116/2019 10/30/2019 11 BOP Pressure Test 1 10f9f2019 10/23/2019 4 Camp Evac Drill 1 10/10/2019 1/8/2020 81 Fire Drill 1 10/14/2019 10/28/2019 9 Kick While Tripping Drill 1 10/18/2019 10/25/2019 6 Rig Inspection 11 10119/2019 10/20/2019 1 Safety Meeting 11 10/192019 10/20/2019 1 Spill Drill 4 10/16/2019 10/30/2019 11 TT Camp Evac Drill 1 10/142019 1/12/2020 85 TT H2S Drill 1 10/9/2019 10/10/2019 -9 TT Kick While Drilling 1 10/11/2019 10/18/2019 -1 TT Kick While Tripping 1 10/15/2019 1022t2019 3 TT Man Down Drill 1 10/19/2019 1/17/2020 90 TT Well Kill Drill 1 10/19/2019 1/17/2020 90 Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD (ftKB) VS (ft) I NS (ft) EW (ft) DLS (°/100ft) Method 10/15/2019 21,94377 90.68 319.96 4,001.65 18,408.55 16,76779 -9,403.36 1.74 MWD 10/15/2019 22,037.07 90.32 319.65 4,000.84 18,50136 16,839.05 -9,463.57 0.51 MWD 10/152019 22,110.00 90.32 319.65 4,000.43 18,573.93 16,894.63 -9,510.79 0.00 MWD Job Information Job Phase Spud Date End DateTarget Depth (ftKB) Target Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (ftlhr) DRILLING 22,100.0 3,992.7 9,290.00 62.54 148.5 Daily Summary Operations 24h Forecast Trip in BHA #19 Ram Seal Bore assembly set/test/disconnect. Pullout and lay down BHA #19. Pick-up 5-1/2' liner and assembly and trip in hole 24h Summary Pump out from 7,075to 5,300' Pulling on elevators from 5,300 to BHA #18 113' and lay down P/U BHA #19 Ram Seal Bore assembly to 153', trip in hole to 9,079' Operation at 07.00 Pulling out of hole with running tool. Lithology Shows Mud Weight (Iblgal) 9.40 Time Log Start End Cum our End Depth Time Time our (hr) (hr) Phase Opr. Act. Plan Oper. Descr. (ftKB) 0000 0200 2.00 2.00 DRILL E 4 TWO1 Pull out hole pumping from 7,705' to 5,300' with rate of 300 GPM at 670 PSI with 50 ft./min UW= 120K 22,110.0 Note Operations were slowed due to high wind conditions 0200 0530 3.50 5.50 DRILL E 4 TW01 Continue pulling out of the hole on elevators from 5,306' to 3,444' per schedule staging up to 50 -60 ft /min 22.110.0 UW= 105K Note Operations were slowed due to high wind conditions 0530 06:00 0.50 6.00 DRILL E 5 TWO1 Change handling equipment from 5" to 4-1/2"and prep pipe shed to lay down 22,110.0 Note Operations were slowed due to high wind conditions 0600 07:00 1 o0 7.00 DRILL E 4 TWO1 PJSM -Pulled out of hole 3,444' to 2,777' lay down 7 stands of 4-1/2" Delta 425 drill pipe UW= 100K. 22,110.0 Note Operations were slowed due to high wind conditions 07:00 0930 2.50 9.50 DRILL E 4 TWO1 Resumed to pull of hole on elevators from 2,777'to 113' and stand back in derrick 22,110.0 Note. Operations were slowed due to high wind conditions. 09:30 1200. 250 12.00 DRILL E 5 TWO1 PJSM - Lay down BHA #18 Baker whip stock and retrieval hook assembly. Inspection found slight damage on 22,110.0 the right edge. with small metal fines on upper/lower magnets with few bigger pieces Total recovered 10 Ib. Note Operations were slowed due to high wind conditions 12:00 14:00 2.00 14.00 DRILL E 1 P PJSM - Clear and clean floor, rig -up GBR equipment and mob seal bore components to floor Monitor well- 22,110.0 1 9 bbis /hrs lose rate 1400 1700 3,00 17.00 DRILL E 5 P PJSM - Pick-up BHA #19 Baker Ram Seat Bore Diverter assembly, tested running tool 2 times to engage at 22,110.0 350 gpm and set to release set at 480 gpm with 870-900 psi Make-up Schlumberger MWD tool and orientate. 153' UW=60k DW=65K 1700 2000 3.00 20.00 DRILL E 4 P Run in the hole with BHA #19 from 153' to 3,479. Perform shallow test at 1,575' pumping 315 GPM at 580 22,110.0 PSI (good test) Fill pipe every 20 stands DW= 90K. 20:00 0000 4.00 2400 DRILL E 4 P PJSM - Change over handling equipment to from 4-112" to 5" Continue tripping in the hole with Baker Ram 22,110.0 seal bore diverter assembly from 3,479' tc 9,079'- Fill pipe every 20 stands UW= 132K / DW= 100K Note: Losses to hole last 24 him =- 35 BBL Max gas last 24 hrs.= 3 units and average gas 2 units 10.2 hours rotating / 1.2 K -rev's. Recovered 11 lbs. metal from ditch magnets - Total recovered 280 75 Ibs Gas Readings Avg Background Gas I%) Max Background Gas I%) Avg Connection Gas I%) Max Connection Gas I%) 2.00 3.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (°/) Max Trip Gas I%) 0.00 0.00 0.00 0.00 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments thalcan be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/19/2019 Report #: 11 Page: 2 of 3 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10_. Vis (s/qt) 22,110.0 9.40 51 33 25 16 7 6 18.0 15.006 54 Get (10s) (IbfM... Gel (10m) (Ibf/1 ... Gel (30m) (Ibf/1... n K Filtrate (mU30... FC (1/32') HTHP Filtrate I- HTHP FC (1132') T HTHP (°F) P HTHP (psi) 6.002 TD03 7.003 0.28 19.417 0.0 0 4,4 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (mUmL) Mf (mUmL) Sand (%) Solids I%) H2O (%) Percent Oil I%) Oil Water Ratio MET (Ib/bbl) Titrated 2.800 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (ni Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.6 66,000.000 0.000 30 675.0 3.6 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (lb/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (CP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.40 51 33 25 16 7 6 18.0 15.006 54 Gel (10s) (Ibfll... Gel (10m) (Ibflt... Gel (30m) (bfil... n K Filtrate (mL/30... FC (1/32') HTHP Filtrate (... HTHP FC (1/32') T HTHP (°F) P HTHP (psi) 6.002 7.003 7 003 0.28 19.417 0.0 0 4 4 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (nri Mf (mUmL) Sand (%) Solids I%) H2O (%) Percent Oil I%) Oil Water Ratio MET (Iblbbl) Titrated 2.800 0.1 12.5 24.0 63.5 72.6127.4 Brine (Ib/gal) LGS (%) HGS (%) Barite (lb/bbl) Chlorides lint Calcium (mg/L) Mg (ni Pot (ni CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.6 66,000.000 0.000 30 681.0 3.6 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/f 0... Vis (s/qt) 22,110.0 9.40 51 33 25 16 7 6 18.0 15.006 54 Gel (10s) (IbUll... Gel (10m) (Ibf/1.. Gel (30m) (Ibf/1... n K Filtrate (mLI30... FC (1132') HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 2003 7.003 0.28 19.417 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mLlrri Pf (mUmL) Mf (mUmL) Sand I%) Solids (%) H2O (%) Percent Oil I%) Oil Water Ratio MET (Iblbbl) Titrated 2.800 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Iblgal) LGS (%) HGS (%) Barite (Iblbbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot hri CaCl2 (ppm) Electric Stab (V) Ex. lime (Ib/bbl) 10.60 6.2 3.5 66.500.000 0.000 30 668.0 3.6 Mud Type: LVT - FazePro - 73% OR Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (slqt) 22,110.0 9.40 50 32 25 16 7 6 18.0 14.006 55 Gel (10s) (of/1... Gel (10m) (Ibf/t,. Gel (30m) (Ibf/1 ... n K Filtrate (mL/30... FC (1132') HTHP Filtrate (... HTHP FC (1132') T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 028 19.417 0.0 0 4.5 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (mUmL) Mf (mLlm L) Sand (%) Solids (%) H2O (%) Percent Oil (%) Oil Water Ratio MST (Ib/bbl) Titrated 2.800 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Ib/gal) LGS I%) HGS I%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (ni Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.5 66,500.000 0.000 30 672.0 3.6 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hale 1.612.2 Loss 35.0 Tank 544.2 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 2,156.4 1,612.2 0.0 0.0 35.0 540.0 Daily Contacts Position Contact Name Company Titte Email Office Mobile Eni representative Simone Belemmt Ent Drilling Supv. siddrilling@eni.com 907-685-0715 Ent representative Bruce Simonson Ent Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative David Smith Ent Drilling Supv. siddrilling@eni.com 907-685-0715 Ent representative Mitch Billington Eni Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Ent representative Cory Houghton Eni HSE Ent representative Robed Gonzolez Eni HSE Drilling Supt. Sam Dye Doyon Drilling Field Superintendent Tao[ Push Einer Fleagle Doyon Drilling Tool Push Tool Push Ted Kruger Doyon Drilling Tour Pusher rigl5@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyondrilling.com 685-0796 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRG Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Eni Company Man 12.50 1 Drilling Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling RPS Geologist 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Baker Liner Hanger 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling GBR Casing 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling Mi Swaco Mud Engineer 12.50 2 Drilling SLB Cement 12.50 2 Drilling K&M ERE) 12.50 2 Drilling Competentia Logistic 12.50 3 SID Support SLB Directional Driller 12.50 3 Drilling SLB MWD 12.50 3 Drilling MI Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 12 SID Support Worley Truck driver / Crane operator 12.50 16 Drilling Doyon Rig Personnel 12.50 26 Drilling Total Drilling Personnel Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10/19/2019 displayed Job: DRILLING Report #: 11 WCEI Level: 3 Page: 3 of 3 BOP Stack & Components Description BOP Stack Start Date 8!7/2019 Last Certification Date Pressure Rating (psi) 5/1/2015 5,000.0 Type Make Model to Nom (in) P Range (psi) Last Cert Date Annular Hydril GK500 135/8 5,000.0 5/12015 31/2'-6"VBR Hyddl MPL 5000 135/8 5,000.0 8/242018 Blind Shear Ram Hydric MPL 5000 13 5/8 5,000.0 8/242018 4 112" x 7" VDR Hydril MPL 5000 13 5/8 5,000.0 5/1/2015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 8/27/2019 6 0.113 I 5.323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff 1%) Q Flow (gpm) 10/14/2019 22,110.0 Yes 22 450.0 10/14/2019 22,110.0 Yes 30 590.0 Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 8/27/2019 6 0.113 5, 323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eft (%) Q Flow (gpm) 10/14/2019 22,110.0 Yes 22 460 0 10/14/2019 22.110.0 Yes 30 600.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 8/27/2019 6 0.102 4,665.0 Date Depth (ftKB) Slow Spit Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/14/2019 22,110.0 Yes 29 450.0 10/14/2019 Yes 39 600.0 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/19/2019 1,056.0 1,056.0 I 11,336.0 11,336.0 0.0 0.0 Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10!19/2019 198.0 1980. 2,178.0 2,178.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/19/2019 1,986.0 0.0 31,895.0 42,752.0 0.0 10,857.0 Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/19/2019 66.0 135.0 850.0 1,156.0 0.0 306.0 Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc No[e 10/19/2019 42.0 42.0 462.0 462.0 0.0 0.0 Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum consumed Cum Received Cum Returned Cum On Loc Note 10/19/2019 0.0 0.0 210.0 210.0 0.0 0.0 Last Authority Visit Date I Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Co. Doyon Drilling 9 PJSM'S Doyon Drilling Inc. 9 COW Doyon Drilling Inc. 2 Safe Cards Doyon Drilling Inc. 9 HRWS MI Swaco 8 RIR's Ml Swaco 8 HARC/JSA General Notes Comment: Seal Bore Diverter BHA Non Locating Seal Assembly --------3.25 Pup _____.-_.--____ ___-______-__.___ 13.41 Production Anchor --------------------6.54 Pup PUp -------------------- - D -Nipple ---- _----- _- ----- _----- -__-_____ 1.20 Pup----------------- --------- ------------ _-5.85 Pup 7.88 Pup----------- ---- ----- ----------------------- 7,88 Seal Bore Diverter----------------------27.88 Handling Pup ------------------------8.30 Float Sub --------------------------2.51 WD_-____ _-------- -__________._--_------- 29 .06 MWD ------ Magnesia, Magne-11.81 Magnesta,Magnet-13 X -over to DP ----------------------4.13 Total Length -1 53.53' Selected table Well Name: SP03-NE2 L1 OR(A) Dail Report has no valid Wellbore Name: SP03-NE2 L1 y p attachments Date: 10/20/2019 that can be Well Code: 32145 displayed Job: DRILLING Report #: 12 WCEI Level: 3 Page: 1 of 3 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc. DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) TR -Base Flange (ft) RKB -Tubing Spool (ft) 53.60 13 10 16.34 37.26 31.76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 9/27/2019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (fUhr) POB MD @ Report Time (ft... TVD @ Report Time (ft... 22,110.0 4,000.4 0.00 113.0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Clear 18.6 S @ 7 MPH 723.00 723.00 0.00 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Accumulator Drill 1 10/16/2019 10/30/2019 10 BOP Pressure Test 1 10/9/2019 10/23/2019 3 Camp Evac Drill 1 1011012019 1/8/2020 80 Fire Drill 1 10114/2019 10/28/2019 8 Kick While Tnpping Dnll 2 1020/2019 10/272019 7 Rig Inspection 12 10/20/2019 10/21/2019 1 Safety Meeting 12 10120/2019 1021/2019 1 Spill Drill 4 10/16/2019 10/30/2019 10 TT Camp Evac Drili 1 10/142019 1/12/2020 84 TT H2S Drill 1 1019/2019 10/10/2019 -10 TT Kick While Drilling 1 10/11/2019 10118/2019 -2 TT Kick While Tripping 1 10/1512019 1022/2019 2 TT Man Down Drill 1 10/19/2019 1/1712020 89 TT Stripp.ng Drill 1 10202019 1/18/2020 90 TT Well Kill Drill 1 10/19/2019 1/1712020 89 Survey Data Date MD (ftK8) Incl (°) Azm (°) TVD (RKB) VS (ft) NS (ft) EW (ft) DLS (°1100ft) Method 10/1512019 21,943.77 90.68 319.96 4,001.65 18,408.55 16,767.79 -9,403.36 114 MWD 10/15/2019 22,037.07 90.32 319.65 4,000.84 18,501.36 16,83205 -9,463.57 0.51 MWD 10/15/2019 22,110.00 90.32 319.65 4,000.43 18,573.93 16,894.63 -9,510.79 0.00 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (fUhr) DRILLING 22,100.0 3,992.7 9,290.00 62.54 148.5 Daily Summary Operations 24h Forecast Continue pick up 5-1/2" liner per tally to 9,301'. Pick up Ram Liner Hanger and continue in hole on drill pipe tally to 22,101' shoe. 24h Summary Trip in from 9,079' to 12,719 BHA #19 (Sea[ Bore Diverter) setiputt test and release -top 12,759. Pull out and lay down BHA #19. PJSM - Pick up 4-1/2"x 5-112" liner to 206'. Operation at 07.00 Running in hole with 5 12" 15.5# L-80 Hyd 521 slotted liner Lithology Shows Mud Weight (Ib/gal) 9.45 Time Log Start End Cum our End Depth Time Time Dur (hr) (hr) Phase OF, Act. Plan Oper. Descr. (RKB) 00:00 02-30 2 50 2.50 DRILL E 4 P PJSM - Tripping in the hole with Baker Ram Seal Bore Diverter assembly from 9,079' to 12,719'- Fill pipe 22,110.0 every 20 stands UW= 155K / DW= 108K. 0230 03:30 1.00 3.50 DRILL E 5 P Break circulation - record parameters and tool face 6L; wash down from 12,719' to 12,844', observed the seal 22,110.0 and anchor locate into the MLZXP packer with MWD reading of 25L Continue to slack -off to 30K set down. Pick-up to 12,839' with 35K over to confirm latch into the MLZXP profile. Increase pump rate to 497 gpm at 2300 psr to release running tool from SBD at 12.759' Pick-up to 12,727' UW= 155K f DW= 405K 03:30 13-00 9.50 13.00 DRILL E 4 P Pump out of hole from 12,727' to 5,800' with rate of 200 GPM at 370 PSI with 50 ft./min UW- 125K / DW= 22,110.0 00K. 1300 18 30 5.50 18.50 DRILL E 14 P Pull out on elevators from 5,800' to 65' BHA #19 22,110.0 18.30 19:30 1.00 19.50 DRILL E 5 P Lay down MWD and Baker seal bore diverter running tool - good condition Recovered 8 lbs. metal fines from 22 110.0 magnets 19:30 2230 3.00 22.50 DRILL E 1 P Clear and clean rig floor of BHA. PJSM - Rig up GBR tongs and torque turn system prep -pipe shed. Make 22,110.0 safety cross-over to valve for safety joint Monitor well - static loss rate 1 4 bbl./hr. 2230 00:00 t.5o 24.00 DRILL G 4 P Pickup 4-112" liner to 165' and change handling equipment and continue with 5-1/2" liner to 206'. GER 22,110.0 replaced tong senor, not working properly to dump hydraulic at make-up setting. Note Losses to hole last 24 him = - 31 BBL Max gas last 24 hm.= 3 units and average gas 2 units / 3 hours rotating ! 1.6 K -rev's. Recovered 8 lbsmetal from ditch magnets - Total recovered 288.75 lbs Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas (%) Max Connection Gas (%) 2.00 3.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (%) 0.00 0.00 I 0.00 0.00 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (RKB) Density (Ib/gal) Vis 600rpm 22,110.0 9.40 50 Vis 300rpm 32 Vis 200rpm Vis tOOrpm Vis 6rpm Vis 3rpm 25 16 7 6 PV Calc (eP) YP Cate Qbf/10... Vis (stgt) 18.0 14.006 55 Gel (10s) (Ibf/1... Gel (10m) (IbflL.. Gel (30m) (of/1 ... n K Filtrate (mU30... FC (1132") HTHP Filtrate I_ HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.28 19.417 0.0 0 4.5 1 150.0 500.0 pH pH Method Pre (mUmL) Pf (mL/mL) Mf (mLImL) Sand (%) Solids (%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Tlrated 2.800 0.1 12.5 24.0 63.5 72.6/27.4 Brine (1b/gai) IGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg1L) Mg (mg1L) Pot (mg1L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.5 66,500.000 0.000 30 686.0 16 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/20/2019 Report #: 12 Page: 2 of 3 Mud Type: LVT - FazePro - 73%0l/Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.40 50 32 25 16 7 6 18.0 14.006 54 Get (10s) (I1of/1... Gel (10m) (Ibf/1... Gel (30m) (lbf/1... n K Filtrate (mU30... FC (1/32") HTHP Filtrate I- HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.28 79.477 0.0 0 4.5 1 150.0 500.0 PH pH Method Pm (mL/mL) Pf (mL/mL) Mf (mUmL) Sand (%) Solids I%) H2O (%) Percent Oil I%) Oil Water Ratio MET (Ib/bbl) Titrated 2.800 0.1 12.5 24.0 63.5 72.6/27.4 1699,0 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mglL) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.5 66,500.000 0.000 30 3.6 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.45 51 32 25 16 7 6 19.0 13.005 55 Gel (10s) (Ibfl1.- Gel (tem) (Ibfi1... Gel (30m) (Ibf/1... n K Filtrate (ml -130... FC (1/32') HTHP Filtrate (... HTHP FC (1132-) T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.28 19.417 0.0 0 4,5 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf hn /mL) Mf (mUmL) Sand I%) Solids I%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.800 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.6 66,000.000 0.000 30 676.0 3.6 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.45 51 32 25 16 7 6 19.0 13.005 55 Gel (10s) (Ibf/1... Gel (10m) (ofi1.. Gel (30m) (101... n K Filtrate (ml -130... FC (1/32') HTHP Filtrate (... HTHP FC (1/32') T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.28 19.417 0.0 0 4.5 1 150.0 500.0 PH pH Method Pm (mL/mL) Pf (mL/mL) Mf (mL/mL) Sand I%) Solids I%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.700 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Ib/gal) LGS (%) HGS I%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.5 66.500.000 0.000 30 674.0 3.5 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (lbf110... Vis (s/qt) 22,110.0 9,45 51 32 25 16 7 6 19.0 13.005 55 Gel (los) (Ibf/1.,. Gel (tem) (Ibf/1_. Gel (30m) (Ibfl1 ... n K Filtrate (mL/30... FC (1/32') HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.28 19.417 0 pH pH Method Pm (mL/mL) Pf (mL/mL) Mf (mUmL) Sand I%) Solids I%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) 0.1 12.5 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 0.000 674.0 Daily Mud Volumes TanWAddition/Loss Type Des Volume (bbl) Hole L.668.8 Loss 31.0 Tank 458.2 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 2,127.0 1,668.8 0 0 0.0 31 0 571.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative David Smith Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington Eni Rig Clerk AKRigClerksDoyon75@eni.com 907-685-0722 Eni representative Cory Houghton Eni HSE Eni representative Robert Gonzolez Eni HSE Drilling Supt Sam Dye Doyon Drilling Field Superintendent Tool Push Einer Fleagle Doyon Drilling Tool Push Tool Push Ted Kruger Doyon Drilling Tour Pusher rig 15@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyondrilling.com 685-0796 Personnel Log (POS) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note Eni Company Man 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling RPS Geologist 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Baker Liner Hanger 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB Directional Driller 12.50 2 Drilling SLB MWD 12.50 2 Drilling K&M ERD 12.50 2 Drilling GBR Casing 12.50 3 Drilling Competentia Logistic 12.50 4 SID Support MI Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 12 SID Support Worley Truck driver / Crane operator 12.50 16 Drilling Doyon Rig Personnel 12.50 26 Drilling Total Drilling Personnel Selected table Well Name: SP03-NE2 L1 DR(A) has no valid Wellbore Name: SP03-NE2 L1 Daily Report attachments that can be Well Code: 32145 Date: 10/20/2019 displayed Job: DRILLING Report #: 12 WCEI Level: 3 Page: 3 of 3 BOP Stack 8 Components Description BOP Stack Start Date 8/7/2019 Last Certification Date 5/1/2015 Pressure Rating (psi) 5,000 0 Type Make Model ID Nom (in) P Range (psi) I Last Cert Date Annular 3 1/2 "- 6" VBR Blind Shear Ram 4 112" x 7" VBR I Hydril Hydril Hydril Hydril GK 50013 MPL 5000 MPL 5000 MPL 5000 518 13 518 13 5/8 13 5/8 5.000.0 5,000.0 5,000.0 5,000.0 5112015 8/24/2018 8/24/2018 5!112015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Dale 8/27/2019 Liner Size 6 (in) Volume Per Stroke Override (bbl/stk) 0.113 Max Pressure (psi) 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/14/2019 10/14/2019 22,110.0 22.110.0 Yes Yes 22 30 450.0 590.0 Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date 8/27/2019 Liner Size 1 6 (in) Volume Per Stroke Override (bbllstk) 0.113 Max Pressure (psi) 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 10/14/2019 10/14/2019 22,110.0 22,110.0 Y-22 Yes 30 4600 600.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date 827/2019 Liner Size 6 (in) Volume Per Stroke Override (bbllstk) 0.102 Max Pressure (psi) 4,665.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 10/14/2019 10/14/2019 22,110.0 Yes Yes 29 39 450.0 600.0 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date I Consumed Received Returned Cum Consumed 102012019 750.0 750.0 12,086.0 Cum Received 12,086.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed 102012019 198.0 198.0 2,376.0 Cum Received 2,376.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date I Consumed Received Returned Cum Consumed 10/20/2019 1,672.0 7,429.0 33,567.0 Cum Received 50,1810 Cum Returned Cum On Loc 0.0 16,614.0 Note Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date ConsumedReceived Returned Cum Consumed 10/20/2019 52.0 0.0 902.0 Cum Received 1,156.0 Cum Returned Cu. On Loc 0.0 254.0 Note Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed 10120/2019 42.0 42.0 504.0 Cum Received 504.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed 10/20/2019 1,134.0 1,134.0 1,344.0 Cum Received 1,344.0 Cum Returned Cum On Loc 0.0 0.0 Note Last Authority Visit Date I Tot msp. Nb, Total I.N.C. number I Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. Al Swaco Al Swaco 10 10 17 10 8 8 PJSM'S COW Safe Cards HRWS RIR's HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 Daily Report attachments that can be Well Code: 32145 Date: 10/21/2019 displayed Job: DRILLING Report #: 13 WCEI Level: 3 Page: 1 of 3 Well Header Permit/Concession N° OperatorSubsidiary Initial Lahee Code ADL -392938 I ENI PETROLEUM ENI Petroleum Cc Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB -Base Flange (ft) RKB - Tubing Spool (ft) 53.60 13.10 16.34 37 26 31.76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 9/2712019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB MD @ Report Time (ft... TVD @ Report Time (ft... 22,110.0 4,000.4 0.00 112.0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Overcast 27.8 E @ 17 MPH 72400 724.00 0.00 Safety Incidents - Near Miss Date Category Type I Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Accumulator Drill 1 10/16/2019 10/30/2019 9 BOP Pressure Test 1 101912019 10/23/2019 2 Camp Evac Drill 1 10/10/2019 1/812020 79 Fire Drill 2 10/21/2019 11/4/2019 14 Kick While Tripping Drill 2 10/20/2019 10/27/2019 6 Rig Inspection 13 10/21/2019 10/22/2019 1 Safety Meeting 13 10/21/2019 10/22/2019 1 Spill Drill 4 10/16/2019 10/30/2019 9 TT Camp Evac Drill 1 10/14/2019 1/12/2020 83 TT H2S Drill 1 1019/2019 10/10/2019 -11 TT Kick While Drilling 1 10/11/2019 10/18/2019 -3 TT Kick While Tripping 1 10/15/2019 10/22/2019 1 TT Man Down Drill 1 10/19/2019 1/17/2020 88 TT Rig Evacuation Drill 1 1021/2019 11/4/2019 14 TT Stripping Drill 1 10/20/2019 1/18/2020 89 TT Well Kill Drill 1 10/19/2019 1/17/2020 88 Survey Data Date MD (ftKB) Incl (") A- (°) TVD (ftKB) VS (ft) I NS (ft) EW (ft) DLS ("1100ft) Method 10/1512019 21,943.77 90.68 319.96 4,001.65 18,408.55 16,76779 -9,403.36 174 MWD 10!1512019 22,037.07 90.32 319.65 4,000.84 18,501.36 16,839.05 -9,463 57 0.51 MWD 10/152019 22110.00 90.32 319.65 4,000.43 18,573.93 16,894.63 -9,51079 0.00 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft...19D epth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (ft/hr) DRILLING 22,100.0 3,992.7 290.00 I 62.54 148.5 Daily Summary Operations 24h Forecast Pull out of hole lay down hanger and production liner. Make up bent joint assembly and run in hole with production liner and test SOP's 24h Summary Run in hole with 5.5" slotted production liner F206' T/9,303'. Make up hanger assembly and run in hole with 4 1/2" drill pipe T/12,675' Change out saver sub and run in hole on 5° drill pipe T/12,752' Make several attempts and unable to pass through Seal Bore Assembly. Pump out of hole with 5" drill pipe T/12,782' Change saver sub and handling equipment to 4 %" and pump out of holeF/12,675' T/9,410' Note: Sent 5 %" production liner joint to Baker to be slightly bent for next run Operation at 07.00 Continue to pull out of hole laying down 5 1/2" production liner. Lithology Shows Mud Weight (Iblgal) 9.45 Time Log Start End Cum our End Depth Time Time Dur (hr) (hr) Phase Opr. Act. Plan Oper. Descr. (ftKB) 00:00 1000 10.00 10.00 DRILL E 4 P Run in hole with 5.5" slatted production liner F1206' T/9,303'.SO=90k 22,110.0 10:00 11:30 1 50 11 50 DRILL E 4 P Make up hanger assembly, cross overs and pup F/9,302' T/9,355' Clear floor and change over to 4 %" drill 22,110.0 pipe handling equipment 11:30 14:00 2.50 14.00 DRILL E 4 P Run in hole with 5 %" slotted production liner on 4 X" drill pipe F/9,355' T/12,675'. SO=95k. 22,110.0 1400 16:00 2.00 16.00 DRILL E 4 P Change out handling equipment to 5' drill pipe and establish parameters. PU=142k, SO=95k, RT= 120k, 20 22,110.0 rpm, TQ=1 Ok, 100 gpm Run in hole with no rotation/12,675' T/12,782' set down 15k Pull Up T/12,761 (top of seal bore assembly). Rotate down at 10 rpm, 100 gpm F/12,761' T/12 781' and tag with 101k. Make several attempts and unable to pass through Seal Bore Assembly. 1600 16:30 0.50 16.50 DRILL E 4 1 U Pump out of hole F/12,782' 7112,675' with 100 gpm, racking back 5" drill pipe in derrick. 22,110.0 16:30 1800 1 50 18.00 DRILL E 20 U Blow down top drive. Change out savers sub from 5" to 4 WDelta 425 Change out pipe handling equipment to 22,110.0 4 Y". Static fluid loss rate = 5 bph 1800 23:30 5.50 23.50 DRILL E 4 U Pump out of hole with 4 W drill pipe F/12,675' T/9,500' with 200 gpm, 180 psi at 30-50 fi/min., PU=1251, 22,110.0 2330 0000 0.50 24 00 DRILL E 4 U Pump out of hole F/9,500' T/9.410' at 3 fUmin with 200 gpm at 160 psi PU=129k 22,110.0 Losses to hole last 24 hours=9 BBL, Max gas last 24 HRS 3 units, average gas 1 units Sent 5 %' production liner joint to Baker to be slightly bent for next run Gas Readings Avg Background Gas I%) Max Background Gas (%) Avg Connection Gas I%) Max Connection Gas (%) 1.00 3.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas I%) 0.00 0.00 0.00 0.00 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gap Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (slgt) 22,110.0 9.45 51 32 25 16 7 6 19.0 13.005 55 Gel (10s) (Ibf/1... Gel (10m) (Ibfli.. Gel (30m) (Ibf/1... n K Filtrate (mL130... FC (1132") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.28 19.417 0.0 0 4,5 1 150.0 500.0 PH pH Method Pm (mUmL) Pf (mL/mL) Mf (mL/mL) Sand (%) Solids I%) H2O I%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.700 0.1 12.5 24.0 63.5 72.6/27.4 Brine fblgal) LGS (%) HGs (%) Barite (Ib/bbl) Chlorides (mglL) Calcium (mgll-) Mg (mglL) Pot (mg/L) C.C12 (ppm) Electric Stab (V) Ex. Lime fb/bbp 10.60 6.2 3.5 66,500.000 10.000 30 672.0 3.5 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/21/2019 Report #: 13 Page: 2 of 3 Mud Type: LVT - FazePro - 73%01IRatio Depth (ftKB) Density (Iblgal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc lop) YP Cato (Ibf/10... Vis (slgt) 22,110.0 9.45 51 32 25 16 7 6 19.0 13.005 55 Gel (10s) (Ibf/1- Gel (10m) (Ibf/1... Gel (30m) (Ibfl1 ... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 U. 7.003 0.28 19.417 0.0 0 4,5 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (mL/mL) Mf (mL/mL) Sand I%) Solids (%) H2O I%) Percent Oil (%) Oil Water Ratio MST (I1o1641) Titrated 2.700 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Ib/gal) LGS I%) HGS I%) Barite (Ib/bbl) Chlorides (mglL) Calcium (mg/L) Mg (mg/L) Pot (mg/1-) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.6 66,000.000 0.000 1 30 681.0 3.5 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Iblgaq Vis 600rpm Vis 300rpm Vis 200rpm Vis t00rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.45 51 32 25 16 7 6 19.0 13.005 55 Gel (10s) Qbf/1... Gel (10m) (Ibf/1.. Gel (30m) (Ibfl1... n K Filtrate (mL130... FC (1/32") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.28 19.417 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (mL/mL) Mf (mL/mL) Sand (%) Solids I%) H2O I%) Percent Oil I%) Oil Water Ratio MST (Ib/bbl) Titrated 2.700 0.1 12.5 24.0 63.5 72.6/27.4 Brine (lb/gal) LGS (%) HGS (%) Barite (lb/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/1-) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.5 66,500.000 0.000 30 663.0 3.5 Mud Type: LVT - FazePro - 73% 011 Ratio Depth (ftKB) Density (ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (slqt) 22,110.0 9.45 51 32 25 16 7 6 19.0 13.005 56 Gel (10s) (Ibf/1... Gel (10m) (Ibfl1... Gel (30m) (Ibf/l ... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate I- HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.28 19.417 0.0 0 4.5 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (nri Mf (mL/mL) Sand (%) Solids I%) H2O I%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.700 0.1 12.5 24.0 63.5 72.6/27.4 Brine (16/gal) LGS I%) HGS (%) Barite (Iblbbl) Chlorides (mgll-) Calcium (mg/L) Mg (mg/L) Pot mg/L) C.C12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.5 66,500.000 0.000 30 671.0 3.5 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,617.6 Loss 9.0 Tank 503.7 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 2,121.3 1,617.6 0.0 0.0 9.0 580.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Ent representative Bruce Simonson Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb Eni Drilling Supv. siddrilling@ent.com 907-685-0715 Drilling Engineer Amjad Chaudhry Eni Drilling Engineer Eni representative Mitch Billington Em Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Ent representative Cory Houghton Em HSE Ent representative Robert Gonzolez Enr HSE Drilling Supt Sam Dye Doyon Drilling Field Superintendent Tool Push Einer Fleagle Doyon Drilling Tool Push Tool Push Ted Kruger Doyon Drilling Tour Pusher rig 15@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyonddiling.com 685-0796 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Baker Liner Hanger 12.50 1 Drilling Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Eni Engineer 12.50 1 Drilling Northern Oilfeiid Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling RPS Geologist 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling SLB Cement 12.50 2 Drilling SL8 Directional Driller 12.50 2 Drilling SLB MWD 12.50 2 Drilling K&M ERD 12.50 2 Drilling GBR Casing 12.50 3 Drilling Competenfta Logistic 12.50 4 SID Support Purcell Security 12.50 5 SID Support MI Swaco Mud Plant 12.50 6 Drilling MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 12 SID Support Worley Truck driver / Crane operator 12.50 16 Drilling Doyon Rig Personnel 12.50 26 Drilling_Total Drilling Personnel BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 8/7/2019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular GK 500 13585,0000 5I1/20153 1/2 "- 6" VBR ril MPL5000 13 518 5,000.0 6/24/2018 Blind Shear Ram �IHyddnl ril MPL 5000 135/8 5,000.0 8/24/2018 4 1/2" x 7" VBR nl MPL 5000 13 518 5,000.0 5/1/2015 Selected table Well Name: SP03-NE2 L1 OR(A) Dail Report has no valid Wellbore Name: SP03-NE2 L1 y p attachments that can be Well Code: 32145 Date: 10/21/2019 displayed Job: DRILLING Report #: 13 WCEI Level: 3 Page: 3 of 3 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date 8/27/2019 Liner Size 6 (in) Volume Per Stroke Override (bbl/s[k) Max Pressure (psi) 0.113 5, 323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 10/14/2019 10114/2019 22,110.0 22,110.0 Y-22 Yes 30 450.0 590.0 1 1 Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date 8/27/2019 Liner Size 6 (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 0.113 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) I P (psi) Eff I%) Q Flow (gpm) 10/14/2019 10/14/2019 22,110.0 22,110.0 Yes Yes 22 30 460.0 600.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date 8/27/2019 Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 0.102 4,66,5 Date Depth (ftKB) Slow Spit Strokes (spm) P (psi) Eff (!) Q Flow (gpm) 10/1412019 10/14/2019 22,110.0 Yes Yes 29 39 450.0 600.0 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed 10/21/2019 1,491.0 1,491.0 13,577,0 Cum Received 13,577.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed 10/21/2019 198.0 198.0 2,574.0 Cum Received 2,574.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed 10/21/2019 1,513.0 0.0 35,080.0 Cum Received 50,1810 Cum Returned Cum On Loc 0.0 15,101.0 Note Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed 10/21/2019 34.0 0.0 936.0 Cum Received 1,156.0 Cum Returned Cum On Loc 0.0 2200. Note Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed 10/21/2019 42.0 42.0 54711 Cum Received 546.0 Cum Returned Cum On Loc 0.0 0.0 Notc Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: DateConsumed Received Returned Cum Consumed 10/21/2019 0.0 0.0 1,344.0 Cum Received 1,344.0 Cum Returned Cum On Loc OA 0.0 Note Last Authority Visit Date I Tot insp. Nbr I Total I.N.C. number I Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling Doyon Dulling Inc. Doyon Drilling Inc. Doyon Drilling Inc. MI Swaco MI Swaco 11 11 37 11 8 8 PJSM'S COW Safe Cards HRWS RIR's HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/22/2019 Report At: 14 Page: 1 of 3 Well Header Permit/Concesswo N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Cc Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.60 13.10 16.34 37.26 31 76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 9/2772019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB MD @ Report Time (ft... TVD @ Report Time (it 22,110.0 14,000A a.00 120 Weather Temperature (°F) Wind Days LT (days) Days RI (days) Days From Spud (days) Cloudy 26.6 E @ 15 MPH 725.00 725.00 0.00 Safety Incidents - Near Miss Date I Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Accumulator Drill 1 10716/2019 10/30/2019 8 BOP Pressure Test 1 10/92019 10123/2019 1 Camp Evac Drill 1 10/1012019 1/812020 78 Fire Drill 2 1021/2019 1114/2019 13 Kick While Tripping Dnli 2 1020/2019 1027/2019 5 Rig Inspection 14 10/22/2019 1023/2019 1 Safety Meeting 14 10/222019 1012312019 1 Spill Drill 4 10/16/2019 10/302019 8 TT Camp Evac Drill 1 10/14/2019 1/12/2020 82 TT 1-12S Drill 1 10/9/2019 10/10/2019 -12 TT Island Evacuation Drill 1 1022/2019 1/20/2020 90 TT Kick While Drilling 1 10/1112019 10/18/2019 d TT Kick While Tripping 1 10/15/2019 10/22/2019 0 TT Man Down Drill 1 10/19/2019 1/17/2020 87 TT Rig Evacuation Drill 2 1022/2019 1/2012020 90 TT Stripping Drill 1 1020/2019 1/18/2020 88 TT Well Kill Drill 1 10/19/2019 1/17/2020 87 Survey Data Date MD (ftKB) Inc'(*) Azm (°) TVD (ftKB) VS (ft) NS (ft) EW (ft) DLS (°I100ft) Method 10/15/2019 21,943 77 90.68 319.96 4,001.65 18,408,55 16,767 79 -9,403.36 1.74 MWD 10/15/2019 22,037.07 90.32 319.65 4,000.84 18,501.36 16,839.05 -9,463.57 0.51 MWD 10/15/2019 22,110.00 90.32 319.65 4,000.43 18,573.93 16,894.63 -9,510.79 0.00 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (fdhr) DRILLING 22,100.0 3,992.7 9,290.00 62.54 148.5 Daily Summary Operations 24h Forecast RIH with 5 1/2" slotted liner on drill pipe as per plan, pick up 9 518" storm packer, hang off string Rig up and test ROPE as per permit. 24h Summary Continue pumping drill pipe out of hole to hanger at 9302', Rig up casing equip and lay down hanger and pull out of hole with 5.5" liner to surface Make up slightly bent shoe joint and run in hole with 5'/," 15.5# L- 80 slotted production liner F/surface T/5,715'. Operation at 07.00 Running in hole with 5 1/2" liner at 12,865' MD Lithology Shows Mud Weight (Iblgal) 9.45 Time Log Start End Cum our End Depth Time Time Dur (hr) (hr) Phase Opr. Act. Plan Oper. Descr. (ftKB) 0000 00-30 0.50 0.50 DRILL E 4 U Continue pumping out of hole f/9410' t/9355', 200gpm 160 psi 3 fpm as per schedule, PUW=125k. 22,110.0 00:30 01.30 1.00 1.50 DRILL E 4 U Rig up GBR power tong and handling equipment, lay down hanger and XO 22,110.0 0130 1600 14.50 16.00 DRILL E 4 U Continue to pull out of hole laying down 5.5" liner f/ 9302' to surface. 22,110.0 16:00 1700 too 17.00 DRILL E 4 U Clean and clear floor. Test GBR tongs Prepare pipe shed for liner run 22,110.0 17'00 0000 7.00 24.00 DRILL E 4 P Make up slightly bent shoe joint and run in hole with 5 %" 15.5# L-80 slotted liner F/surface T/5,715' PU=98k, 22,110.0 SO=90k. Losses to hole last 24 hours= 22 bbls, total losses including original hole =1,840.5 bbls, Max gas last 24 HRS 0 units, average gas 0 units. 24 hour metal recovery= 0 LBS, 288.75 LBS Total of metal recovered from ditch magnets Gas Readings Avg Background Gas I%) Max Background Gas I%) Avg Connection Gas I%) Max Connection Gas I%) Avg Drill Gas (%) Max Drill Gas I%) Avg Trip Gas M Max Trip Gas I%) Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (lb/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis t00rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (slgt) 22,110.0 9.45 51 33 25 16 7 6 18.0 15.006 55 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1... Gel (30m) (Ibf/1... n K Filtrate (mL/30... FC (1132") HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.28 19.417 0.0 0 4.5 1 150.0 500.0 PH pH Method Pm (.U.L) Pf (mL/mL) Mf (mL/mL) Sand (%) Solids (%) H2O I%) Percent Oil I%) Oil Water Ratio MST (Iblbbl) Tinted 2.700 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Iblgal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mglL) Pot (mgll-) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 36 66,000.000 0.000 30 670.0 3.5 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/22/2019 Report #: 14 Page: 2 of 3 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis t00rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.45 51 33 25 16 7 6 18.0 15.006 55 Gel (los) (I1of/1... Gel (10m) (Ibf/l... Gel (30m) (Ibfl1... n K Filtrate (ml -130... FC (1/32") HTHP Filtrate I- HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.28 19.417 0.0 0 4,4 1 150.0 500.0 PH pH Method Pm (mL/mL) Pf (mL/.L) Mf (.L/mL) Sand (%) Solids I%) H2O I%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.700 0.1 12.5 24.0 63.5 72.6/27.4 Brine (Ib/gal) LGS (%) HGS I%) Barite lb/bbl) Chlorides (mglL) Calcium (ni Mg (mg1L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.6 66,000.000 0.000 1 30 659.0 3.5 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (lb/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibfl10... Vis (slgt) 22,110.0 9.40 52 33 25 16 7 6 19.0 14.006 55 Gel (10s) (Ibf/1... Get (10m) (Ibf/1... Gel (30m) (Ibf/1... In K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.28 19.417 0.0 0 4.5 1 150.0 500.0 PH pH Method Pm (mUmL) Pf (mL/mL) Mf (mL/mL) Sand (% i Solids (%) H2O I%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.700 0.1 12.5 24.0 63.5 72.6127.4 Brine (Ib/gal) LGS (%) HGS I%) Barite (Ib/bbl) Chlorides (mglL) Calcium (mg/L) Mg (mglL) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Iblbbl) 10.60 6.1 3.7 65,500.000 0.000 30 664.0 3.5 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (CP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.45 52 33 25 16 7 6 19.0 14.006 56 Gel (los) (Ibfl1... Gel (10m) (Ibfl1 .. Gel (30m) (Ibfl1 ... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.28 19.417 0.0 0 4.5 1 150.0 500.0 PH pH Method Pm (mUmL) Pf (m L1mL) Mf (mL/mL) Sand (%) Solids I%) H2O I%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) Titrated 2.700 0.1 12.5 24.0 63.5 72.6127.4 Brine (Ib/gal) LGS I%) HGS I%) Barite (Ib/bbl) Chlorides (mglL) Calcium (mg/L) Mg (mg1L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Iblbbl) 10.60 6.2 3.6 66.000.000 0.000 30 660.0 3.5 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,637.7 Loss 22.0 Tank 455.6 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbi) Cu. Additions (bbl) Losses (bbl) Cum Losses (bbl) 2,093.3 1,637.7 0.0 0.0 22.0 602.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson Eni Drilling Supv_ siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb Em Drilling Supv. siddrilling@eni.com 907-685-0715 Drilling Engineer Amjad Chaudhry Eni Drilling Engineer Eni representative Mitch Billington Eni Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Eni representative Cory Houghton Eni HSE Eni representative Robert Gonzolez Eni HSE Drilling Supt Sam Dye Doyon Drilling Field Superintendent Tool Push Einer Fleagle Doyon Drilling Tool Push Tool Push Ted Kruger Doyon Drilling Tour Pusher rig 15@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Dave Sena Doyon Drilling HSE dsena@doyonddlling.com 685-0796 Personnel Log (POB) Company Sow. Type Work H (hr) Stand-by H (hr) Count Note ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Baker Liner Hanger 12.50 1 Drilling Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Eni Engineer 12.50 1 Drilling Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco(BHGE) WellHead 12.50 1 Drilling RPS Geologist 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB Directional Driller 12.50 2 Drilling SLB MWD 12.50 2 Drilling K&M ERD 12.50 2 Drilling GBR Casing 12.50 3 Drilling Competentia Logistic 12.50 4 SID Support Purcell Security 12.50 5 SID Support MI Swaco Mud Plant 12.50 6 Drilling MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 12 SID Support Worley Truck driver / Crane operator 12.50 16 Drilling Doyon Rig Personnel 12.50 26 Drilling_Total Drilling Personnel BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 8/72019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) I Last Cert Date Annular Hydril GK 500 13 518 5,000.0 5/1/2015 3 1/2 "- 6" VBR Hydril MPL 5000 13 518 5,000.0 8/24/2018 Blind Shear Ram Hydril MPL 5000 13 5/8 5,000.0 8/24/2018 4 1!2" x 7" VBR Hydril MPL 5000 13 5/8 5,000.0 5/1/2015 Selected table Well Name: SP03-NE2 L1 CIR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10I22I2019 displayed Job: DRILLING Report#: 14 WCEI Level: 3 Page: 3 of 3 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date 8/27/2019 Liner Size 6 (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 0.113 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/1412019 10174/2019 22,110.0 22,110.0 Yes Yes 22 30 450.0 590.0 Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date 8127[2019 Liner Size 8 (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 0.113 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/14/201922,110.0 10/14/2019 22,110.0 Yes Yes 22 30 460.0 600.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date 8/27/2019 Llner Size 6 (in) Volume Per Stroke Override (bbl/stk) I Max Pressure (psi) 0.102 4.665.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/14/2019 10/14/2019 22,110.0 Yes Yes 29 39 450.0 600.0 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed 10122/2019 935.0 935.0 14.512.0 Cum Received 14,512.0 Cum Returned Cum On Loc C) "I'm 0.0 No[e Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date ed Received Returned Cu- Consumed Consum 10/22/2019 198.0 198.0 2,772.1) Cum Received 2,772.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed 10Y22/2019 1.429.0 0.0 36,509.0 Cum Received 50,181.0 Gum Returned Cum On Loc 0.0 13,672.0 Note Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed 10/22/2019 58.0 315.0 994.0 Cum Received 1,471.0 Cum Returned Cum On Loc 0.0 477.0 Note Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed 10/22/2019 42.0 42.0 588.0 Cum Received 588.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed 10/22/2019 0.0 0.0 1,344.0 Cum Received 1,344.0 Cum Returned Cum On Loc 0.0 0.0 Note Last Authority Visit Date I Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. MI Swaco Ml Swaco 3 3 20 3 8 8 PJSM'S HRWS Safe Cards COW RIR's HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 L1 OR(A) Dail Report has no valid Wellbore Name: SP03-NE2 L1 y p attachments that can be Well Code: 32145 Date: 10123/2019 displayed Job: DRILLING Report #: 15 WCEI Level: 3 Page: 1 of 3 Well Header PermitlConcession W Operator Subsitliary Initial Lahee Code ADL -392938 ENI PETROLEUM IENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (k) - Base Flange (ft) RKB - Tubing Spool (ft) 53.60 13.10 IRKS I 16.34 37.26 31.76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Dale Rig Release Date RIG 15 DOYON LAND RIG 0723 9/27/2019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB MD @ Report Time (ft... TVD @ Report Time (ft... 22,110.0 4 [)00.4 0.00 112-0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Overcast 22.1 SE @ 9 MPH 726.00 726.00 0.00 Safety Incidents - Near Miss Date Category Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Accumulator Drill 1 10/1612019 10/30/2019 7 BDP Pressure Test 1 10/92019 10/23/2019 0 Camp Evac Drill 1 10/102019 1/8/2020 77 Fire Drill 2 10/21/2019 11/4/2019 12 Kick While Tripping Drill 2 10/20/2019 10/27/2019 4 Rig Inspection 15 10/2312019 1024/2019 1 Safety Meeting 15 10/232019 10242019 1 Spill Drill 5 10/23/2019 11/6/2019 14 TT Camp Evac Drill 1 10/142019 1/12/2020 81 TT 1-12S Drill 2 10232019 1024/2019 1 TT Island Evacuation Drill 1 10/22/2019 1/20/2020 89 TT Kick While Drilling 1 10/112019 10/18/2019 -5 TT Kick While Tripping 1 10/152019 10/22/2019 -1 TT Man Down Drill 1 10/19/2019 1117/2020 86 TT Rig Evacuation Drill 2 1022/2019 1/20/2020 89 TT Stripping Drill 1 1020/2019 1/18/2020 87 TT Well Kill Drill 1 10/19/2019 1/17/2020 86 Casings seat Cas. Type OD (in) ID (in) I Grade Top (ftKB) I Bottom (ftKB) I TVD Bot. (ftKB) Landing Date LINER 5 1121 4.95 1 L-80 12,755.0 II 4,000.5 10/23/2019 Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD (ftKB) Vs (ft) NS (ft) EW (ft) DLS (°I100ft) Method 10/15/2019 21,94377 90.68 319.96 4,001.65 18,408.55 16,767.79 -9,40336 174 MWD 10/15/2019 22,037.07 90.32 319.65 4,000.84 18,501.36 16,839.05 -9,46357 0.51 MWD 10/15/2019 22,110.00 90.32 319.65 4,000.43 18,573.93 16,894.63 -9,510.79 0.00 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (ft/hr) DRILLING 22,100.0 3,992.7 9,290.00 6254 148.5 Daily Summary Operations 24h Forecast Rig up and test BOPE as per permit Rig down test equipment. Rig up and run in hole with LEM/SLZXP with slim pulse MWD to verify orientation 24h Summary Continue to run in hole with 5.5" liner F/5,715' T/9,300' Make up hanger and continue to run in hole with 5 5" liner on 4.5"drill pipe F/9,300 T/12,870 Change out saver sub and handling equip. to 5" DP Continue to run in hole with 5.5" liner on 5" drill pipe to 21,800' without rotation, run in hole and snap in hanger and pump release ball and set, leaving hanger top at 12,758.95' Pull out of hole and lay down running tool Clear floor, drain stack and rinse. Pull wear bushing. AOGCC Melvin Rixse granted an extension to allow us to get out of hole with Drill pipe and running tool before testing BOPE. Operation at 07.00 Testing SOP's. Lithology ShowsMud Weight (iblgal) 9.45 Time Log End Cum our End Depth Time Dur(hr) (hr) Phase Opc Act. Plan Open Descr. (ftKB) 0300 3.00 3.00 DRILL E 4 P Run in hole with 5 %" 15.5# L-80 slotted liner production completion T15,715'to 9,300'. 22,110.004:00 1.00 4.00 DRILL E 4 P Make up liner hanger assembly f/9300 to 9342' PUW=120k SOW=90k. 22,110.0 rTime 0600 2.00 6 00 DRILL E 4 P RIH with liner on 4 5" DP 1/9342' Ui2,870' 22,110.0 0800 2.00 8.00 DRILL E 20 P Change saver sub on top drive from DELTA 425 to TT525, change outjaws and bell guide, change to 5" DP 22,110.0 handling equipment14-00 6.00 14.00 DRILL E 4 P Can RIH w/ liner on 5" DP from 12870'to 21,832'. 22,110.0 1400 15:00 1.00 15.00 DRILL E 4 P Stage up pumps to 3 bpm, 315 psi, 40 rpm, TO=171,, PU=2001,, RT=120k. Was clown F/21,832' 7/21,920', 22,110.0 washing profile 3 times. Continue to rotate down with no pumps F/12,920' T22,100', set down and snap in with 10 k down, snap out with 40 k over pull, set back down with 10 k 15:00 16:30 1.50 16 50 DRILL E 19 P Drop 1 M" release ball pump to seat with 3 bpm at 315 psi, slowing rate down prior to ball seating. Pressure up 22,110.0 to 2900 psi and release from hanger on second attempt, PU=160k, S0=1101, Top of hanger at 12,755'. 16:30 21 00 4.50 21.00 DRILL E 4 P Pull out of hole with running tool F/12,835' 713,607racking back 5" drill pipe. 22,110.0 Note AOGCC Brian Bixby arrives to witness BOP Test at 19:00. 21.00 2230 1.50 22.50 DRILL E 4 1P Continue pulling out of hole racking back 4'/:" drill pipe F/3607' T/92' 22.110.0 22:30 2300 0.50 23.00 DRILL E 4 P Pull out of hole F/92' T/surface, laying down running too). 22,110.0 2300 2330 0.50 23.50 DRILL E 1 P Clean and clear floor Blow down top drive. Drain BOP stack and flush with fresh water while functioning 22,110.0 annular and rams 2330 0000 0.50 24.00 DRILL E 19 P Pull, wear bushing. 22,11 D.0 Loses to hole last 24 hours=16 BBL, total lost to hole including original hole 1,856.5 bbis, Max gas last 24 HRS 4 units, average gas 1 units 24 hour metal recovery= 0 LBS. 82 LBS Total of metal recovered from ditch magnets Selected table Well Name: SP03-NE2 L1 CIR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10123/2019 displayed Job: DRILLING Report #: 15 WCEI Level: 3 Page: 2 of 3 Gas Readings Avg Background Gas (%) Max Background Gas I%) Avg Connection Gas I%) Max Connection Gas (%) 1.00 4.00 0.00 0.00 Avg Drill Gas I%)Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (%) 0.00 0.00 0.00 0.00 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ibigal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.45 52 33 25 16 7 6 19.0 14.006 56 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1... Gel (30m) (Ibf/1... n K Filtrate (.1130... FC (1/32') HTHP Filtrate I- HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.28 19.417 0.0 0 4.5 1 150.0 500.0 PH pH Method Pm (mU.L) Pf (mUmL) Mf (mL/mL) Sand I%) Solids I%) H2O I%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) 0.0 0 2.700 0.0 0.0 0.1 12.5 24.0 63.5 72.6/27.4 0.0 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mglL) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.2 3.6 0.00 66,000.000 0.000 0.000 0.000 0 662.0 3.5 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22.110.0 9.45 52 33 25 16 7 6 19.0 14.006 56 Get (10s) (Ibf/1... Get (10m) (Ibf/1... Gel (30m) (Ibf/1... n K Filtrate (mL/30... FC (1/32') HTHP Filtrate (... HTHP FC (1/32) T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.28 19.417 0.0 0 4.5 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (mL/mL) Mf (mL/mL) Sand (%) Solids (%) H2O (%) Percent Oil I%) Oil Water Ratio MBT (lb/bbl) 0.0 0 2.700 0.0 0.0 0.1 12.5 24.0 63.5 72.6127.4 0.0 Brine (Ib/gal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 6.1 3.7 0.00 65,500.000 0.000 0.000 0.000 0 656.0 3.5 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (1b/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (sigt) 22,110.0 9.45 52 33 25 16 7 6 19.0 14006 56 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1... Gel (30m) (Ibf/1 ... n K Filtrate (ml -130... FC (1/32') HTHP Filtrate I- HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 6.002 7.003 0.28 19.417 0.0 0 4.5 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (mLJmL) Mf (mL/mL) Sand (%) Solids I%) H2O I%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) 0.0 0 2.700 0.0 0.0 0.1 12.5 24.0 63.5 72,6/274 0.0 Brine (Ib/gal) LGS (%) HGS I%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 1060 6.2 3.6 0.00 66.000.000 0.000 0.000 0.000 0 671.0 3.5 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ibigal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10.., Vis (s/qt) 22,110.0 9.45 53 34 26 17 7 6 19.0 15.006 54 Gel (10s) (Ibf/1... Get (10m) (Ibf/1., Gel (30m) (Ibf/1.. n K Filtrate (mt130... FC (1/32') HTHP Filtrate (... HTHP FC (1/32') T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.297 18.876 0.0 0 4.3 1 150.0 500.0 PH pH Method Pm (mL/mL) Pf (mL/mL) Mf (wUmL) Sand (%) Solids (%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) 0.0 0 2.650 0.0 0.0 0.1 12.5 24.0 63.5 72.6/27.4 0.0 Brine (lb/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Iblbbl) 10.60 5.5 4.3 0.00 65,500.000 0.000 0.000 0.000 0 677.0 3.4 Daily Mud Volumes Tank/AdditioniLoss Type Des Volume (bbl) Hole 1,538.2 Loss 160 Tank 685.7 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl)Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 2,223.9 1,538.2 0.0 0.0 16.0 618.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Drilling Engineer Amjad Chaudhry Eni Drilling Engineer Eni representative Mitch Billington Eni Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Ent representative Cory Houghton Eni HSE Eni representative Robert Gonzolez Eni HSE Toot Push Justin Hays Doyon Drilling Tool Pusher rig 15@doyondrilling.com Tool Push Ted Kruger Doyon Drilling Tour Pusher rig 15@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling. cow 685-0796 Tool Push Scott Simmons Doyon Drilling HSE Personnel Log (POB) Company Se". Type Work H (hr) Stand-by H (hr) Count Note Doyon Field Superintendent 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Baker Liner Hanger 12-50 1 Drilling Beacon Medic 12.50 1 SID Support Eni Engineer 12.50 1 Drilling Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling RPS Geologist 12.50 1 Drilling State of Alaska AOGCC 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12-50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB Directional Driller 12.50 2 Drilling SLB MWD 12.50 2 Drilling KSM ERD 12.50 2 Drilling GBR Casing 12.50 3 Drilling Competenfia Logistic 12.50 4 SID Support Purcell Security 12.50 5 SID Support MI Swaco Mud Plant 12.50 6 Drilling Selected table Well Name: S1303-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 Daily Report attachments Date: 10/23/2019 that can be Well Code: 32145 displayed Job: DRILLING Report #: 15 WCEI Level: 3 Page: 3 of 3 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note MI Swaco ESS Worley Doyon WIF Catering Truck driver / Crane operator Rig Personnel 12.508 12.50 12.50 1250 12 16 26 SID Support SID Support Drilling 1 Drilling _Total Drilling Personnel BOP Stack & Components Description BOP Stack Start Date Last Certification Date Pressure Rating (psi) 8/7/2019 5/l/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) I Last Cert Date Annular :jHylril 3 1/2 "- 6"VBR Blind Shear Ram 4 1/2" x 7" VBR ril ril GK 500 MPL 5000 MPL 5000 MPL 5000 13 5/8 13 518 13 5/8 13 5/8 5,000.0 5,000.0 5,000.0 5,000.0 5/1/2015 8/242018 8/24/2018 5112015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date 8/27/2019 Liner Size (in) 6 Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 0.113 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/14/2019 10/14/2019 22.110.0 22,110.0 Yes Yes 22 30 450.0 590.0 Pump Number; 2 Make: White Star Model: Quatro 2450 Start Date End Date 8/27/2019 Liner Size (in) 6 Volume Per Stroke Override (bbllstk) Max Pressure (psi) 0.113 5,323.0 Date Depth (ftKB) I Slow Spd Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 10(1412079 1071412019 22,110.0 22,110.0 Yes Yes 22 450.0 30 600.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date 8/27/2019 I Liner Size (in) 6 Volume Per Stroke Override (bbllstk) Max Pressure (psi) 0.102 4,665.0 Date Depth (ftKB) I Slow Spit Strokes (spm) P (psi) Eff 1%) Q Flow (gpm) 10/14/2019 10/14/2019 22,110.0 Yes Yes 29 39 450.0 600.0 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received 70123!2019 1.442.0 1,442.0 Returned Cum Consumed Cum Received 15,954.0 15,954.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed I ReceivedReturned 10/23/2019 198.0 198.0 Cum Consumed Cum Received 2,970.0 2,970.0 Cum Returned Cum On Loc 1 0.0 0.0 Note supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received 10/2312019 7,692.0 0.0 Returned Cum Consumed Cum Received 38,201,0 50,181.0 Cum Returned Cum On Loc 0.0 11,980.0 Note Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received 70723/2019 26.0 0.0 Returned Cum Consumed Cum Received 7,020.0 1,471.0 Cum Returned Cum On Loc 0.0 451.0 Note Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received 10/23/2019 42.0 42.0 Returned Cum Consumed Cum Received 630.0 630.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumetl Received 10/23/2019 0.0 0.0 Returned Cum Consumed Cum Received 1,344.0 1,344.0 Cum Returned Cum On Loc 0.0 0.0 Note Last Authority Visit Date Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Co. Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. Ml Swaco MI Swaco 13 13 7 13 8 8 PJSM'S COW Safe Cards HRWS HARC/JSA RIR's General Notes Comment: Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 Daily Report attachments that can be Well Code: 32145 Date: 10/24/2019 displayed Job: DRILLING Report#: 16 WCEI Level: 3 Page: 1 of 3 Well Header Permit/Concession No Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co. Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB - Base Flange (ft) RKB -Tubing Spool (ft) 53.60 13.10 16.34 37.26 31.76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 9/27/2019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (k) Drilling Hours (hr) Avg ROP (ft/hr) POB MD @ Report Time (ft... TVD @ Report Time (ft... 22,110.0 4,000.4 0.00 113.0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Cloudy 21.7 WSW @ 13 MPH 727.00 727.00 0.00 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause I Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Accumulator Drill 2 10/24/2019 11/7/2019 14 Authority Visit 1 10/24/2019 11/2112019 28 BOP Pressure Test 2 10/24/2019 11!7!2019 14 Camp Evac Drill 1 1011012019 1/8/2020 76 Fire Drill 2 10/2112019 11/4/2019 11 Kick While Tripping Drill 2 10/20/2019 1027/2019 3 Rig Inspection 16 10/2412019 1025/2019 1 Safety Meeting 16 10/24/2019 1025/2019 1 Spill Drill 5 1023/2019 11/6/2019 13 TT Camp Evac Drill 1 10/14/2019 1/122020 80 TT H2S Drill 2 10123/2019 10124/2019 0 TT Island Evacuation Drill 1 10222019 12012020 88 TT Kick While Drilling 1 10/1112019 10/18/2019 -6 TT Kick While Tripping 1 10/152019 10/22/2019 -2 TT Man Down Drill 1 10/19/2019 1/17/2020 85 TT Rig Evacuation Drill 2 101=019 1/20/2020 88 TT Stripping Drill 1 10/20/2019 1/18/2020 86 TT Well Kill Drill 1 10/19/2019 1/17/2020 85 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 1121 495 L-80 12,755.0 22,101.0 4,000.5 10/23/2019 Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD (ftKB) VS (ft) NS (ft) EW (ft) DLS (°/t00ft) Method 10/15/2079 21,943.77 90.68 319.96 4,00165 18,408.55 16,767.79 -9,403.36 174 MWD 10/15/2079 22.037.07 90.32 379.65 4,000.84 18,50136 16,839.05 -9,463.57 0.51 MWD 10!1512019 22,110.00 90.32 319.65 4,000.43 18,573.93 16,894.63 -9,510.79 0.00 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (ftfhr) DRILLING 22,100.0 3,992.7 9,290.00 62.54 148.5 Daily Summary Operations 24h Forecast RIH to top of hanger, set SLZXP pick up and verify latch, test backside to 1500 psi for 30 min Cut and slip drilling line Pull out of hole laying down drill pipe, run in hole with drill pipe to top of liner, displace to 9.2 ppg brine, POOH laying down DP 24h Summary Rigup and test BOPE 250/3500. Rig down and blow down lines Install wear bushing Pick up and make up LEM assembly as per Baker, scnoe line to MWD, Run in hole with LEM and packer to -1500' shallow test slim pulse MWD Continue to run in hole T/10,070', filling pipe every 20 stands Operation at 07.00 Preparing to cut & slip drill line. Lithology Shows Mud Weight (Ib/gal) 9.45 Time Log Start End Cum our End Depth Time Time our (hr) (hr) Phase Opr. Act. Plan Oper. Descr. (ftKB) 0000 0230 2.50 2.50 DRILL C 1 P Blow down BOP lines, flush same with H2O, drain stack, install test plug, rig up to test BOPE, hook up test 22,110.0 line, make up test manifold on FOSV and IBOP, flood stack and choke manifold with water 02.30 0500 2.50 5.00 DRILL C 1 P Rig up and shell test stack and choke manifold 22,110.0 0500 1030 5..50 10.50 DRILL C 12 P Test BOPE 25013500 psi with 4.5" & 5" test jointsall tests passed Test witnessed by Brian Bixby of AOGCC 22,110.0 10:30 1200 1 50 12.00 DRILL C 1 P Rig down test equipment, pull test plug, install wear bushing, blow down choke and kill lines. 22,110.0 1200 1430 2.50 14 50 DRILL E 1 P Mobilize BHA components to rig floor and pipe shed, rig up GBR equipment Make up Lem/SLZXP assembly, 22,110.0 I verify orientation and run in hole T/117'. Set SLZXP to shear at 50 k. 1', 16-30 2.00 16.50 DRILL E 4 P Run in hole with 4'/:" drill pipe Fit 17'T/1535. Shallow hole test tools, good test. PU=78 k, SO=73 k, 22,110.0 16.30 00-00 7.50 2400 DRILL E 4 P Continue to run in hole with LenUSLZXP assembly with 5"drill pipe Fl1535' T/10,070' Filling drill pipe every 20 22,110.0 stands Losses to hale last 24 hours=13 BBL. total lost to hole Including original hole 1.870 bbis. Max gas last 24 HRS 2 units, average gas 1 units 24 hour metal recovery= 0 LBS, 288.75 LBS Total of metal recovered from ditch magnets Gas Readings Avg Background Gas I%) Max Background Gas (%) Avg Connection Gas NO Max Connection Gas (%) Avg Drill Gas (%) 1 Max Drill Gas I%) I Avg Trip Gas (%) Max Trip Gas I%) Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/24/2019 Report #: 16 Page: 2 of 3 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.45 53 34 26 17 7 6 19.0 15.006 54 Gel (10s) (Ibf/1... Gel (10m) (lbfl1... Gel (30m) (Ibf11... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate I- HTHP FC (1132') T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.297 18 876 0.0 0 4.4 1 150.0 500.0 PH pH Method Pm (mUmL) Pf (mL/mL) Mf (rri Sand (%) Solids I%) H2O (%) Percent Oil I%) Oil Water Ratio MET (Ib/bbl) 0.0 0 2.700 0.0 0.0 0.1 12.5 24.0 63.5 72.6/27.4 0.0 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (ori Pot (mg/L) CaC12 (ppm) Electric Stab (V) I Ex. Lime (Ib/bbl) 10.60 4.9 4.9 0.00 65,500.000 0.000 0.000 0.000 0 681.0 3.5 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (lb/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (CP) YP Calc (I1of/10... Vis islet) 22,110.0 9.45 53 34 26 17 7 6 19.0 15.006 54 Get (10s) (Ibf/1.,. Gel (10m) (Ibf/1... Gel (30m) (lbfl1... n K Filtrate (mU30... FC (1132") HTHP Filtrate (... HTHP FC (1/32"') T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.297 18.876 0.0 0 4,4 1 150.0 500.0 PIT pH Method Pm (mUmL) Pt (mUmL) Mf (mL/mL) Sand (%) Solids (%) H2O (%) Percent Oil I%) Oil Water Ratio MET (Iblbbl) 0.0 0 2.700 0.0 0.0 0.1 12.5 24.0 63.5 72.6127.4 0.0 Brine (Ib/gal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides mg/L) Calcium (irri Mg (mg/L) Pot (mg/L) C.C12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 4.9 4.9 0.00 65.500.000 0.000 0.000 0.000 0 681.0 3.5 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (eP) YP Calc (Ibf110-- Vis (s/qt) 22,110.0 9.45 53 34 26 17 7 6 19.0 15.006 54 Gel (10s) (Ibf/1... Gel (10m) (I1,1/1.. Gel (30m) (lbfl1... n K Filtrate (mL/30... FC (1132') HTHP Filtrate I- HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0 297 18.876 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mLlmL) Pf (mL/mL) Mf (mL/mL) Sand (%) Solids (%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (lb/bbl) 0.0 0 2.700 0.0 0.0 0.1 12.5 24.0 63.5 72.6/27.4 0.0 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (lb/bbl) 10.60 5.0 4.8 0.00 66.000.000 0.000 0.000 0.000 0 681.0 3.5 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibfl10... Vis (s/qt) 22,110.0 9.45 54 35 27 18 7 6 19.0 16.007 54 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1... Gel (30m) (Ibf/1... n K Filtrate (mL/30... FC (1/32') HTHP Filtrate (... HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.313 18.381 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mLlmL) Pf (mL/mL) Mf (mL/mL) Sand (%) Solids I%) H20(%) Percent Oil (%) Oil Water Ratio MBT (Iblbbl) 0.0 0 2.700 0.0 0.0 0.1 12.5 24.0 63.5 72.6/27.4 0.0 Brine (Ib/gal) LGS (%) HGS (%) Barite (Iblbbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 4.9 4.9 0.00 65,500.000 0.000 0.000 0.000 0 670.0 3.5 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,128.1 Loss 13 0 Tank 642.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 1,770.1 1,128.1 0.0 0.0 13.0 631.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Em representative Mike Grubb Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington Eni Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Eni representative Cory Houghton Eni HSE Eni representative Mark Hubler Eni HSE Tool Push Justin Hays Doyon Drilling Tool Pusher rig 15@doyondrilling.com Tool Push Ted Kroger Doyon Drilling Tour Pusher rig 15@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Scott Simmons Doyon Drilling HSE Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note Doyon Field Superintendent 12.50 0 Drilling Eni Engineer 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Archer Inspection 12.50 1 Drilling Baker Liner Hanger 12.50 1 Drilling Beacon Medic 12.50 1 SID Support Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling RPS Geologist 12.50 1 Drilling State of Alaska AOGCC 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Baker Centrilift ESP Techs 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swam Mud Engineer 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB Directional Driller 12.50 2 Drilling SLB MWD 12.50 2 Drilling K&M ERD 1250 2 Drilling GBR Casing 12.50 3 Drilling Competentia Logistic 12.50 4 SID Support Purcell Security 12.50 5 SID Support MI Swam Mud Plant 12.50 6 Drilling MI Swam WIF 12.50 8 SID Support ESS Catering 12,50 11 SID Support Worley Truck driver / Crane operator 12.50 16 Drilling Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10/2412019 displayed Job: DRILLING Report #: 16 WCEI Level: 3 Page: 3 of 3 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note Doyon Rig Personnel 12.50 26 Drilling_Total Drilling Personnel BOP Stack & Components Description 80P Stack Start Date 8/7/2019 Last Certification Date Pressure Rating (psi) 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular 112 "- 6" VBR Blind Shear Ram 4 1/2" x 7" VBR Hydril Hydril Hydril Hydril T13K 00 00 00 13518 13 5/8 13 518 13 5/8 5,000.0 5,000.0 5,000.0 5,000.0 5/1!20153 8/24/2018 8!24/2018 5/1/2015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date 8/27/2019 Liner Size (in) 6 Volume Per Stroke Override (bbllstk) Max Pressure (psi) 0.113 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/14/2019 10/14/2019 22,110.0 22,110.0 Yes Yes 22 30 450.0 590.0 Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date 8/27/2019 Liner Size (in) 6 Volume Per Stroke Override (bbllstk) Max Pressure (psi) 0.113 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10114/2019 10114/2019 22,110.0 22,110.0 Yes Yes 22 30 460.0 600.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date 8/27/2019 Liner Size (in) 6 Volume Per Stroke Override (bbllstk) Max Pressure (psi) 0.102 14.665.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/14/2019 10/14/2019 22,110.0 Yes Yes 29 39 450.0 600.0 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received 10/24/2019 771.0 771.0 16,725.0 16,725.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item. Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Gum Consumed Cum Received 10/24/2019 1980. 198.0 3,168,0 3,168.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed I Received ReturnedCum Consumed Cum Received 10/24/2019 1,392.0 0.0 39,593.0 50,181.0 Cum Returned Cum On Loc 0.0 10,588.0 Note Supply Item Description: Rig Water Unit Label: bbi Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received 10/24/2019 91.0 135.0 1,1110 1.606.0 Cum Returned Cum On Loc 0.0 495.0 Not, Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received 10/24/2019 42.0 42.0 672.0 672.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: WE Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received 10/24/2019 0.0 0.0 1,344.0 1,344.0 Cum Returned Cum On Loc 0.0 0.0 Note Last Authority Visit Date Tot insp. Nor Total I.N.C. 10/24/2019 number Comment AOGCC Brian Bixby witnessed BOP Test. STOP Cards Submitted Company # Rpts Co. Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. Ml Swaco MI Swaco 4 4 10 4 8 8 1 PJSM'S COW Safe Cards HRWS HARC/JSA RIR's General Notes Comment: Selected table Well Name: SP03-NE2 L1 DR(A) Dail Report has no valid Wellbore Name: SP03-NE2 L1 y p attachments that can be Well Code: 32145 Date: 10/25/2019 displayed Job: DRILLING Report #: 17 WCEI Level: 3 Page: 1 of 3 Well Header Permit/ Concession N' OperatorSubsidiary Initial Lanes Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) -Base Flange (k) RKB -Tubing Spool (ft) 53.60 13.10 IR 16.34 37.26 37 76 Rigs Rig Name ContractorRig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 9/27/2019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (fUhr) POB MD @ Report Time (ft... TVD @ Report Time (ft... 22110.0 14,0004 0.00 114.0 Weather Temperature (°F) Wind Days LTf (days) Days RI (days) Days From Spud (days) Cloudy 25.3 SW @ 6 MPH 728.00 728.00 0.00 Safety Incidents - Near Miss Date Category Type Subtype I Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Accumulator Drill 2 10/24/2019 11/7/2019 13 Authority Visit 1 10/24/2019 11/21/2019 27 BOP Pressure Test 2 10/2412019 11!7/2019 13 Camp Evac Drill 1 10/10/2019 1/8/2020 75 Fire Drill 2 10/21/2019 11/4/2019 10 Kick While Tripping Drill 2 10/20/2019 10/27/2019 2 Rig Inspection 17 10/25/2019 10/26/2019 1 Safety Meeting 17 10/25/2019 1026/2019 1 Spill Drill 5 101232019 11/6/2019 12 TT Camp Evac Drill 1 10/1412019 1/12/2020 79 TT H2S Drill 2 10/232019 121/2020 88 TT Island Evacuation Drill 1 10222019 1/20/2020 87 TT Kick While Drilling 1 10/11/2019 10/18/2019 -7 TT Kick While Tripping 1 10/15/2019 1022/2019 -3 TT Man Down Drill 1 10/19/2019 1/17/2020 84 TT Rig Evacuation Drill 2 1022/2019 12012020 87 TT Stripping Drill 1 10/202019 1118/2020 85 TT Well Kill Drill 1 1011912019 1/17/2020 84 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftKB) I Bottom (ftKB) I TVD Bot. (ftKB) Landing Date LINER 5112 495 L-80 12,755.0 22,101.0 4,000.5 1012312019 Survey Data Date I MD (ftKB) Incl (°) -m n TVD (ftKB) VS (ft) NS (ft) EW (ft) DLS (°/100ft) Method 10/15/2019 21,943.77 90.68 319.96 4,007 65 18,408.55 16,767 79 -9,403.36 174 10!75!2019 22,03707 90.32 319.65 4,000.84 18,50136 16,839.05 -9,46357 0.51 JMWD MWD 10/15/2019 22,110.00 90.32 319.65 4,000.43 18,573.93 16,89463 -9,51079 0.00 MWD Job Information Job Phase Spud Data End Date Target Depth (ftKB) Target Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (ft/hr) DRILLING 22,100.0 3.992.7 9,290.00 62.54 148.5 Daily Summary Operations 24h Forecast Run in hole with drill pipe to top of SLZXP, displace to 9.2 ppg brine. Pull out of hole laying down drill pipe. 24h Summary Continue to run in hole with LEM, latch & set packer, release running tool. Top of packer at 12,679' MD Test backside to 1500 psi F130 mintest held, rig up and cut/slip drilling line Pump ball on seat, rupture burst disk. Pump dry job Pull out of hole laying down drill pipe & racking back drill pipe. Make up mule shoe and magnet BHA and run in hole with pipe from derrick T/3,719'. Operation at 07.00 Displacing well to brine Lithology Shows Mud Weight (Ib/gal) I 9.45 Time Log start End Cum our End Depth Time Time Dur (hr) (hr) Phase Opr. Act. Plan Oper. Descr. (ftKB) 00:00 0200 2.00 2.00 DRILL E 4 P Continue to run in hole with LEM on 5" drill pipe F/10,070' T/12,687' 22,170.0 0200 0430 2 50 450 DRILL E 19 P Obtain MWD survey, run in hole F/12,687' engage LEM to RAM hanger at 12,754', tool face at 39L, PU to 15k 22,110.0 overpull to confirm latch, drop 1,25" ball and pump down, seat ball and pressure up and set packer as per Baker procedure, release running tool as per Baker, pick up and confirm release, top of packer @12,679' MD 04:30 05:30 1 00 5.50 DRILL E 12 P Rig up and test annulus to 1500 psi for 30 min. chartedtest held 22,110.0 05:30 0600 0.50 6.00 DRILL E 19 P Attempt to pressure up and rupture burst disk, unable to pressure up enough to rupture disk due to pumping 22,110.0 past ball on seat. 06:00 0630 0.50 6.50 DRILL E 4 P Lay down singles F/12,679' T/12,594', drop 15" ball 22,110,0 06:30 08:30 2.00 8.50 DRILL E 25 P Slip and cut 112' of drilling line, service and inspect top drive and draw works 22,110.0 0830 1030 2.00 10.50 DRILL E 19 P Pump 1.5" ball on seat, pressure up to 4k with mud pump then to 4800 with test pump, rupture the burst disk, 22,110.0 pump dryjob, blow down choke manifold, kill line and top drive, install stripping rubbers 1030 1530 5.00 15.50 DRILL. E 4 P Pull out of hole laying down 5" DP F/12,594' Tt8,112' 22,110.0 15:30 1700 1 50 17.00 DRILL E 4 PPull out of hole racking back 5" drill pipe F/8,112' T/3,630' 22,110.0 17: 00 21:50 4.00 21.00 DRILL E 4 P Pull out of hole laying down 4'/," drill pipe and running tool F/3,630' T/ surface 22,110.0 21:00 22:00 1.00 22.00 DRILL E 4 P Clean and clear floor Make up magnet and mule shoe BHA and run in hole T/18' 22,110.0 22:00 00:00 2.00 24.00 DRILL E 4 P Run in hole on elevators F/18' T/3,719', PU=700 k, SO=95 k 22,110.0 Gas Readings Avg Background Gas I%) Max Background Gas I%) Avg Connection Gas I%)Max Connection Gas M 1.00 2.00 0.00 0.00 Avg Drill Gas I%) Max Drill Gas I%) Avg Trip Gas I%) Max Trip Gas (% ) 0.00 0.00 0.00 0.00 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/25/2019 Report #: 17 Page: 2 of 3 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (lbf/10.,. Vis (slgt) 22,110.0 9.45 53 34 26 17 7 6 19.0 15.006 54 Gel (10s) (Ibf/1.,. Gel (10m) (Ibfl1 ... Gel (30m) (Ibfl1... n K Filtrate (mL/30... FC (1132') HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.297 18.876 0,0 0 4.4 1 150.0 500.0 pH pH Method Pm (mL/mL) Pf (mL/mL) Mf (mL/mL) Sand (%) Solids (%) H2O (%) Percent Oil (%) Oil Water Ratio MET (Iblbbl) 0.0 0 2.650 0.0 0.0 0.1 12.5 24.0 63.5 72.6/27.4 0.0 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg1L) Mg (mg/L) Pot (mg1L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 4.9 4.9 0.00 65,500.000 0.000 0.000 0.000 0 677.0 3.4 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (lb/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10.., Vis (s/qt) 22,110.0 9.45 53 34 26 17 7 6 19.0 15.006 55 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1... Gel (30m) (Ibf/1... n K Filtrate (mL/30... FC (1/32') HTHP Filtrate (... HTHP FC (1132') T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.297 18.876 0.0 0 4,4 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (mL/mL) Mf (mL/mL) Sand (%) Solids I%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (lb/bbl) 0.0 0 2 650 0.0 0.0 0.1 12.5 24.0 63.5 72.6/27.4 0.0 Brine (Ib/gal) LGS (%) HGS (%) Barite (Iblbbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 4.9 4.9 0.00 65,500.000 0.000 0.000 0.000 0 662.0 3.4 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.45 53 34 26 17 7 6 19.0 15.006 55 Get (10s) (I1of/1... Get (10m) (Ibf/1.. Gel (30m) (Ibf/1... n K Filtrate (m1130... FC (1132') HTHP Filtrate I- HTHP FC (1/32') T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0297 18.876 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (mUmL) Mf (mUmL) Sand (%) Solids (%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (Ib/bbl) 0.0 0 2.650 0.0 0.0 0.1 12.5 24.0 63.5 72.6127.4 0.0 Brine (Ib/gal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg1L) Mg (mglL) Pot (mg1L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 5.0 4.8 0.00 66,000.000 0.000 0.000 0.000 0 671.0 3.4 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (iblgap Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 945 53 34 26 17 7 6 19.0 15.006 54 Gel (10s) (I1:4/1... Gel (10m) (Ibf/1 ... Gel (30m) (Ibf/1... n K Filtrate (ml -130... FC (1/32') HTHP Filtrate (... HTHP FC (1/32') T HTHP (°F) P HTHP (psi) 6.002 7.003 7.003 0.297 18.876 0.0 0 4.4 1 150.0 500.0 PH pH Method Pm (mUmL) Pf (mL/.L) Mf (mUmL) Sand (%) Solids (%) H2O (%) Percent Oil (%) Oil Water Ratio MBT (lb/bbl) 0.0 0 2 650 0.0 0.0 0.1 12.5 24.0 63.5 72.6/27.4 0.0 Brine (Ib/gal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 10.60 4.9 4.9 0.00 65,500.000 0.000 0.000 0.000 0 678.0 3.4 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,165.6 Loss9.0 Tank 51910 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses {bbl) 1,756.6 1 165.6 0.0 0.0 19,0 650.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson Eni Drilling Supv. sidddiling@eni.com 907-685-0715 Eni representative Mike Grubb Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington Eni Rig Clerk AKRigClerksDoyon l 5@eni.com 907-685-0722 Ent representative Cory Houghton Eni HSE Eni representative Mark Hubler Eni HSE Tool Push Justin Hays Doyon Drilling Tool Pusher rig 15@doyondrilling.com Tool Push Ted Kruger Doyon Drilling Tour Pusher rig 15@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Scott Simmons Doyon Drilling HSE Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note Doyon Field Superintendent 12.50 0 Drilling Eni Engineer 12.50 0 Drilling RPS Geologist 12.50 0 Drilling K&M ERD 12.50 0 Drilling State of Alaska AOGCC 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Archer Inspection 12.50 1 Drilling Baker Liner Hanger 12.50 1 Drilling Beacon Medic 12.50 1 SID Support Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (SEGE) WeIlHead 12.50 1 Drilling SLB Directional Driller 12.50 1 Drilling ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB MWD 12.50 2 Drilling Expro Flow back 12.50 2 Drilling ACS Enviromental 12.50 3 SID Support GBR Casing 12.50 3 Drilling Competentia Logistic 12.50 4 SID Support Baker Centrilift ESP Techs 12.50 5 Drilling Purcell Security 12.50 5 SID Support MI Swaco Mud Plant 12.50 6 Drilling MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 11 SID Support Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10125/2019 Report #: 17 Page: 3 of 3 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note Worley Doyon Truck driver / Crane operator12.50 Rig Personnel 12.50 15 27 Drilling Drilling_Total Drilling Personnel BOP Stack & Components Description BOP Stack Start Date 8/7/2019 Last Certification Date Pressure Rating (psi) 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) I Last Cert Date Annular 3 112 "- 6" VBR Blind Shear Ram 4 1/2' x 7" VBR Hydril Hydril Hydril Hydril GK 500 MPL 5000 MPL 5000 MPL 5000 13 5/8 13 5/8 13 5/8 13 5/8 5,000.0 5,000.0 5,000.0 5,000.0 511/2015 8/2412018 8/24/2018 5/12015 Slow Circulation Rates Pump Number: t Make: White Star Model: Quatro 2450 Start Date End Date 8/27/2019 Liner 6 Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 0.113 5,323.0 Date Depth (ftKB) I Slow Spd Strokes (spm) I P (psi) Eft I%) Q Flow (gpm) 10/141201922,110.0 10/14/2019 22,110.0 Yes Yes 22 30 450.0 590.0 Pump Number; 2 Make: White Star Model; Quatro 2450 Start Date End Date 8/27/2019 Liner Size (in) 6 Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 0.113 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) I P (psi) Eff (%) Q Flow (gpm) 10114/2019 10/14/2019 22,110.0 22,110.0 Yes Yes 22 30 1 460.0 600.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date 8/27/2019 Liner Size (in) 6 Volume Per Stroke Override (bbllstk) Max Pressure (psi) 0.102 4.665.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/14/2019 10/1412019 22,110.0 1 Yes Yes 29 39 450.0 600.0 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received 10/25/2019 885.0 885.0 Returned Cum Consumed Cum Received 17,610.0 17,610.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received 1025/2019 198.0 198.0 Returned Cum Consumed Cum Received 3,366.0 3,366.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received 10252019 1,399.0 6,720.0 Returned Cum Consumed Cum Received 40,992.0 56,901.0 Cum Returned Cum On Loc 0.0 115,909,0 Note Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received 10/25/2019 18.0 0.0 Returned Cum Consumed Cum Received 1.,129.0 1,606.0 Cum Returned Cum On Loc 0.0 477.0 Note Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received 10/25/2019 42.0 42.0 Returned Cu. Consumed Cum Received 714.0 714.0 Cum Returned Cum On Loc 0.0 0.0 No[e Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received 10/2572019 0.0 0.0 Returned Cum Consumed Gum Received 1,344.0 1,344.0 Cum Returned Cum On Loc 0.0 0.0 Note Last Authority Visit Date Tot insp. Nbr 1 1112412019 Total LN.C. number Comment AOGCC Brian Bixby witnessed BOP Test. STOP Cards Submitted Company p Rpts Com Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. MI Swaco MI Swaco 8 8 8 9 8 8 PJSM'S COW HRWS Safe Cards HARC/JSA RIR's General Notes Comment: Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10/26/2019 displayed Job: DRILLING Report #: 18 WCEI Level: 3 Page: 1 of 3 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft)' • Base Flange (ft) R1,11,; Tubing Spool (ft) 53.60 1310 16.34 37.26 31 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 9/27/2019 Daily Information End Depth (ftKB) End Depth (TVD) (ftKB) Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr)POB MD @ Report Time (ft... TVD @ Report Time (ft... 22,110.0 4,000.4 0,00 177.0 Weather Temperature (°F) Wind Days LTI (days) Days RI (days) Days From Spud (days) Clear 19.4 SW @ 25 MPH 729.00 729.00 0.00 Safety Incidents - Near Miss Date I Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Accumulator Drill 2 10/24/2019 11/7/2079 12 Authority Visit 1 10242019 11/2112019 26 BOP Pressure Test 2 10/24/2019 11/712019 12 Camp Evac Drill 1 10/1012019 1/812020 74 Fire Drill 2 10/21/2019 11/4/2019 9 Kick While Tripping Drill 2 1020/2019 10/27/2019 1 Rig Inspection 18 10/26/2019 1027/2019 1 Safety Meeting 18 10/26/2019 102712019 1 Spill Drill 5 10232019 11/6/2019 11 TT Camp Evac Drill 2 1026/2019 124/2020 90 TT 1-12S Drill 2 1023/2019 1/21/2020 87 TT Island Evacuation Drill 1 10222019 1202020 86 TT Kick While Drilling 1 10/11/2019 10/18/2019 -8 TT Kick While Tripping 1 10/152019 1022/2019 -4 TT Man Down Drill 1 10/19/2019 1/17/2020 83 TT Rig Evacuation Drill 2 1022/2019 120/2020 86 TT Stripping Drill 1 10120/2019 1/18/2020 84 TT Well Kill Drill 1 10/19/2019 1/17/2020 83 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftKB) I Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1121 495 I L-60 12,755.0I Z2,101.0 4,000.5 11012312019 Survey Data Date MD (ftKB) Incl (°) Azm (°) TVD (ftKB) VS (ft) NS (ft) EW (ft) OLS (°/100ft) Method 10/152019 21,94377 90.66319'.96 4,00165 18,408.55 16,76779 -9,403.36 1.74 MWD 10/15/2019 22,037.07 90.32 319.65 4,000.84 18,501.36 16,839.05 -9,46357 0.51 MWD 10/15/2019 22,110.00 90.32 319.65 4,00043 18,573.93 16,894,63 -9,51079 0.00 MWD Job Information Job Phase Spud Date End Date Target Depth (ftKB) Target Depth (TVD) (ft.. Depth Dr. (MO) (ft) Drilling Time (hr) Avg ROP (fUhr) DRILLING 22,100.0 3,992.7 9,290.00 62.54 148,5 Daily Summary Operations 24h Forecast Continue to pull out of hole laying down drill pipe Clean pits and clear pipe shed Rig up and run completion 24h Summary Continue to run in hole T/ 12,650' with mule shoe and magnet BHA. Prepare and displace well to 9.2 ppg brine Clean under shakers and trip tank Pull out of hole laying down drill pipe F/12,650' T/1,122 Operation at 07.00 Prepanng tools and equipment for completion run. LithologyShows Mud Weight (Ib/gal) 9.20 Time Log Start End Cum our End Depth Time Time Dur (hr) (hr) Phase Can Act. Plan Oper. Descr. (ftKB) 00:00 04-00 4.00 4.00 DRILL E 4 P Continue to run in hole with mule shoe and magnet BHA F/3719' T/12,650' 22,110.0 04:00 10:30 6 50 10,50 DRILL E 9 P PJSM with all involved, pump 40 bbi LVT spacer, flush pumps & lines with brine, clean OBM from rig floor to 22,110.0 prevent cross contamination, spot trucks, displace well to 9.2 ppg brine 7-8 bpm 1100 psi, 110 rpm 9k to, slow pump to deal with interface at surface, clean troughshaker undedlow, and trip tank, monitor well static 1030 17 30 7.00 17 50 DRILL E 4 P Pull out of hole laying down OP f/12,650' to 5.530' 22,110.0 1730 1900 1.50 19.00 DRILL E 25 P Service draw works and ST -100 iron roughneck 1 22,110.0 19:00 00100 5.00 24.00 DRILL E 4 P Continue laying down 5' drill pipe F/5,530' Til, 122'. 22,110.0 Note losses for 24 hours 10 bbis, total lost to hole including original hole 1,899 bbs Gas Readings Avg Background Gas I%) Max Background Gas (%) Avg Connection Gas (%) Max Connection Gas I%) 1.00 1.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas I%) Max Trip Gas l%) 0.00 0.00 0.00 0.00 Mud Type: LVT - FazePro - 73% Oil Ratio Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.45 53 34 26 17 7 6 19.0 15.006 54 Gel (los) (Ibf/1... Gel (10m) (Ibfll.., Gel (30m) (Ibf/1.., n K Filtrate (mtJ30... FC (1132") HTHP Filtrate I- HTHP FC (1132") T HTHP (°F) P HTHP (psi) 6.002 T003 7.003 0.297 18.876 0.0 0 4.4 1 150.0 500.0 pH pH Method Pm (mUmL) Pf (m LlmL) Mf (mLlmL) Sand (%) Solids (%) H2O I%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) 0.0 0 2.650 0.0 0.0 0.1 12.5 24.0 63.5 72.6/27.4 0.0 Brine (Ib/gal) LGS (%) HGS (%) Barite (Ib/bbi) Chlorides (mglL) Calcium (mg/L) Mg (mg/L) Pot (mg/l-) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 1060 4.9 4.9 0.00 65,500.000 0.000 0.000 0.000 0 663.0 3.4 Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/26/2019 Report #: 18 Page: 2 of 3 Mud Type: H2O - KCl/NaCl - 0 Depth (ftKB) Density (lb/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.20 27 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1.. Gel (30m) (Ibf/1... in K Filtrate (mL130... FC (1/32") HTHP Filtrate (... HTHP FC (1/32') T HTHP (°F) P HTHP (psi) 0.000 0.0 0 0.0 0 0.0 0.0 pH pH Method Pm (mL/mL) Pf (mUmL) Mf (mLImL) Sand I%) Solids I%) H2O I%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) 8.0 pH meter 0.000 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Brine (lb/gal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg hil Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 9.20 0.0 0.0 0.00 0.000 0.000 0.000 0.000 0 0.0 0.0 Mud Type: H2O - KC11NaCI - 0 Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22.110.0 9.20 27 Gel (10s) (Ibfl1... Gel (tom) (Ibf/1.. Gel (30m) (Ibfl1... in K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 0.000 0.0 0 0.0 0 0.0 0.0 pH pH Method Pm (mLImL) Pf (mL/mL) Mf (mUmL) Sand (%) Solids I%) H2O (%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) 8.0 pH meter 0.000 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Brine (Ib/gal) LGS I%) HGS (%) Barite (lblbbl) Chlorides (mg/L) Calcium (mg/L) Mg (mgll-) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (lb/bbl) 9.20 0.0 0.0 0.00 0.000 0.000 0.000 0.000 0 0.0 0.0 Mud Type: H2O - KCl/NaCl - 0 Depth (ftKB) Density (Iblgal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (s/qt) 22,110.0 9.20 27 Get (los) (IbrM.. Gel (10m) (Ibf/1_. Gel (30m) (Ibf/1... n K Filtrate (mU30... FC (1/32') HTHP Filtrate I... HTHP FC (1/32") T HTHP (°F) P HTHP (psi) 0.000 0.0 0 0.0 0 0.0 0.0 PH pH Method Pm (mL/mL) Pf (mUmL) Mf (mUmL) Sand I%) Solids (%) H2O (%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) 8.0 pH meter 0.000 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Brine (Iblgal) LGS I%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg1L) Mg (ni Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 9.20 0.0 0.0 0.00 0.000 0.000 0.000 0.000 0 0.0 0.0 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,183.8 Loss 10.0 Tank 142.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 1,325.8 1,183.8 0.0 0.0 10.0 660.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb Enr Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington Ere Rig Clerk AKRigClerksDoyonl 5@eni.com 907-685-0722 Eni representative Cory Houghton Ern HSE Eni representative Mark Hubler Em HSE Tool Push Justin Hays Doyon Drilling Tool Pusher rigl5@doyondrilling.com Tool Push Ted Kruger Doyon Drilling Tour Pusher ogl5@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Scott Simmons Doyon Drilling HSE Personnel Log (POB) Company Se". Type Work H (hr) Stand-by H (hr) Count Note Doyon Field Superintendent 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling SLB Directional Driller 1250 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling SLB Cement 12.50 2 Drilling SLB MWD 12.50 2 Drilling Expro Flow back 12.50 2 Drilling Competentia Logistic 12.50 4 SID Support GBR Casing 12.50 4 Drilling Baker Centrilift ESP Techs 12.50 5 Drilling Purcell Security 12.50 5 SID Support MI Swaco Mud Plant 12.50 6 Drilling MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 11 SID Support Worley Truck driver! Crane operator 12.50 14 Drilling Doyon Rig Personnel 12.50 27 Drilling Total Drilling Personnel BDP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 8/72019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) I Last Cert Date Annular r GK 500 13 518 5,000.0 5/1/2015 3 112 "- 6" VBR MPL 5000 13518 5,000.0 8/242018 Blind Shear Ram ::tHydl:� ril MPL 5000 13 5/8 5,000.0 8/2412018 4 1/2' x7" VBR ril MPL 5000 13 5/8 5,000.0 5/112015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 8/27/2019 6 0.113 5, 323.0 Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 Strokes (spm) attachments that can be Well Code: 32145 Date: 10/26/2019 displayed Job: DRILLING Report #: 18 WCEI Level: 3 Page: 3 of 3 Date Depth (ftKB) Slow Spit Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 10/14/2019 10/14/2019 22,110.0 22,110.0 Yes Yes 22 30 450.0 590.0 Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date 8/27/2019 Liner 6 Size (in) Volume Per Stroke Override (bbl/stk) I Max Pressure (psi) 0.113 5.323.0 Date Depth (ftKB) I Slow Spot Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 10/14/2019 10/14/2019 22,110.0 22,110.0 Yes Yes 22 30 460.0 600.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date 8/27/2019 Liner 6 Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 0.102 4,665.0 Date Depth (ftKB) I Slow Spd Strokes (spm) P (psi) Eff I%)) Q Flow (gpm) 10114/2019 10/14/2019 22,1100 Yes29 Yes 39 450.0 600.0 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Receivetl Returned Cum Consumed Cum Received 10/26/2019 758.0 758.0 18,368.0 18,368.0 Cum 0.0 Returned Cum On Loc 0.0 Note Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received 10/26/2019 198.0 198.0 3,564.0 3,564.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: DateConsumed Received Returned Cum Consumed Cum Received 10/26!2019 2,056.0 0.0 43,048.0 56,901.0 Cum Returned Cum On Loc 0.0 13,853.0 Note Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received 10/26/2019 51.0 0.0 1,180.0 1,606.0 Cum Returned Cum On Loc 0.0 4260 Note Supply Item Description: WIF Bailers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received 10/26/2019 42.0 42.0 756.0 756.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Si— Note: Date Consumed Received Returned Cum Consumed Cum Received 10/26/2019 0.0 0.0 1,344.0 1,344.0 Cum Returned Cum On Loc 0.0 0.0 Note Last Authority Visit Date I Tot insp. Nbr Total I.N.C. number Comment 10/24/2019 AOGCC Brian Bixby witnessed BOP Test. STOP Cards Submitted Company # Rpts Com Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. Ml Swaco MI Swaco 15 15 15 9 8 8 PJSM'S COW HRWS Safe Cards HARC/JSA RR's General Notes Comment: Selected table Well Name: SP03-NE2 L1 OR(A) has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 displayed Job: DRILLING WCEI Level: 3 Daily Report Date: 10/2712019 Report #: 19 Page: 1 of 3 Well Header Permit/Concession W Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Cc Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.60 13 10 116.34 37.26 31.76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON I LAND RIG 0723 9/27/2019 Daily Information End Depth (ft KB) End Depth (TVD) (ftK6) Depth Progress (ft) Drilling Hours (hr) Avg ROP (fUhr)POB MD @ Report Time (ft... TVD @ Report Time (ft... 22,110.0 4,000.4 0.00 114.0 Weather Temperature (°F) Wind Days LTt (days) Days RI (days) Days From Spud (days) Clear 28.9 E @ 28 MPH 730.00 730.00 0.00 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Accumulator Drill 2 10/24/2019 1117/2019 11 Authority Visit 1 10124/2019 11/21/2019 25 BOP Pressure Test 2 10/24/2019 11472019 11 Camp Evac Drill 1 10/10/2019 1/8/2020 73 Fire Drill 2 102112019 11/4/2019 8 Kick While Tripping Drill 2 1020/2019 1027/2019 0 Rig Inspection 19 10/27/2019 1028/2019 1 Safety Meeting 19 10/2712019 102812019 1 Spill Drill 5 101232019 11/6/2019 10 TT Camp Evac Drill 2 10/26/2019 124/2020 89 TT 112S Drill 2 1023/2019 1/21/2020 86 TT Island Evacuation Drill 1 10222019 120/2020 85 TT Kick While Drilling 1 10/11/2019 10/18/2019 -9 TT Kick While Tripping 1 10/152019 1022/2019 -5 TT Man Down Drill 2 10/27/2019 125/2020 90 TT Rig Evacuation Drill 2 10122/2019 120/2020 85 TT Stripping Drill 1 10/2012019 1/18/2020 83 TT Well Kill Drill 1 10119/2019 1117/2020 82 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftK6) I Bottom (RKB) TVD Bot. (RKB) Landing Date LINER 5 1/2 4.95 L-80 12,755.0 22,101()I 4,000.5 10123/2019 Survey Data Date MD (RKB) Incl (°) Azm (") TVD (ftK6) VS (ft) NS (ft) EW (ft) DLS (°1100ft) Method 10/15/2019 21,943.77 90.68 379.96 4,00165 18408.55 16,76779 -9,403.36 1.74 MWD 10/15/2019 22,037.07 90.32 319.65 4,000.84 18,50136 16,839.05 -9,463.57 0.51 MWD 10/15/2019 22,110.00 90.32 319.65 4,000.43 18,573.93 16,894.63 -9,51079 0.00 MWD Job Information Job Phase Spud Date End Date' arget Depth (f[KB) Target Depth (TVD) (ft... Depth Dr. (MD) (ft) Drilling Time (hr) Avg ROP (ft/hr)DRILLING 22,100.0 3,992.7 9,290.00 62.54 148.5 Daily Summary Operations 24h Forecast Drilling phase complete Run completion. 24h Summary Service Rig and ST -100. Pull out of hole laying down drill pipe and BHA F/1,122'T/ surface Operation at 07.00 Drilling phase of the well is complete This will be last drilling report Lithology Shows Mud Weight (Ib/gal) 9.20 Time Log Start End Cum Dur End Depth Time Time our (hr) (hr) Phase Opt. Act. Plan Oper. Descr. (ftK6) 0000 01'.00 1.00 1.00 DRILL E 25 P Rig service while repairing iron rough neck (ST -100). 22.110.0 01:00 0300 2.00 3.00 DRILL E 4 P Continue to pull out of hole laying down drill pipe and BHA F11,122' Tlsurface. 6 lbs of metal on magnet. 22,110.0 Losses to hole last 3 hours=0 BBL, Total BELS lost including original hole=1,899 BELS, Max gast units. average gas 1 units. 6 lbs metal recovered from magnet, total metal recovered 295 lbs Gas Readings Avg Background Gas I%) Max Background Gas I%) Avg Connection Gas I%) Max Connection Gas I%) 1.00 1.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas ( % ) Avg Trip Gas (%) Max Trip Gas (%) 0.00 0.00 0.00 0.00 Mud Type: H2O - KCl/NaCl - 0 Depth (RKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibfl1#27 22,110.0 9.20 0 0 0 0 0 0 0.0 0.000 Gel (10s) (Ibf/1... Gel (10m) (Ibf11... Gel (30m) (Ibf11... n K Filtrate (mL/30... FC (1132") HTHP Filtrate I- HTHP FC (1132") T HTHP(°F)psi) 0000 0000 0.000 00 0 0.0 0 0.0 pH pH Method Pm (mLIml-) Pf (mL/mL) Mf (mLJmL) Sand (%) Solids (%) H2O I%) Percent Oil (%) Oil Water Ratiobl) 80 pH meter 0000 0.0 0.0 0.0 00 0.0 0.0 Brine (Ib/gap LGS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mgiL) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab IV) Ex. Lime (Ib/bbl) 9.20 0.0 0.0 0.00 10000 0.000 0.000 0.000 0 0.0 0.0 I Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10/27/2019 displayed Job: DRILLING Report M 19 WCEI Level: 3 Page: 2 of 3 Mud Type: H2O - KCl/NaCl - 0 Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 1100rpm Vis 6rpm Vis 3rpm Pv Calc (cP) YP Calc (lbf/10... Vis (s/qt) 22,110.0 9.20 0 0 0 0 0 0 0.0 0.000 27 Gel (10s) (Ibf/1... Gel (10m) (lbfl1.. Gel (30m) (I1af/1... n K Filtrate (ml -130... FC (1/32") HTHP Filtrate (... HTHP FC (1132') T HTHP (°F) P HTHP (psi) 0.000 0.000 0.000 0.0 0 0.0 0 0.0 0.0 PH pH Method Pm (mUmL) Pf (mL/mL) Mf (mL/m L) Sand I%) Solids (%) H2O I%) Percent Oil I%) Oil Water Ratio MBT (Ib/bbl) 8.0 pH meter 0.000 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Brine (Ib/gal) LES (%) FIGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mglL) Pot (mgll-) CaC12 (ppm) Electric Stab (V) Ex. Lime (Iblbbl) 9.20 0.0 0.0 0.00 0.000 0.000 0.000 0.000 0 0.0 0.0 Mud Type: H2O - KC!/NaCl - 0 Depth (ftKB) Density (lb/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis t00rpm Vis 6rpm Vis 3rpm PV Calc (cP) YP Calc (Ibf/10... Vis (slgt) 22.110.0 9.20 0 0 0 0 0 0 0.0 0 o0o 27 Gel (10s) (Ibf/1... Gel (10m) (Ibf/1... Gel (30m) (Ibf/1... n K Filtrate (mL/30... FC (1/32') HTHP Filtrate (- HTHP FC (1/32') T HTHP (°F) P HTHP (psi) 0.000 0.000 0.000 0.0 0 0.0 0 0.0 0.0 PH pH Method Pm (mLImL) Pf (mL/mL) Mf (mL/mL) Sand (%) Solids (%) H2O I%) Percent Oil I%) Oil Water Ratio MBT (lb/bbl) 8.0 pH meter 0.000 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Brine (Ib/gal) 1 -GS I%) HGS I%) Barite (lb/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 9.20 0.0 0.0 0.00 0.000 0.000 0.000 0.000 0 0.0 0.0 Mud Type: H2O - KCl/NaCl - 0 Depth (ftKB) Density (Ib/gal) Vis 600rpm Vis 300rpm Vis 200rpm Vis 100rpm Vis 6rpm Vis 3rpm Pv Calc ep) YP Calc (lbf110... Vis (stgt) 22,110.0 920 0 0 0 0 0 0 0.0 0 000 27 Gel (10s) (Ibf/l... Gel (10m) (Ibf/1.. Gel (30m) (Ibf/l ... n K Filtrate (mL/30... FC (1/32") HTHP Filtrate (... HTHP FC (1132') T HTHP (°F) P HTHP (psi) 0-000 0.000 0.000 0.0 0 0.0 0 0.0 0.0 PH pH Method Pm (mLImL) Pf (mLImL) Mf (mLImL) Sand (%) Solids I%) H2O (%) Percent Oil I%) Oil Water Ratio MBT (Iblbbl) 8.0 pH meter 0.000 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Brine (Ib/gal) -GS (%) HGS (%) Barite (Ib/bbl) Chlorides (mg/L) Calcium (mg/L) Mg (mg/L) Pot (mg/L) CaC12 (ppm) Electric Stab (V) Ex. Lime (Ib/bbl) 9.20 0.0 0.0 0.00 0.000 0.000 0.000 0.000 0 0.0 0.0 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,188.6 Loss0 Tank 136.2 Cumulative Mud Volumes Active Volume (bbl)Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 1,324,8 1,188.6 0.0 0.0 1.0 661.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Ent representative Bruce Simonson Eni Drilling Supv. sidddlling@eni.com 907-685-0715 Eni representative Mike Grubb Eni Drilling Supv. siddrilling@ent.com 907-685-0715 Eni representative Mitch Billington Eni Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Eni representative Cory Houghton Eni HSE Eni representative Mark Hubler Ent HSE Tool Push Justin Hays Doyon Drilling Tool Pusher rigs 5@doyondrilling.com Tool Push Ted Kruger Doyon Drilling Tour Pusher rigl5@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Scott Simmons Doyon Drilling NSE Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note Doyon Field Superintendent 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12,50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling SLB Cement 12.50 2 Drilling Competentia Logistic 12.50 4 SID Support GBR Casing 12.50 4 Drilling Baker Centnliff ESP Techs 12.50 5 Drilling Purcell Security 12.50 5 SID Support MI Swaco Mud Plant 12.50 6 Drilling MI Swaco WE 12.50 8 SID Support Expro Flow back 12.50 8 Drilling ESS Catering 12.50 11 SID Support Worley Truck driver / Crane operator 12.50 14 Drilling Doyon Rig Personnel 12.50 27 Drilling_Total Drilling Personnel BOP Stack 8 Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 8/72019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular GK 500 3 5/8 5,000.0 5!1720153 112 "- 6" VBR rHd MPL 5000 13 518 5,000.0 8/242018 Blind Shear Ram MPL 5000 13 5/8 5,000.0 8/242018 4 1/2" x T' VBR MPL 5000 13 5/8 5,000.0 5/7/2015 Slow Circulation Rates Pump Number: i Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 8/27/2019 6 0.113 I 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff I%) Q Flow (gpm) 10!14/2079 22,110.0 Yes 22 450.0 10)14/2019 22,110.0 1 Yes 30 590.0 Selected table Well Name: SP03-NE2 L1 OR(A) Daily Report has no valid Wellbore Name: SP03-NE2 L1 attachments that can be Well Code: 32145 Date: 10/27/2019 displayed Job: DRILLING Report #: 19 WCEI Level: 3 Page: 3 of 3 Slow Circulation Rates Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date 8/27/2019 Liner 6 Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 0.113 5.323.0 Date Depth (ftKB) Slow Spd I Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10/14/2019 10/14/2019 22,110.0 22,110.0 yes Yes 22 30 460.0 11 600.0 Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date 8127!2019 Liner 6 Size (in) Volume Per Stroke Override (bbl/stk) Maz Pressure (psi) 0.102 4,665.0 Date Depth {ftK6) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) 10!14/2019 1 0/1412 01 9 22,110.0 Yes Yes 29 450.0 39 600.0 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received 10/27/2019 119.0 119.0 Returned Cum Consumed Cum Received 1:8,487.0 18,487.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received 10/27/2019 25.0 25.0 Returned Cum Consumed Cum Received 3,589.0 3,589.0 Cum Returned Cum On Loc 0.0 0.0 Note Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: DateConsumed Received 10/27/2019 1,561.0 0.0 Returned I Cum Consumed Cum Received 44,609.0 56,901.0 I Cum Returned I Cum On Loc 0.0 12,292.0 Note Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received 10/27/2019 179.0 135.0 Returned cum consumed Cum Received 1,359,0 1,741.0 Cum Returned Cum On Loc 0.0 382.0 Note Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received 10/27/2019 5.0 5.0 Returned Cum Consumed Cum Received 7610 761.0 Cum Returned Cu. On Loc 1 0.0 0.0 Note Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received 10/27/2019 0.0 0.0 Returned Cum Consumed Cum Received 1,344 C 1,344.0 Cum Returned Cum On Loc 0.0 0.0 Note Last Authority Visit Date Tot insp. Nbr 10/24/2019 Total I.N.C. numberComment P.OGCC Brian Bixby witnessed BOP Test. STOP Cards Submitted Company # Rpts Com Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. Ml Swaco MI Swaco 8 8 24 8 8 B PJSM'S COW Safe Cards HRWS HARC/JSA 1 RIR's General Notes Comment: Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 10/27/2019 Report #: 1 Page: 1 of 3 Well Header PerrniUConcession No Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.60 13 10 16.34 37.26 31 76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 10/27/2019 Daily Information Weather Temperature (°F) Wind Days LTI (days) Days RI (days) POB Clear 28.9 E @ 28 MPH 730.00 730.00 114.0 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause I Lost time? Comment Safety Drills Type # Occur Last Date Next Date Days Until Next Check (days) Rig Inspection Safety Meeting TT Man Down Drill 1 1 1 10/27/2019 1027/2019 102712019 10128/2019 10/28/2019 1/25/2020 7 1 90 Casings seat Cas. Type OD (in) ID (in) Grade Top (RKB) Bottom (RKB) I TVD Bot. (RKB) Landing Date CASING13 CASING 3!8 9 5/8 12.42 8.84 1 L-80 L-80 0.0 0.0 1 2,916.0 12,962.0 1 2,4811 4,096.6 1 7282079 9/1212019 Last Cementing Cementing Start Date: 9/12/2019 String: CASING, 12,962.OftKB Comment: Schlumberger pressure tested to 3500 psi. Rig pump 101 bbls. of 10.0 ppg spacer at 5 bpm rate @ 520 psi, shut down and drop bottom plug. Schlumberger mix and pump 243 bbls. of Lead 12.50 ppg cement at 5 bpm @ 440 psi. Shut down and batch up Tail cement @ 15.8 ppg pumped 56 bbls. with 5 bpm FCP @ 315 psi. Drop top plug and Schlumberger pumped 20 bbls. of water 5 bpm @ 336 psi. Rig displaced with 961 bbls. of 9.4 ppg -SND mud - staging rates down from 8 bpm to 6 bpm @ 700 bbls. to 5 bpm @ 800 hbls. to 4 bpm @ 900 bbls. FCP = 600 psi. No indication of first plug bumping and did not bump top plug at maximum strokes allowed. Shut down pump - pressure stabilized @ 290 psi. Cement in place @ 1600 hrs. Stg # Top (ftK8) Top Meas Meth Bum (ftKB) Com Job Information Job Phase Planned Start Date Start Date End Date P80 Duration (days) COMPLETION 10/27/2019 03:00 10/27/2019 03:00 0.00 Daily Summary Operations 24h Forecast Continue to run completion 24h Summary Rig up to run completion Make up ESP pump and motor assembly make MILE and ESP cable splice. Run in hole with coated tubing T/283' Operation at 07.00 POOH with ESP completion, at 2,104' MD ESP cable was checked and found a fault to ground, pull out of hole checking cable for ground fault. Time Log Start End Cum our Time Time Dur (hr) (hr) Phase Opr. Act. Plan Oper. Descr. 0300 04:00 1.00 1 00 COMP K 1 P Clear floor and pull wear bushing. 04:00 1200 8.00 9.00 COMP K 20 P Bring hanger, clamp boxes, job box, load shed with shroud and ESP components, Make up floor valve, hang ESP and cap sheaves, spot spooling unit and generator, install cable reel in spooler, pull cable & cap tube over sheave to rig floor, pick up 7 5/8" shroud and set in rotary table 12:00 1700 5.00 14.00 COMP K 4 P PU motor and sensor, attach centralizer, lower into shroud, service motor, MU tandem seals connect to motor and check rotation, service seals and remove air from chamber, Make up GASSEP F1 surface T/78' 17100 2030 350 17.50 COMP K 20 P Splice ESP cable to MLE. ENI electrician witness. 20.30 23:00 2.50 20.00 COMP K 20 P Splice capillary line from pump assembly to spooling unit, test cap line T11000 psi, good test Pump through at 3200 psi, good test Simops Repair/replace cap line valve on spooling unit 23:00 0000 1 1.00 21.00 COMP K 4 P I Run in hole with 4'/," 12.6# Hyd 563 coated tubing F/78' T/283' Sit=70k. Losses to hole last 24 hours=l BBL, Total BBLS lost including original hole=l 900 BBLS, Max gas 7 units average gas 1 units Gas Readings Avg Background Gas (%) 1.00 Max Background Gas I%)Avg 1.00 Connection Gas (%) 0.00 Max Connection Gas I%) 0.00 Avg Drill Gas (%) 0.00 Max Drill Gas (%) 0.00 Avg Trip Gas (%) 0.00 Max Trip Gas I%) 0.00 Mud Type: H2O - KCl/NaCl - 0 Depth (RKB) 22,110.0 Density (Ibigal) 9.21 Funnel Viscosity (s/qp 27 PV Calc (cP) 0.0 YP Calc (Ibf/t00ft') 0.000 pH 8.0 Chlorides (mg/L) 0.000 Electric Stab (V) 0.0 Solids (%) 0.0 Sand (%) 0.0 NTU in 0 NTU Out 0 Temp Crystal (°F) 0.0 Oil & Grease 0 Static Sheen 0 Filtration Size (pm) 0 Mud Type: H2O - KCl/NaCl - 0 Depth (ftK8) 22,110.0 Density (lb/gal) 922 Funnel Viscosity (slgt) 27 PV Calc (CP) 0.0 YP Calc (Ibf/100ft') 0.000 pH 8.0 Chlorides (mg/1-) 0.000 Electric Stab (V) 0.0 Solids I%) 0.0 Sand (%) 0.0 NTU in 0 NTU Out 0 Temp Crystal (°F) 0.0 Oil & Grease 0 Static Sheen 0 Filtration Size (pm) 0 Mud Type: H2O - KCI/NaCl - 0 Depth (RKB) 22,110,0 Density {Ib/gal) 9.22 Funnel Viscosity (s/qt) 27 PV Calc (cP) 0.0 YP Calc (Ibf/100ft°) 0.000 pH 8.0 Chlorides (mg/L) 0.000 Electric Stab (V) 0.0 Solids (%) 0.0 Sand (%) 0.0 NTU in 0 NTU Out 0 Temp Crystal (°F) 0.0 Oil & Grease 0 Static Sheen 0 Filtration Size (pm) 0 Mud Type: H2O - KCl/NaCl - 0 Depth (ftKB) 22,110.0 Density (Ib/gal) 9.21 Funnel Viscosity (slgq 27 PV Calc (eP) 0.0 YP Calc (Ibf/100fil 0.000 pH 8.0 Chlorides (mg/L) 0.000 Electric Stab (V) 0.0 SolidsI%) 0.0 Sand (%) 0.0 NTU in 0 I NTU Out 0 Temp Crystal (°F) 0.0 I Oil & Grease 0 I Static Sheen 0 Filtration Size (pm) 0 Daily Mud Volumes TanWAddition/Loss Type Des Volume (bbl) Hole Loss 1.188.6 1.0 Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 10/27/2019 Report At: 1 Page: 2 of 3 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Tank 136.2 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 1,3248 11,1886 0.0 0.0 1.0 1 0 Daily Contacts Position Contact Name Company Title Email Office Mobile Ent representative Bruce Simonson Ent Drilling Supv, siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb Em Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington Eni Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Ent representative Cory Houghton Eni HSE Ent representative Mark Hubler Eni HSE Tool Push Justin Hays Doyon Drilling Tool Pusher rig 15@doyondrilling.com Tool Push Ted Kruger Doyon Drilling Tour Pusher rigl5@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Scott Simmons Doyon Drilling HSE Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note Doyon Field Superintendent 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WeilHead 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling SLB Cement 12.50 2 Drilling Competentia Logistic 12.50 4 SID Support GBR Casing 12.50 4 Drilling Baker Cenbilift ESP Techs 12.50 5 Drilling Purcell Security 12.50 5 SID Support MI Swaco Mud Plant 12.50 6 Drilling MI Swaco WIF 12.50 8 SID Support Expro Flow back 12.50 8 Drilling ESS Catering 12,50 11 SID Support Worley Truck driver 7 Crane operator 12.50 14 Drilling Doyon Rig Personnel 12.50 27 Drilling -Total Drilling Personnel BOP Stack 8 Components Description Start Date Last Certification Date Pressure Rating (psi) SOP Stack 10/24/2019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular Hydril GK 500 135!8 5,000.0 5112015 3 1/2 "- 6" VBR Hydril MPL 5000 13 5/8 5,000.0 8/242018 Blind Shear Ram Hydril MPL 5000 13 5/8 5,000.0 81242018 4 12" x 7" VBR Hydril MPL 5000 13 5/8 5,000.0 5/1/2015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 10/24/2019 e 0.113 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 10/24/2019 6 0.113 5,323.0 Date Depth (ftKB) Slow Spit Strokes (spirit P (psi) Eff (%) Q Flow (gpm) Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (P.010/24/2019 I I 6 I 0.102 4,665.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/272019 834.0 834.0 834.0 834.0 0.0 0.0 Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/27/2019 173.0 173.0 173.0 173.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/27/2019 1,561.0 13,853.0 1,561.0 13,853,0 0.0 12,292.0 Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date lConsurned Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/27/2019 179.0 361.0 179.0 381.0 0.0 202.0 Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: DateConsumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/27/2019 37.0 37.0 37.0 37.0 0.0 0.0 Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/27/2019 0.0 00 0.0 0.0 0.0 0.0 Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION # Rpts WCEI Level: 3 Daily Report Date: 10/27/2019 Report #: 1 Page: 3 of 3 Last Authority Visit Date I Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. MI Swaco Ml Swaco 8 24 8 8 8 8 PJSM'S Safe Cards COW HRWS RIR's HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 10/2812019 Report #: 2 Page: 1 of 3 Well Header Permit/Concession No Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB - Base Flange (ft) • Tubing Spool (ft) IR 53 60 13 10 16.34 37.26 31 76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 10/27/2019 Daily Information WeatherTemperature (°F) Wind Days LTI (days) Days RI (days) POB Partly Cloudy 36.3 SW @ 19 MPH 731.00 731.00 119.0 Safety Incidents - Near Miss Date Category Type Subtype I Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Rig Inspection 2 10/28/2019 10/29/2019 1 Safety Meeting 2 10/28/2019 10/29/2019 1 TT Man Down Drill 1 10/27/2019 1/25/2020 89 Casings seat Cas. Type OD (in) ID (in) Grade Top (RKB) Bottom (ftK6) I TVD Bot. (RKB) Landing Date CASING 13 3(8 12.42 L-80 0.0 2,916.0 2,487 1 7/2812019 CASING 95/8 8.84 1 L-80 0.0 12,962.0 4,096.6 9/12/2019 Last Cementing Cementing Start Date' 9/12/2019 String: CASING, 12,962.0111<6 Comment: Schlumberger pressure tested to 3500 psi. Rig pump 101 bbls. of 10.0 ppg spacer at 5 bpm rate @ 520 psi, shut down and drop bottom plug. Schlumberger mix and pump 243 bbls. of Lead 12.50 ppg cement at 5 bpm @ 440 psi. Shut down and batch up Tail cement @ 15.8 ppg pumped 56 bbls. with 5 bpm FCP @ 315 psi. Drop top plug and Schlumberger pumped 20 bbls. of water 5 bpm @ 336 psi. Rig displaced with 961 bbls. of 9.4 ppg -SND mud - staging rates down from 8 bpm to 6 bpm @ 700 bbls. to 5 bpm @ 800 bbls. to 4 bpm @ 900 bbls. FCP = 600 psi. No indication of first plug bumping and did not bump top plug at maximum strokes allowed. Shut down pump - pressure stabilized @ 290 psi. Cement in place @ 1600 hrs. Stg # Top (ftK6) Top Meas Meth Btm (RKB) I Com Job Information Job Phase Planned Start Date Start Date End DateP50 Duration (days) COMPLETION 10/27/2019 03:00 10/27/2019 03:00 0.00 Daily Summary Operations 24h Forecast Continue to run completion 24h Summary Continue to run in hole with 4 %" coated 12.6#, HYD 563 F/283' T/2,183' Testing cable every 1,000'. Second test of cable was grounded. Pull out of hole and cut 100' cable, splice cable and retest good. Continue to run in hole Operation at 07.00 Running in hole with ESP completion. Time Log Start End Cum Dur Time Time Dur (hr) (hr) Phase Opr. Act. Plan Oper. Descr. 00:00 0630 6.50 6.50 COMP K 4 P Continue to run in hole with 4 Y/, coated 12.6#, HYD 563 F/283' T/2,183' Perform electrical checks on ESP cable Cable was grounded Stripped it back and retested with different meter with same result, still grounded. 0630 11-00 4.50 11 00 COMP K 4 U PJSM for laying down tubing with ESP cable.. Lay herculite between beaver slide and spooling unit Lay down tubing F2,183' T/1, 194' Found damaged area at 1,375' and continued to pull out of hole T/ 1.090, cut 100' cable off and temporary splice to -gather 11:00 1200 1 00 12.00 COMP K 4 U Run in hole F11,090' Tf 1 275to spot temporary cable splice at rig floor Lay out joints #30 and #31 due to damaged coating. PU=75 k 1200 1530 3.50 15.50 COMP K 20 U Splice ESP cable with ENI electrician witness. Tested good. Splice taped and splice clamp/ canon clamp installed. Splice is at 1,275'. 15:30 0000 8.50 24.00 COMP K 4 P Continue to run in hale with coated 4 Y" 12.6# HYD 563 tubing Fl1,275' 714,790'. Testing cable every 1000' Losses to hole last 24 hours=0 BBL, Total BBLS lost including original hole=1,900 BBLS Max gas last 24 HRS 1 units, average gas 1 units Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas (%) Max Connection Gas (%) 1.00 1.00 0.00 0.00 Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (% ) 0.00 0.00 0.00 0.00 Mud Type: H2O - KCl/NaCl - 0 Depth (RKB)Density (Ib/gal) Funnel Viscosity (s/qt) PV Calc (cP) YP Calc (lbf/10011') pH Chlorides (mg/L) Electric Stab (V) 22,110.0 9.20 27 0.0 0.000 8.0 0.000 0.0 Solids I%) Sand (%) NTU in NTU out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) 0.0 0.0 0 0 0.0 0 0 0 Mud Type: H2O - KCl/NaCl - 0 Depth (ftK6) Density (ib/gal) Funnel Viscosity (s/qt) PV Calc (cP) YP Calc (IbU100ft') pH Chlorides mg/L) Electric Stab (V) 22.110.0 9.20 27 0.0 0.000 6.0 0.000 0.0 Solids (%I Sand I%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) 0.0 0.0 0 I 0 0.0 0 0 0 Mud Type: H2O - KCl/NaCl - 0 Depth (ftK6) (Ib/gap Funnel Viscosity (s/qt) PV Cato (cP) YP Calc (lbi/100ft') pHChlorides (mglL) Electric Stab (V) 22,110.0 27 0.0 0.000 8.0 0000 0.0 Solids (%) FDenity (%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) 0 0 0.0 0 0 0 Mud Type: H2O - KCl/NaCl - 0 Depth (ftK6) Density (Ib/gal) Funnel Viscosity (s/qt) PV Calc (cP) YP Calc (Ibf/100fl pH Chlorides (mg1L) Electric Stab (V) 22,110.0 9.20 27 0.0 0.000 8.0 0.000 0.0 Solids I%) Sand I%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) 0.0 0.0 0 0 0.0 0 0 0 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,169.0 Loss 0.0 Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION Type WCEI Level: 3 Daily Report Date: 10/28/2019 Report #: 2 Page: 2 of 3 Daily Mud Volumes TanklAddition/Loss Type Des Volume (bbl) Tank 156 0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 1,325.0 1,169.0 OA 0 0 0.0 1 0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson Eni Drilling Sup, siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mitch Billington Eni Rig Clerk AKRigClerksDoyonl 5@eni.com 907-685-0722 Eni representative Cory Houghton Eni HSE Eni representative Mark Hoofer Eni HSE Tool Push Justin Hays Doyon Drilling Tool Pusher rig 15@doyondrilling.com Tool Push Ted Kruger Doyon Drilling Tour Pusher rigl5@doyondrilling.com 907-685-0716 Tool Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Scott Simmons Doyon Drilling HSE Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note Doyon Field Superintendent 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Northern Oilfelld Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling EPA Inspector 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling SLB Cement 12.50 2 Drilling NC Machinery Mechanic 1250 2 Drilling Competents Logistic 12.50 4 SID Support GBR Casing 12 50 4 Drilling Baker Centrilift ESP Techs 12.50 5 Drilling MI Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12.50 8 SID Support Expro Flow back 12.50 8 Drilling ESS Catering 12.50 11 SID Support Worley Truck driver / Crane operator 12.50 16 Drilling Doyon Rig Personnel 12.50 26 Drilling -Total Drilling Personnel BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 10/24/2019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular Hydnl GK 500 13 5/B 5,000.0 5/1/2015 3 112 "- 6" VBR Hydric MPL 5000 13 518 5,000.0 8!24/2018 Blind Shear Ram Hydril MPL 5000 13 5/8 5,000.0 812412018 4 1/2" x 7" VBR Hydrit MPL 5000 13 5/8 5,000.0 5/1/2015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 10/24/2019 6 0.113 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Pump Number- 2 Make: While Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bblistk) Max Pressure (psi) 10/24/2019 6 0.113 I 5.323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 10/24/2019 6 0.102 4,665.0 Date Depth (ftKB) 41 Slow Spd Strokes (spm) P (psi)Eff l%) Q Flow (gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 1012812019 1,847.0 1,847.0 2,681.0 2,6810 0.0 0.0 Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date lConsumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/28/2019 198.0 198.0 371.0 371.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date lConsurned Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/28/2019 1,307.0 0.0 I 2,868.0 13,853.0 0.0 10,985.0 Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/28/2019 43.0 0.0 222.0 I 381.0 I 0.0 I 159.0 Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cu.Cum On Cu- Returnedoc Note 10/28/2019 42.0 42.0 79.0 79.0 0.0 0.0 Supply Item Description: WIF Injected Diesel Unit Label: Gat Unit Size: Note: Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 10/28/2019 Report #: 2 Page: 3 of 3 Date Consumed Received 10/28/2019 0.0 0.0 Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 0.0 0.0 0.0 0.0 Last Authority Visit Date I Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. MI Swaco Ml S—c. 3 20 3 3 3 3 PJSM'S Safe Cards COW HRWS RIR's HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 10/29/2019 Report #: 3 Page: 1 of 3 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) Rl, • Base Flange (ft) RKB-Tubing Spool (ft) 53 60 13 10 16.34 37.26 31.76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 10/27/2019 Daily Information Weather Temperature (°F) Wind Days LTI (days) Days RI (days) POB Mostly Cloudy 33.2 SW @ 5 MPH 732.00 732.00 121 0 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Los[ time? Comment Safety Drills Type # Occur Last Date Next Date Days Until Next Check (days) Rig Inspection Safety Meeting Spill Drill TT Man Down Drill 3 10/29/2019 3 1029/2019 1 10/29/2019 1 10/272019 10130/2019 10/30/2019 11/12/2019 1/25/2020 1 1 14 88 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftK6) Bottom (fit TVD Bot. (ftK6) Landing Date CASING CASING LINER 133/8 9 518 5 12 12.42 8.84 4.95 -80 L-80 L-80 IL 0.0 0.0 12,812.1 2.916.0 12,962.0 13,553.0 2487.1 4,096.6 4,109 7 7(28!2019 9!12!2019 10/6/2019 Last Cementing Cementing Start Date: 9/12/2019 String: CASING, 12,962.OftKB Comment: Schlumberger pressure tested to 3500 psi. Rig pump 101 bbls. of 10.0 ppg spacer at 5 bpm rate @ 520 psi, shut down and drop bottom plug. Schlumberger mix and pump 243 bbls. of Lead 12.50 ppg cement at 5 bpm @ 440 psi. Shut down and batch up Tail cement @ 15.8 ppg pumped 56 bbls. with 5 bpm FCP @ 315 psi. Drop top plug and Schlumberger pumped 20 bbls. of water 5 bpm @ 336 psi. Rig displaced with 961 bbls. of 9.4 ppg -SND mud - staging rates down from 8 bpm to 6 bpm @ 700 bbls. to 5 bpm @ 800 bbls. to 4 bpm @ 900 bbls. FCP = 600 psi_ No indication of first plug bumping and did not bump top plug at maximum strokes allowed. Shut down pump - pressure stabilized @ 290 psi. Cement in place @ 1600 hrs. Stg # Top (ftK6) Top Meas Meth Bt. (ftK6) Com Job Information Job PhasePlanned Start Date Start Date End Date P50 Duration (days) COMPLETION 10/27/2019 03.00 10/27/2019 03:00 0.00 Daily Summary Operations 24h Forecast Continue to run completion 24h Summary Continue to run in hole with 4 Y." coated 12.6#, HYD 563 Testing cable every 1,000'and cap tube pressure. Change out spool and spice Continue running in hole T/10,000' Trouble shoot cap tube pressure loss, pulling out of hole to last good pressure test. Operation at 07.00 Pulling out of hole inspecting cap tube. Time Log Start End Cum our Time Time Dur (hr) (hr) Phase Opr. Act. Plan Oper. Descr. 00:00 0230 2.50 2.50 COMP K 4 P Continue to run in hole with coated 4 %" 12.6# HYD 563 tubing F(4,790'T16026' Testing cable every 1000'. SO=78 k 02:30 0330 1.00 3.50 COMP K 9 P At 6,026' Test ESP cable and cap tube while circulating tubing volume 89 gpm, 670 psi 03:30 0630 3.00 6.50 COMP K 4 P Continue to run in hole with coated 4 %" 12.6# HYD 563 tubing F16,026 'T/7,270" Testing cable every 1000'. SO=78k 06:30 0830 2.00 8.50 COMP K 20 P Replace empty ESP spool in spooling unit 08:30 11-30 3.00 11.50 COMP K 20 P Splice ESP cable witnessed by ENI electrician Pump tubing volume while making splice 1130 18:00 650 18.00 COMP K 4 P Continue to run in hole with coated 4 %" 12.6# HYD 563 tubing Fl7,270' T/9 750" Testing cable every 1000', checking cap tube pressure. SO=78k 18:00 19:30 1.50 1950.COMP K 4 P Run in hole F/9,750' T/10,000' SO=75k Work on BHI clamp crimp tool. 19:30 21.00 1 50 21.00 COMP K 12 U Test ESP cable, check Cap tube, pressure dropped 1000 psi to 140 psi Trouble shoot cap tube: pump through and Flush, check surface around spool, pump up T/1,570 psi and see check valve open Prepare to pull out of hole to last good 21:00 210 0.50 21 50 COMP K 4 U Pull out of hole F/10,000' T/9,920' 3 2130 22:30 1.00 22.50 COMP K 12 U Fluid was observed on cap tube on spool Cup cap line and test spool, good pressure test holding 1000 psi Test cap tub down hole, pump up to 1000 psi and bleed offto 125 psi, test fail 22:30 00-00 1.50 24.00 COMP K 4 U Pull out of hole F/9,920' Tt9,255' testing cap tube and inspecting for damage. PU=125 psi. Losses to hole last 24 hours=0 BBL, Total BELS lost including original hole=1,900 BBLS Max gas last 24 HRS 1 units, average gas 1 units Gas Readings Avg Background Gas I%) 1.00 Max Background Gas I%) 1.00 Avg Connection Gas I%) 0.00 Max Connection Gas (%) 0.00 AvgDrill Gas (%) 0.00 Max Drill Gas I%) 0.00 Avg Trip Gas I%) 0.00 Max Trip Gas l 0.00 Mud Type: H2O - KCl/NaCl - 0 Depth (ftK6) 22,110.0 Density (lb/gal} 9.20 Funnel Viscosity (siqt) 27 PV Calc (cP) 0.0 IP Calc (Ibf/t00ft') 0.000 pH Chlorides (mg/L) 7.8 0.000 Electric Stab (V) 0.0 Solids (%) 0.0 Sand M 0.0 NTU in 0 NTU Out 0 Temp Crystal (°F) 0.0 Oil & Grease Static Sheen 0 0 Filtration Size (pm) 0 Mud Type: H2O - KCl/NaCl - 0 Depth (ftK6) 22,110.0 nsity (Ib/gal) 0 Funnel Viscosity (slgt) 27 PV Calc (CP) 0,0 YP Calc (Ibf/100ft') 0.000 pH 7.8 Chlorides (mg/L) 0.000 Electric Stab (V) 0.0 Solids I%) 0.0 F92 nd I%) NTU in 0 NTU Out 0 Temp Crystal (°F) 0.0 Oil 8 Grease 0 Static Sheen 0 Filtration Size (pm) 0 Mud Type: H2O - KCl/NaCl - 0 Depth (RKB) 22,110.0 Density pb/gal) 9.20 Funnel Viscosity (slgt) 21 PV Calc (cP) 0.0 YP Calc (Ibf/100W) 0.000 pH 7.8 Chlorides (mg/L) 0.000 Electric Stab (V) 0.0 Solids I%) 0.0 Sand (%) 0.0 NTU in 0 NTU Out 0 Temp Crystal (°F) 0.0 I Oil 8, Grease 0 I Static Sheen 0 Filtration Size (pm) 0 Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 1 0/2 91201 9 Report #: 3 Page: 2 of 3 Mud Type: H2O - KCl/NaCl - 0 Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Calc (cP) YP Calc pbf/100W), pH Chlorides (mg/L) Electric Stab (V) 22,110.0 920 27 0.0 0.000 7.8 0.000 0.0 Solids I%) Sand (%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) D.0 0.0 0 0 0.0 0 0 0 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,149.0 Loss 0.0 Tank 176.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 1,325.0 1,149.0 0.0 0.0 0.0 1 0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson Eni Drilling Supv, siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Em representative Carlos Monteiro Eni Engineer Eni representative Lucas Atencio Eni Engineer Eni representative Mitch Billington Eni Rig Clerk AKRigClerksDoyonl5@eni. com 907-685-0722 Eni representative Cory Haughton Eni HSE Eni representative Mark Hubler Eni HSE Tool Push Justin Hays Doyon DrlNng Tool Pusher rig 15@doyondril[ing.com Tool Push Ted Kruger Doyon Drilling Tour Pusher rig 15@doyondrilling.com 907-685-0716 Tao[ Push Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 685-0796 Tool Push Scott Simmons Doyon Drilling HSE Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note Doyon Field Superintendent 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Northern Oilfeild Services Fueler 12.50 1 SID Support Vetco (BHGE) WellHead 12.50 1 Drilling EPA Inspector 12.50 1 Drilling Eni Engineer 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling SLB Cement 12.50 2 Drilling NC Machinery Mechanic 12.50 2 Drilling Competentia Logistic 12.50 4 SID Support GBR Casing 12.50 4 Drilling Baker Centrilift ESP Techs 12.50 5 Drilling MI Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12.50 8 SID Support Exp. Flow back 12 50 8 Drilling ESS Catering 12.50 11 SID Support Worley Truck driver Crane operator 1250 16 Drilling Doyon Rig Personnel 12.50 27 Drilling_Total Drilling Personnel BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 10/24/2019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular Hydril GK 500 13 518 5,000.0 5/1/2015 3 112 "-6" VBR Hydril MPL 5000 13 5/8 5,000.0 8/24/2018 Blind Shear Ram Hydril MPL 5000 13 5/8 5,000.0 8/242018 41/2'x7" VER Hydril MPL 5000 13 5/8 5,000.0 5/1/2015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 10/24/2019 6 0.113 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Pump Number: 2 Make; White Star Model: Quatro 2450 Start Date End Dale Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 10/24/2019 6 0.113 5,323.0 Date Depth (ftKB) Slow SpdStrokes (spm) P (psi) Eff (%) Q Flow (gpm) Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 10/24/2019 6 0.102 4,665.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) EN (%) Q Flow (gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date lConsurned Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 1029/2019 902.0 902.0 3,583.0 3,583.0 0.0 0.0 Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/29/2019 198.0 198.0 569.0 569.0 0.0 0.0 Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 10129/2019 Report #: 3 Page: 3 of 3 Daily Bulk Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed I Received 10/29/2019 1.142.0 0.0 Returned Cu. Consumed 4,010.0 Cum Received 13,853.0 Cum Returned 0.0 Cum On Loc 9,843.0 Note Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received 10/29/2019 26.0 0.0 Returned Cum Consumed 248.0 Cum Received 381.0 Cum Returned 0.0 Cum On Loc 133.0 Note Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received 10/29/2019 42.0 42.0 Returned Cum Consumed 121.0 Cum Received 121.0 Cum Returned 0.0 Cum On Loc 0.0 Note Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received 10/29/2019 0.0 0.0 Returned Cum Consumed 0.0 Cum Received 0.0 Cum Returned 0.0 Cum On Loc 0.0 Note Last Authority Visit Date Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. MI Swaco Ml Swaco 6 11 6 6 8 8 PJSM'S Safe Cards COW HRWS RIR's HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 10/30/2019 Report #: 4 Page: 1 of 3 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Cc Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RIB - Base Flange (ft) RKB - Tubing Spool (ft) 53.60 13 10 16.34 37.26 31 76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 10/27/2019 Daily Information Weather Temperature (°F) Wind Days LTI (days) Days RI (days) POB Overcast 29.4 SW @ 44 MPH / Gust @ 48 MPH 733.00 733.00 117.0 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Rig Inspection 4 10/30/2019 10/31/2019 1 Safety Meeting 4 10/302019 10/3112019 1 Spill Drill 1 1029/2019 11/12/2019 13 TT H2S Drill 1 10/302019 11/13/2019 14 TT Man Down Drill 1 10/2712019 125/2020 87 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftKB) I Bottom (ftKB) TVD Bot. (ftKB) Landing Date CASING 13 378 12.42 L-80 0.0 2,916.0 2,487.1 7/282019 CASING 9 5/8 8.84 L-80 0.0 72,962.0 4,096.6 9!122019 LINER 5 1/2 4.95 L-80 12,812.1 13,553.0 4,109.7 10/6/2019 Last Cementing Cementing Start Date: 9/12/2019 String: CASING, 12,962.OftKB Comment: Schlumberger pressure tested to 3500 psi. Rig pump 101 bbls. of 10.0 ppg spacer at 5 bpm rate @ 520 psi, shut down and drop bottom plug. Schlumberger mix and pump 243 bbls. of Lead 12.50 ppg cement at 5 bpm @ 440 psi. Shut down and batch up Tail cement@ 15.8 ppg pumped 56 bbls. with 5 bpm FCP @ 315 psi. Drop top plug and Schlumberger pumped 20 bbls. of water 5 bpm @ 336 psi. Rig displaced with 961 bbls. of 9.4 ppg -SND mud - staging rates down from 8 bpm to 6 bpm @ 700 bbls. to 5 bpm @ 800 bbls. to 4 bpm @ 900 bbls. FCP = 600 psi. No indication of first plug bumping and did not bump top plug at maximum strokes allowed. Shut down pump - pressure stabilized @ 290 psi. Cement in place @ 1600 hrs. Sig # Top (RKB) Top Meas Meth Btm (ftKB) Com Job Information Job Phase Planned Start Date Start Date End Date P50 Duration (days) COMPLETION 10/272019 03.00 10/272019 03:00 0.00 I Daily Summary Operations 24h Forecast Terminate ESP cable and 3/8' chemical injection line through tubing hanger. Land tubing hanger, run in lock down screws Install TWC, nipple down BOP stack and nipple up tree. Passport test wellhead 24h Summary Continue laying down 4.5° 12.6# tubing with 318" chemical injection line and ESP cable from 9,255 MD to 7,776' MD. After performing various tests on chemical injection line, based upon test results @ 7,776' the decision was made to Continue running in hole with 4.5" 12.6# completion from 7,776' MD to 12,566' MD (Tally Joint # 302) Testing ESP continuity every 1000' Operation at 07.00 Suspended operations due to Phase 3 Weather Conditions Time Log Start End Cum our Time Time our (hr) (hr) Phase Opr. Act, Plan Oper. Descr. 00:00 0430 4 50 4.50 COMP K 4 U Continue to lay down 4.5" 12.6# tubing with chemical injection line and ESP cable from 9,255' MD to 8,000' MD Test chemical injection line to 1000 psi, bleed off rate was 5 psi / 10 Min As opposed to a bleed off rate of 10 psi 110 Min @ 0430 1030 6.00 10.50 COMP K 4 U Continue to lay down 4,5" 12.6# tubing with chemical injection line and ESP cable from 8,000' MD to 7,776'M D. Test chemical injection line to 100 psi, bled down to 92 psi Test chemical injection fine to 500 psi, bleed down to 30 psi then continue to bleed down at 1 psi/minute Pressured up to 2500 psi and pumped down chemical injection line and check valve for 3 minutes After turning off pump chemical injection line bled down to 92 psi Based upon test results, the decision was made to begin Running in hole with 4.5" 12.6# ESP Completion 10:30 1200 1.50 12.00 COMP K 4 U Run in hole with TP 12.0 ESP completion from 7,776' MD to 8,097' MD 1200 18.00 600 18.00 COMP K 14 IP Run in hole with 4 5' 12.6# ESP completion from 8,097' MD to 10,492' MD Test ESP cable continuity every 1000' 1800 21:00 3.00 21 00 COMP K 4 P Run in hole with 4.5" 12.6# ESP completion from 10,492' MD to 11,030' MD Circulate tubing volume 167 bbls 700 psi @ 89 gpm Return Flow = 16% Rig down TIW, blow down top drive 2t00 0000 3.00 24.00 COMP K 14 1 P I Run in hole with 4 5" 12.6# ESP completion from 11,030' MD to 12,566' MD Test ESP cable continuity every 1000'. Gas Readings Avg Background Gas Max Background Gas (%) Avg Connection Gas (%) Max Connection Gas (%) 00 1.00 Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas I%) Mud Type: H2O - KCl/NaCl - 0 Depth (RKB) Density (ib/gal) Funnel Viscosity (s/qt) PV Calc (cP) YP Calc (lbf1100ft') pH Chlorides (mg/L) Electric Stab (V) 22,1 "") 9.20 27 0.0 0.000 8.0 0.000 0.0 Solids (%) Sand (%) NTU in NTU Out Temp Crystal (°F)Oil Grease Static Sheen Filtration Size (pm) 0.0 0.0 0 0 0.0 0 0 0 Mud Type: H2O - KCl/NaCl - 0 Depth (ftKB) Density (Ib/gap Funnel Viscosity (s/qt) PV Calc (CP) YP Calc (Ibf1100ft') pH Chlorides (mg/L) Electric Stab (V) 22,110.0 920 27 00 0.000 so 0.000 0.0 Solids (%) Sand (%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) 0.0 0.0 0 0 0.0 0 0 0 Mud Type: H2O - KCl/NaCl - 0 Depth (ftKB) Density (ibigal) Funnel Viscosity (s/qt) PV Calc (cP) YP Calc (Ibf/100W) pH Chlorides (mg/L) Electric Stab (V) 22,110.0 9.20 27 0.0 0.000 8.0 0.OoO 0.0 Solitls (%) Sand (%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) 0.0 0.0 0 0 0.0 0 0 0 Mud Type: H2O - KCl/NaCl - 0 Depth ftKB) Density (ib/gap Funnel Viscosity (s/qt) PV Calc (cP) YP Calc (Ibf/100ft2) pH Chlorides (mg/L) Electric Stab (V) 22,110.0 920 27 0.0 0.000 8.0 0.000 0.0 Solids I%) Sand (%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) 0.0 0.0 0 0 0.0 0 0 0 Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 10/30/2019 Report #: 4 Page: 2 of 3 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,134.0 Loss 0.0 Tank 1930. Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 1,327.0 1,134.0 0.0 0.0 0.0 1 0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb Eni Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Eli Wilson Eni Company Man 685-0715 Em representative Carlos Monteiro Eni Engineer Em representative Lucas Atencio Eni Engineer Eni representative Wade Thomas Eni Rig Clerk AKRigClerksDoyonl5@eni.com 907-685-0722 Eni representative Pat Ahem Eni HSE Eni representative Mark Hubler Eni HSE Tool Push Justin Hays Doyon Drilling Tool Pusher rigl5@doyonddlling.com Tool Push Ted Kruger Doyon Drilling Tour Pusher rigl5@doyonddlling.com 907-685-0716 Tool Push Cliff Owens Doyon Drilling HSE cowens@doyonddlling.com 685-0796 Tool Push Scott Simmons Doyon Drilling HSE Personnel Log (POB) Company Sent. Type Work H (hr) Stand-by H (hr) Count Note Doyon Field Superintendent 12.50 0 Drilling EPA Inspector 12.50 0 Drilling NC Machinery Mechanic 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Northern Oilfelld Services Fueler 12.50 1.. SID Support Vetco (BHGE) WellHead 12.50 1 Ddlling Ent Engineer 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling Halliburton Mud Loggers 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling SLB Cement 12.50 2 Drilling Competentia Logistic 12.50 4 SID Support Baker Centrilift ESP Techs 12.50 5 Drilling GBR Casing 12.50 5 Drilling MI Swaco Mud Plant 12.50 6 Drilling Purcell Security 12.50 6 SID Support MI Swaco WIF 12.50 8 SID Support Expro Flow back 12.50 8 Drilling ESS Catering 12.50 11 SID Support Worley Truck driver! Crane operator 12.50 14 Drilling Doyon Rig Personnel 12.50 27 Drilling -Total Drilling Personnel BOP Stack 8 Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 10124/2019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) Last Cert Date Annular Hydril GK 500 13 518 5,000.0 5/112015 3 1/2 "- 6" VBR Hydril MPL 5000 135/8 5,000.0 8/24/2018 Blind Shear Ram Hydril MPL 5000 135/8 5,000.0 8/24/2018 4 112" x 7" VBR Hydril MPL 5000 13 5/8 5,000.0 5/1/2015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Dale Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 10/241201977 6 0.113 5,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff I%) Q Flow (gpm) Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 10/24/2019 6 0.113 5,323.0 Date Depth (ftKB) Slow Spoil Strokes (spm) P (psi) Eff l Q Flow (gpm) Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 10/24/2019 6 0.102 4,665.0 Date Depth (ftKB) Slow Spot Strokes (spm) P (psi) Eff (%) Q Flow (gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/30/2019 930.0 930.0 4,513.0 4,513.0 0.0 0.0 Supply Item Description: Mud Plant Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received lReturned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/30/2019 198.0 198.0 767.0 767.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10130!2019 1.308.0 2,270.0 5,318.0 16,123.0 0.0 10,805.0 Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 10/30/2019 Report #: 4 Page: 3 of 3 Date I Consumed I Received 10/30/2019 43.0 0.0 Returned Cum Consumed 2910 Cum Received 387.0 Cum Returned 0.0 Cum On Loc 90.0 Note Supply Item Description: WIF Boilers Unit Label: Gat Unit Size: Note: Date Consumed Received 10/30!2019 42.0 42.0 Returned Cum Consumed 163.0 Cum Received 163.0 Cum Returned 0.0 Cum On Loc 0.0 Note Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received 10/3012019 0.0 0.0 Returned Cum Consumed 0.0 Cum Received 0.0 Cum Returned 0.0 Cum On Loc 0.0 Note Last Authority Visit Date I Tot insp. Nbr Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Com Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. MI Swaco Ml Swaco 21 21 21 21 8 8 PJSM'S HRWS COW Safe Cards RIR's HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 10/31/2019 Report #: 5 Page: 1 of 3 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ADL -392938 ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB • Base Flange (ft) RKB • Tubing Spool (ft) 53.60 13.10 16.34 31.26 31.76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 DOYON LAND RIG 0723 10/27/2019 Daily Information Weather Temperature (°F) Wind Days LTI (days) Days RI (days) POB Overcast 27.3 SW @ 25 MPH 734.00 734.00 87.0 Safety Incidents - Near Miss Date Category Type I Subtype Severity Cause los[ time? Comment Safety Drills Days Until Next Check Type # Occur Last Date Next Date (days) Fire Drill 1 10/31/2019 11/14/2019 14 Rig Inspection 5 10/3112019 11/1/2019 1 Safety Meeting 5 10/31/2019 111112019 1 Spill Drill 1 10/29/2019 11/12/2019 12 TT H28 Drill 1 10/30/2019 11/13/2019 13 TT Man Down Drill 1 10127/2019 1125/2020 86 Casings seat Cas. Type OD (in) ID (in) Grade Top (RKB) I Bottom (RKB) I TVD Bot. (ftK6) Landing Date CASING 13 3/8 12.42 L-80 0.0 2,916.0 2,487.1 7/28/2019 CASING 9 5/8 8 84 L-80 0.0 12,962,0 4,096.6 9/12/2019 LINER 5112 4.95 L-80 12,812.1 13.553.0 4,1097 10/6/2019 Last Cementing Cementing Start Date: 9/12/2019 String: CASING, 12,962.OftKB Comment: Schlumberger pressure tested to 3500 psi. Rig pump 101 bbls. of 10.0 ppg spacer at 5 bpm rate @ 520 psi, shut down and drop bottom plug. Schlumberger mix and pump 243 bbls. of Lead 12.50 ppg cement at 5 bpm @ 440 psi. Shut down and batch up Tail cement @ 15.8 ppg pumped 56 bbls. with 5 bpm FCP @ 315 psi. Drop top plug and Schlumberger pumped 20 bbls. of water 5 bpm @ 336 psi. Rig displaced with 961 bbls. of 9.4 ppg LSND mud - staging rates down from 8 bpm to 6 bpm @ 700 bbls. to 5 bpm @ 800 bbls. to 4 bpm @ 900 bbls. FCP = 600 psi. No indication of first plug bumping and did not bump top plug at maximum strokes allowed. Shut down pump - pressure stabilized @ 290 psi. Cement in place @ 1600 hrs. Sig # Top (ftK6) Top Meas Meth Bt. (ftK6) Com Job Information Job Phase Planned Start Date Start Date End Date P50 Duration (days) COMPLETION 10127/2019 03:00 10/27/2019 03.00 0.00 Daily Summary Operations 24h Forecast Verse to nipple up tubing adapter and wellhead tree. Vetco to Pass Port test wellhead then pull Two Way Check Baker centrilift to conduct final checks on ESP cable/motor electrical continuity. Doyon prepping rig for upcoming rig move. 24h Summary Make up swivel joint assembly, hanger, and landing joint Baker displaced glycol out of chemical Injection line with 40 gallons of CL5E oil Terminate ESP cable & 318" chemical injection line through tubing hanger Land tubing hanger and pressure test seals to 5000 psi for 10 minutes, witnessed by ENI company man Operations suspended for logistical & weather conditions 30-50 mph winds. Winds subsided continue completion operations. Rig down ESP spooling unit and sheaves, demobilize equipment from rig floor. Vetco installed Two Way Check in tubing hanger. Begin to nipple down BOP stack. Operation at 07.00 Prep for Tree Testing. Time Log Start End Cum our Time Time Dur (hr) (hr) Phase OF, Act. Plan Oper. Descr. 00:00 01 00 1.00 1.00 COMP K 4 P Make up swivel joint assembly, tubing hanger, and landing joint. 01'00 06-30 550 6.50 COMP K 4 P Terminate ESP cable through tubing hanger while Baker displaces glycol out chemical injection line with 40 gallons of CL5E oil Terminate chemical injection line through tubing hanger 0630 09:00 2.50 9.00 COMP K 22 XW01 All life critical operations suspended due to weather phase conditions 30-50 mph winds Inspect Doyon 15 draw works 09:00 11.00 200 11.00 COMP K 4 P Drain stack Blow down choke and kill line to stack Rinse stack and land tubing hanger, tighten lock down screws Pressure test hanger seals to 5000 psi for 10 minutes, witnessed by ENI company man 11:00 1900 8.00 19.00 COMP K 22 XW01 All life critical operations suspended due to weather phase conditions 30-50 mph winds Flush surface equipmentlines, and pits with citric pill. Monitor weather. 19:00 00:00 5001 24,00 1COMP 1K 14 P I Rig down GBR/Baker ESP equipment and sheaves Install Two Way Check in tubing hanger. Begin to nipple down BOP Gas Readings Avg Background Gas I%) Max Background Gas I%) Avg Connection Gas I%) Max Connection Gas I%) Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas I%) Mud Type: H2O - KC11NaC1 - 0 Depth (ftK6) Density (Ib/gal) Funnel Viscosity (s/qt) PV Calc (cP) YP Calc (Ibf/100W pH Chlorides mg/L) Electric Stab (V) 22,110.0 9.20 0 0.0 0.000 0.0 0.000 0.0 Solids (%) Sand (%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) 0.0 0.0 0 0 0.0 0 0 0 Mud Type: H2O - KCl/NaCl - 0 Depth (ftK6) Density (Ib/gal) Funnel Viscosity (slqt) PV Calc (cP) YP Calc (Ibf/100W' pH Chlorides (mg/L) Electric Stab (V) 22,110.0 9.20 0 0.0 0.000 0.0 0.000 0.0 Solids I%) Sand I%) NTU in NTU Out Temp Crystal (°F) Oil 8, Grease Static Sheen Filtration Size (pm) 0.0 0.0 0 0 0.0 0 0 0 Mud Type: H2O - KC11NaC1 - 0 Depth (ftK6) Density (lb/gal) Funnel Viscosity (s/qt) PV Calc (cP) YP Calc (Ibf/100ft') pH Chlorides (mg/L) Electric Stab (V) 22,110.0 9.20 0 0.0 0.000 0.0 0.000 0.0 Solids (%) Sand (%) NTU m NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) o.0 0.0 0 0 0.0 0 0 0 Mud Type: H2O - KC11NaC1 - 0 Depth (ftK6) Density (Ib/gal) Funnel Viscosity (s/qt) PV Calc (cP)YP Calc (Ibf/100ft') pH Chlorides (mg/L) Electric Stab (V) 22,110.0 9.20 0 0.0 0.000 0.0 0.000 0.0 Solids I%)NTU in NTU Out Temp Crystal (°F) Oil &Grease Static Sheen Filtration Size (pm) 0.0 0.0 0 0 0.0 0 0 0 Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 10/31/2019 Report #: 5 Page: 2 of 3 Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hole 1,134.0 Loss 0.0 Tank 0.0 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum Additions (bbl) Losses (bbl) Cum Losses (bbl) 1,134.0 1,134.0 0.0 0.0 0.0 1 0 Daily Contacts Position Contact Name Company Title Email Office Mobile Ent representative Bruce Simonson Ent Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb Ern Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Eli Wilson Eni Company Man 685-0715 Eni representative Carlos Monteiro Eni Engineer Eni representative Lucas Atencio Eni Engineer Eni representative Wade Thomas Eni Rig Clerk AKRigGlerksDoyonl5@eni.com 907-685-0722 Eni representative Pat Ahern Eni HSE Eni representative Mark Hubler Eni HSE Tool Push Jushn Hays Doyon Drilling Tool Pusher rig 15@doyondrilling.com Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Cliff Owens Doyon Drilling HSE cowens@doyondrilling.com 685-0796 Tool Push Scott Simmons Doyon Drilling HSE Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H (hr) Count Note Baker Centrilift ESP Techs 12.50 0 Drilling GBR Casing 12.50 0 Drilling SLB Cement 12.50 0 Drilling Expro Flow back 12.50 0 Drilling EPA Inspector 12.50 0 Drilling NC Machinery Mechanic 12.50 0 Drilling ASRC Clerk 12.50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Halliburton Mud Loggers 12.50 1 Drilling Northern Oilfend Services Fueler 12.50 1 SID Support Vetco (BHGE) WeIlHead 12.50 1 Drilling Eni Engineer 12,50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12.50 2 Drilling MI Swaco Mud Engineer 12.50 2 Drilling Competentia Logistic 12.50 4 SID Support Purcell Security 12.50 4 SID Support MI Swaco Mud Plant 12.50 6 Drilling MI Swaco WIF 12.50 8 SID Support ESS Catering 12.50 11 SID Support Worley Truck driver / Crane operator 12.50 14 Drilling Doyon Rig Personnel 12.50 19 Drilling Total Drilling Personnel BOP Stack & Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 10/24/2019 5/1/2015 5,000.0 Type Make Model ID Nom (in) P Range (psi) I Last Cert Date Annular GK 500 13 518 5,000.0 5/1/2015 3 1/2'- 6" VBR ril MPL 5000 13 5/8 5,000.0 8/242018 :Iydril Blind Shear Ram ril MPL 5000 135/8 5,000.0 8/24/2018 4 1/2" x 7'VBR ril MPL 5000 135/8 5,000.0 5112015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Qualm 2450 Start Date End Date Liner Size (in) volume Per Stroke Override (bbilstk) Max Pressure (psi) 10/24/2019 6 0.113 15,323.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) O Flow (gpm) Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Maz Pressure (psi) 10/24/2019 6 0.113 15,323,0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff M Q Flow (gpm) Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) Max Pressure (psi) 10124/2019 6 0.102 4,6650 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff 1%) O Flow (gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/31/2019 925.0 925.0 5,438.0 5,438.0 0.0 0.0 Supply Item Description: Mud Plant Boilers Unit Label: Gat Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Not, 10/31/2019 198.0 198.0 965.0 965.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/31/2019 1 665.0 0.0 6,983.0 16,123.0 0.0 9,140.0 Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 10131/2019 Report #: 5 Page: 3 of 3 Dale Consumed Received 10/31/2019 41.0 0.0 Returned Cum Consumed 332.0 Cum Received 381.0 Cum Returned 0.0 Cum On Loc 49.0 Not, Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received 10/31/2019 42.0 42.0 Returned Cum Consumed 205.0 Cum Received 205.0 Cum Returned 0.0 Cum On Loc 0.0 Note Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Date Consumed Received 10/31/2019 0.0 0.0 Returned Cum Consumed 0.0 Cum Received 0.0 Cum Returned 0.0 Cum On Loc 0.0 Note Last Authority Visit Date I Tot msp. Nbr I Total I.N.C. number Comment STOP Cards Submitted Company # Rpts Co. Doyon Drilling Doyon Drilling Inc. Doyon Drilling Inc. Doyon Drilling Inc. MI Swaco Ml Swaco 7 7 7 9 8 8 PJSM'S HRWS COW Safe Cards RIR's HARC/JSA General Notes Comment: Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments thatcan be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 1111/2019 Report #: 6 Page: 1 of 3 Well Header PermitlConcession No Operator Subsidiary Initial Lahee Code ADL-392938ENI PETROLEUM ENI Petroleum Co Inc DEVELOPMENT WELL Rotary Table Elevation (ft) Ground Level (ft) First Flange (ft) RKB - Base Flange (ft) RKB • Tubing Spool (ft) 53.60 13.10 16.34 37.26 31 76 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date RIG 15 D00YON LAND RIG 0723 10/27/2019 Daily Information Weather Temperature (°F) Wind Days LTI (days) Days RI (days) POB Mostly Cloudy 28.4 S W @ 20 MPH 735.00 735.00 87.0 Safety Incidents - Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Type # Occur Last Date Next Date Days Until Next Check (days) Fire Drill Rig Inspection Safety Meeting Spill Drill TT 1-12S Drill TT Man Down Drill 1 10/31/2019 5 10/31/2019 5 10/31/2019 1 1029/2019 1 10/30/2019 1 10/27/2019 11/15/2019 11/2/2019 11/2/2019 11/13/2019 11/1412019 1/262020 14 1 1 12 13 86 Casings seat Cas. Type OD (in) ID (in) Grade Top (ftKB) I Bottom (ftKB) I TVD Bot. (ftKB) Landing Date CASING CASING LINER 13 3/8 9 5/8 5 1/2 12.42 8.84 4.95 L-80 L-80 L-80 0.0 0.0 12,812.1 2,916.0 12,9620 13,553.0 2,487 1 4,096.6 4,109 7 7/28(2019 9112/2019 10/6/2019 Last Cementing Cementing Start Date: 9/12/2019 String: CASING, 12,962.OftKB Comment: Schlumberger pressure tested to 3500 psi. Rig pump 101 bbls. of 10.0 ppg spacer at 5 bpm rate @ 520 psi, shut down and drop bottom plug. Schlumberger mix and pump 243 bbls. of Lead 12.50 ppg cement at 5 bpm @ 440 psi. Shut down and batch up Tail cement @ 15.8 ppg pumped 56 bbls. with 5 bpm FCP @ 315 psi. Drop top plug and Schlumberger pumped 20 bbls. of water 5 bpm @ 336 psi. Rig displaced with 961 blas. of 9.4 ppg -SND mud - staging rates down from 8 bpm to 6 bpm @ 700 bbls. to 5 bpm @ 800 blas. to 4 bpm @ 900 bbls. FCP = 600 psi. No indication of first plug bumping and did not bump top plug at maximum strokes allowed. Shut down pump - pressure stabilized @ 290 psi. Cement in place @ 1600 hrs. stg # Top (ftKB) Top Meas Meth Bt. (ftKB) Com Job Information Job Phase Planned Start Date Start Date End Date P50 Duration (days) COMPLETION 10/27!2019 03:00 10/27/2019 03:00 11/1/2019 13.00 0.00 Daily Summary Operations 24h Forecast N/D BOPE, N/U Tree and perform passport testing 24h Summary N/D BOPE, N/U Tree and Performed passport test (good test). Rig released to SD37-OSP1 @ 13:00 Him. Operation at 07.00 No Operations Time Log Start I End Cum our Time Time Dur (hr) (hr) Phase Opr. Act. Plan Oper. Descr. 0000 0,130 4.50 4.50 COMP C 5 P Nipple down BOPE, remove flow line, pitcher nipple, and accumulator lines Removed choke and kill lines along with manual and HCR valves, while prepping rock washer for rig move Remove BOP stack and set on stand remove high pressure riser and secure same Pull pump 3 away from rig 04.30 07-00 2.50 7.00 COMP C 5 P Nipple up tree and lest hanger void, along with upper and lower sea as to 5000 PSI for 10 minutes each (good lest) 07:00 1300 6.00 13.00 COMP C 5 P Perform passport testing (good test), Secure well Rig Released to SD37-DSP1 @ 13:00 Hrs Gas Readings Avg Background Gas I%) Max Background Gas I%) Avg Connection Gas I%) Max Connection Gas I%) Avg Drill Gas (%) Max Drill Gas I%) Avg Trip Gas (i) Max Trip Gas I%) Mud Type: H2O - KCl/NaCl - 0 Depth (ftKB) Density (Ib/gap Funnel Viscosity (slgt) PV Calc (eP) YP Calc gbf/100ft') pH I Chlorides (mg/L) Electric Stab (V) Solids I%) Sand (%I NTLI in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) Mud Type: H2O - KCl/NaCl - 0 Depth (ftKB) Density (Ib/gal) Funnel Viscosity (slgt) PV Calc (CP) YP Calc (Ibf/100ft2) pH Chlorides mg/L) Electric Stab (V) Solids I%) Sand M) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) Mud Type: H2O - KCl/NaCl - 0 Depth (ftKB) Density (lbigal) Funnel Viscosity (s/qt) PV Calc (CP) YP Calc (11of/100ft2) pH Chlorides (mg/L) Electric Stab (V) Solids I%) Sand I%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) Mud Type: H2O - KCl/NaCl - 0 Depth (ftKB) Density (Ib/gap Funnel Viscosity (s/qt) PV Calc (cla) YP Calc (Ibf/100ft2) pH Chlorides (mg/L) Electric Stab (V) Solids (i) Sand I%) NTU in NTU Out Temp Crystal (°F) Oil & Grease Static Sheen Filtration Size (pm) Daily Mud Volumes Tank/Addition/Loss Type Des Volume (bbl) Hote Loss Tank Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 11/112019 Report #: 6 Page: 2 of 3 Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Additions (bbl) Cum bbl Additions (bbl) Losses (bbl) Cum Losses () O0 . 0.0 40 0.0 0.0 1.0 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson Ent Drilling Supv. siddrilling@eni.com 907-685-0715 Em representative Mike Grubb Ent Drilling Supv siddrilling@eni com 907-685-0715 Em representative Eli Wilson Ent Company Man 685-0715 Eni. representative Carlos Monteiro Ent Engineer Ent representative Lucas Atencio Ent Engineer Ent representative Wade Thomas Ent Rig Clerk AKRigClerksDoyonl 5@eni.com 907-685-0722 Ent representative Pat Ahem Ent HSE Ent representative Mark Hubler Ent HSE Tool Push Justin Hays Doyon Drilling Tool Pusher rigl5@doyondrilling.com Tool Push Ted Kruger Doyon Drilling Tour Pusher rig 15@doyondrilling.com 907-685-0716 Tool Push Cliff Owens Doyon Drilling HSE cowens@doyondrilling.com 685-0796 Tool Push Scoff Simmons Doyon Drilling HSE Personnel Log (POB) Company Serv, Type Work H (hr) Stand-by H (hr) Count Note Baker Cemplift ESP Techs 12.50 0 Drilling GBR Casing 12.50 0 Drilling SLB Cement 12.50 0 Drilling Expro Flow back 12.50 0 Drilling EPA Inspector 12.50 0 Drilling NC Machinery Mechanic 12.50 0 Drilling ASRC Clerk 12,50 1 Drilling ASRC SOA 12.50 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support Doyon Field Superintendent 12.50 1 Drilling Halliburton Mud Loggers 12.50 1 Drilling Northern Orfeild Services Fueler 12.50 1 SID Support Vetm (BHGE) WellHead 12,50 1 Drilling Ent Engineer 12.50 1 Drilling ACS Enviromental 12.50 2 SID Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Drilling Doyon HSE 12-50 2 Drilling MI Swam Mud Engineer 12.50 2 Drilling Competentia Logistic 12.50 4 SID Support Purcell Security 12.50 4 SID Support MI Swam Mud Plant 12-50 6 Drilling MI Swam WIF 12.50 8 SID Support ESS Catering 12.50 11 SID Support Worley Truck driver f Crane operator 12.50 14 Drilling Doyon Rig Personnel 12.50 19 Drilling -Total Drilling Personnel BOP Stack 8 Components Description Start Date Last Certification Date Pressure Rating (psi) BOP Stack 10/2412019 5/1/2015 5.000.0 Type Make Model ID Nom (in) P Range (psi) I Last Cert Date Annular Hydril GK 500 13 5/8 5,000.0 5/112015 3 12 "- 6" VBR Hydril MPL 5000 13 5/8 5,000.0 8!24!2018 Blind Shear Ram Hydril MPL 5000 13 518 5,000.0 8/24/2018 4 1/2" x 7" VBR Hydril MPL 5000 13 518 5,000.0 5/1/2015 Slow Circulation Rates Pump Number: 1 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbl/stk) 7Max Pressure (psi) 101242019 1 6 0.113 15,3230 Date Depth (ftKB) Slow Sod Strokes (spm) P (psi) Eff (%I Q Flow (gpm) Pump Number: 2 Make: White Star Model: Quatro 2450 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) Max 10/24/2019 6 0.113 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff I%) Q Flow (gpm) Pump Number: 3 Make: National Supply Model: 12-P-160 Start Date End Date Liner Size (in) Volume Per Stroke Override (bbllstk) Max Pressure (psi) 10!2412019 6 0.102 4,665.0 Date Depth (ftKB) Slow Spd Strokes (spm) P (psi) Eff (%) O Flow (gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 1013112019 925.0 925.0 5,438.0 5,438.0 0.0 0.0 Supply Item Description: Mud Plant Bolters Unit Label: Gal Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/31/2019 1980. 198.0 965.0 965.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label: gal us Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/31/2019 1.665.0 0.0 6,983.0 16,123.0 D.D 9,140.0 Supply Item Description: Rig Water Unit Label: bbl Unit Size: 1 Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/31/2019 41.0 0.0 332.0 381.0 0.0 49.0 Supply Item Description: WIF Boilers Unit Label: Gal Unit Size: Note: Date Consumed Received ReturnedCum Consumed Cum Received Cum Returned Cum On Loc Note 10/31/2019 42.0 42.0 205.0 205.0 0.0 0.0 Supply Item Description: WIF Injected Diesel Unit Label: Gal Unit Size: Note: Selected table Well Name: SP03-NE2 has no valid Wellbore Name: Original Hole attachments that can be Well Code: 32079 displayed Job: COMPLETION WCEI Level: 3 Daily Report Date: 1111/2019 Report #: 6 Page: 3 of 3 Date Consumed Received Returned Cum Consumed Cum Received Gum Returned Cum On Loc Note 10/3772019 0.0 0.0 0.0 0.0 0.0 0.0 Last Authority Visit Date Tot insp. Nbr To[al I.N.C. number Comment General Notes Comment: Schlumberger PRIN (gni SP03-NE2L1 Survey Geodetic Report (Def Sutveyj Repon Date'. OOL,Der 22. 2019-03:220 PM Survey✓ DLS Computafbn• TVDSS C6esN: En:PouGleum VegtWarS"tionAzimuth :.,,:_.. '._'•n• Fkid: Nlxatonuq VedlutSectlari Orlgtn: G'•uC'+. _.___ .. 5trvolure l Slot! Spy 161AM0i SPD3 TWO Reference Do",: Euta •,-a- We".. Si43-fX2 ( >�•�•` ,dl TVD Referent! Etevatian 53.GD•=•fl a4cre MSL , Sorehola' SP03-NEZL1 ® � Ground Elevation: 13.+.0✓ R a:ave M3L APte: 3jE282W3960 Magnelic Deamuon: 16 506' Survey Name: SPG3-NEZL1 Total GravDy Field 51fengo TVC.O'5Eman i9.a0665 Eaeez' Survey Date: Ottow 14. 2019 Gravity Modem DDl Tort! AND 1 0017 ERD Ra11o: 347118' i 2(r153'274 11'7L 572 4.942 Total Magnetlo Field Strength: 674'9.992 n7 Coordlnate Referenoe Byelaw NAD227 Aa9Ka Stale Pane. Zxe G4, US Feet Magnetac DIP Angle: Benz ` Looation Lot! Long: N 70' 33' 28.221524'. W 149' S2' 13.S4572' Declination Date- ry 25, 7.019 L"Ation Will NE VIX'. N'&053687.9901913. E 511723.308 9US Magnets. De.9t1aw. Mt et 6731.? 2093 CRS Grid Comargenoe Anprr O.G907 - North RNeren4e: 7•,e %ai, Grid Soak Factor: 0.899900/6 Grid Corrrergence Used: 0.0000' vere1611 / PdlCh' 2.10-732.0 Total Con Mag North-sTrue NCnh- E.5CWE ` '-45 106 Local Coord Referenced To: ''.'+e_ E *B_' Coff"oerQe MO WillAtJm Me TVDSS TVD V3EC AMD Cbeure NS EW OLS Northrop EaetMW Latitude Longitude IRi 1`1 C! iRl M! M7 MV IRI 'Rl IRs ""ti}IDtf tRU31 {11USi {"I {•{ F -i. O.DO Goo 0.04 -5364 0.00 9 -GQ G-114 Q.6Q _ __ _. DG 6353267.95 _ 7_ _ -_ _ _ _142'~=•3E26�_3 40.50 0.00 O.00 •13.10 40.58 0.00 0.31 V 0 E353657.95 _ ____ _ __ ____'.-67 -uc g._•3d.CEC3 1.02 351.8a 37.91 91.51 112 015 0.45 '-45 106 -- "' "'__� _ _ �. _ -_ - -- _-- *K7365E 962.9' 0.78 338.67 109.64 163-10 1-50 1.58 1.57 '. 1.35 '__ -_ --- _- - - - _--_ -_ - _ - 194.91, 0.76 35G.Da 14129 194.89 1.92 201 2.00 2.94 147 219.15 0.58 346.:3 165.53 219.13 22.,S 228 2-28 1.53 ---.-- 72.5573`3E'_ ''-8550a3 250.41 4.7D U9.37 195-39 249-98 252 263 2.63 2.5E -0.60 ---_-7_._ - ___.7_ 7,_ 5577=55 .__ _-_355023 278.25 L74 356-89 225.63 27923 2.94 3.10 3.05 802 1.55 '..56 c=b'.0 C.9- 5 '!-"2.E5 '_.5575458,'. -1-' 35'W 326.71 1.210 353.25 273.47 325.67 - 0.07 LOS 3.9. 1.73 &_636-' c- 5..-2256 7_•.5578-8:5- -121..3-3352•=6 370.75 GZ4 35227 31711 37071 4.55 4.86 Lal _.... 1.33 _,.-2 EE1__E :-' 5.772246 73567553 -14993335285 m azG� 7.22 352..20 341.98 395.58 -__ 5.30 5.28 _ 1-39 E=f,-E7_ _51 :: __• _ 557851K, -149'__3853M 429.59 1.49 358.79 375-94 428.54 5 c3 E 1 6.C•E ax_.95 - 63536: 3.9E _ " '_ -- 5585393 -148.933a533.3 488.44 2.62 1.80 435.75 439.35 7.52 325 821 3.''S 1.92' 2C &=3.'376'_ _ ___ __ 7_ 5.754-14fr.9•_385359 535. a'. 3.26 2.90 462.06 535.56 8.53 tG.53 1Q.56 .0.53 1.32 zz- E•_5.':6-:3='. __. __ '_55733333 -1199•_3B5275 533.16 1.04 8.70 528.31 5ffi.91 "1.97 73.6: 13.54 3.5:• 1.52 7_ 6C635a'1- _ __.-: 7.5.53.'452-14c.g3355927 532.91 518 618 578.69 532-9 '525 17.77 1762 - __ ELM 29'. 3_63EdS57 _ __ _' '•__5878857'.. -149.&_352645 676-45 E.30 3.94 622.14 67574 '9.55 23.00 0.45 6.5' EC53E9C. _ -__ - 7,-•.5573994' -119.9_334238 77' 7911.99 358.87 716.03 769.6E 2327 39.03 38.87 Q.7E 3.115 6•_23:7; Ce a a___ _ 735-57643-2 11 9.yr.P_3393P. 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'48.934071E6 1575.50 27.25 356.11 '457.25 ^g/4.85 ". _t 33Z.EG 33806 336.5 _30.:3 -.7- E-40", 51 511891.31 70-55375723 -1-S 9--0 1669.97 27.59 355.87 163924 1592.84 32525 33715 Bee 66 -'r:_8 339, '. 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TVDSS TVD VSEC AHO Closure NS EW DLS Northing Easting Latitude Longitude 1 12767 000 fill 1'1 Ct fit) Ihl Ihl MI 416 111 IM 1'7100111 8750 IIIUsl Ihu51 19 1.1 19331 73 9023 315.28 3961.73 402133 16716.16 11480 a 1614376 14957 15 -7525 77 058 606861165 504114 64 10 59868762 -149 96569057 1942437 9060 315.61 3967.05 402065 16805 83 17573.46 16831 98 1502320 -7590.73 0.58 6068677 59 504109.58 70.59886766 -149 96622494 19517.21 87 5I 315.14 396054 4022.14 1689566 17666.28 1592038 1509929 4655.90 3.31 6068743 57 504044 32 70 59904824 .149.96676102 19611 11 8728 313.98 397276 402636 1698607 1776008 1700935 1515511 -7722 73 1 27 606880926 503977.38 70 59922785 .149 96731083 19104 20 8860 31244 3976 10 4029.70 17075 13 17853 11 1709691 1521880 -7790.53 2 16 6068872 85 50390949 70 59940165 -149 96786857 19797 71 8965 310,58 397753 4031 13 17163.80 17946.61 1715400 1528076 .786055 2.28 6068934.70 503839 39 70 59957072 -149 96844447 19891.86 8963 31027 3918.12 4031.72 17252.51 1804076 17271 11 15341.81 -7932 22 033 6068995 63 503767 63 70 59973729 .149 96903400 1998423 6858 31168 397956 4033.16 1733982 18133 11 1735696 1540237 -8001 94 i 90 606905607 503697 81 70 59990252 .149 96960757 2007778 91 is 31289 3979.78 4033.38 1742892 18226.66 1744475 15465.31 -807115 304 60691/889 50362852 7060007425 -14997017685 20171 21 9042 313.74 397850 403210 1751841 1832008 1753304 15S2940 -8139 12 1 20 6069182 87 503560 45 70 60024912 149 97073604 20264 28 9068 31391 3977.61 4031.21 1760779 18413.14 17621 31 1559384 8206.26 033 6069247 20 503493 21 70 60042497 -149 97128843 2035781 egos 314.13 397783 4011,43 1769770 18506.67 17710 17 1565883 .827351 176 60693/208 503425.86 70 60060231 -149 97104175 20,451 30 8963 31489 3978.91 4032.51 17787 79 18600.15 1779928 15724.37 -8340.18 1.02 6069377 50 503359.10 70.60078113 -149.91239025 2054399 90 18 317 12 3979.06 4032.66 17877.72 18692 64 1788837 1519104 -8404.56 246 6069444 07 503294.62 70 60096308 -149 91291996 20637 31 89 14 31555 3970.62 4033.22 3796040 18766 16 1797824 1585855 -8466.99 202 5069511 46 503230 09 70 60114729 .149 97345010 20131 04 90 13 311.98 398021 4033.61 16058 37 18879 89 1806132 15923 37 -853666 395 6069576 17 503162 32 70 60132415 -149 974OD6694 2082435 9240 30984 3918.15 4031.75 18146.52 18973 17 1815450 15984.45 -8607.15 334 6069637 13 503091.74 70.60149080 .149 97458688 2091760 9395 310.96 397297 402657 18234 4 7 1906653 18241 51 16044 96 .867025 2.04 6069697 52 503020 55 70 60165588 .149 97517/61 2101086 0133 311.35 3968.69 4022-29 1832234 1915942 1832859 1610609 -8748 20 2.85 6069758 54 502950 52 70 60182266 .149.97574725 2110324 8948 313.02 3968.04 402164 16410.32 19251 80 18415 79 16168.12 -881664 2.70 606982045 502881 99 70 60199189 .149 97631041 21197.13 9126 31160 396743 402103 18499.77 19345.68 1850451 1623112 .8886.07 243 6069883.53 50281247 7060216430 -149.97668165 21291 50 9109 309.57 396550 4019.10 18588.75 19440 03 1859281 16292.70 -8957 72 2 16 6069944 79 502740 73 70 60233174 .149.97747116 2135391 91 19 314 17 3963.66 4017.26 1867653 1953242 1BUD 00 1635435 -9026.50 498 6070006 33 502671 85 70 60249993 -149 97803711 21476.65 9169 316.24 396132 401492 1876645 1962543 1876946 1642035 -909203 229 607007222 50260623 7060268001 .14997857638 2157070 92.11 317.04 395821 401181 1885761 19719 13 11186024 1648847 -915636 096 6070140 23 502541 80 70 60286589 .149 97010583 2166362 9061 31762 395600 4OD960 1894824 1991202 1595062 16556 71 -9219.32 1 73 6070208 42 502478 73 70 60305226 -149.97962401 2175729 9199 31843 395388 400748 1903985 1990567 1904183 1662639 -9281 95 1.71 6070277.93 502416 00 70 60324223 •149.98013951 2194293 9225 319.50 395045 4004 05 1913071 1999824 19132 44 1669622 -9342.12 1 19 6070347 66 502355 12 70 60343279 -149 98063960 21943.77 90 68 319.96 3948.05 400165 1022301 20092.05 1922451 16767 T9 -9403.36 1.74 6070419 13 502294 38 7060362811 .149 08113895 2203707 9032 31065 394224 4000.84 1931484 20185.35 19316.13 16839.05 -9463,57 051 6070490.29 502234 06 70 60382256 .149.98163463 2211000 90.32 319.65 3946.83 400043 1938658 2025827 19387 72 1689463 -9510.79 000 6070545.79 502186 70 70 60391425 .149 98202334 Survey Error Yod4I: 4SCWSA Rer 0 '-- 3 0 95.000% Con000nce 2.7955 sgma Surrey Program: D4-paoo Pon ISD From 161 MO To INI EDU Frey 1X1 H.I. Sue 11..1 Casing Domeier ... Survey Teel Type eoreholo ! Surve y 1 1238.780 2509.950 Ad Sins 1 2509 950 2851 400 Ad Stns 1 2851 400 2916.170 Acl Shu 1 2916.170 12712.150 Ad St - 1 12712.150 12767 000 ACI Sins 1 12767 000 12982.710 ACI St - 1 12982 710 22031 070 Ad Stns 1 22037.070 22110 000 Ad Sins Legai Oe dplion: Surface 4486 0 FSL 1186,3 FEL Sig T14N R9E UM OHL 255 FSL 344 FEL 35 TISN ROEUM 16000 13375 SLB_MWD+GMAG SP03-NE2P81l SP03ME2P81 16.000 13375 SLB MWD•GMAG SP03-NE2PHI ISP03-NE2PH1 12.250 9625 SLB_WJVD4NC ONLY FILLER SP03-NE2PB2I SP03-NE2PB2 12.250 9625 SL0_7AWO•GMAG SP03-NE2PB2 7 SP03-NE2P82 12.250 9625 SLB_MWD•GMAG SP03-NE20 ISP03-NE2LI 8.750 5500 SLB MWO-INC ONLY_FILLER SP03-NE2LI ISPO3-NE2L1 8750 5503 SLB_MWD•GMAG SP03-NE2LI ISP03-NE2LI 8750 5500 SLB BLIND•TREND SP03-NF2LI ISP03-NE2LI N911h111d m Eas6m (111 6053667 950 511723300 6070545.790 502186.760 Final Definitive Survey Huy B u i An h CrJRnez Ua�it Evrn 6El+'E Ee+.wrvgs+e :rn Verified and Signed -off 658 78 SLB DE: �c - Chen1 Representative: Datc: `' 1 DEC - 5 2019 AOGCC 9 Winston, Hugh E (CED) From: Winston, Hugh E (CED) Sent: Friday, January 24, 2020 11:27 AM To: Chaudhry Amjad Subject: SP03-NE2 L1 Well Completion Report Amjad, On the well completion report for SP03-NE2 L1 there are many items that need to be addressed.... ✓• The spud date is after the date TD was reached. Please correct the dates (Box 7 and Box 8) ✓• There is no date of first production but there is a date of test production. Please also list the date the well was first produced (Box 27) ✓• The method of operation for production is missing (Box 27) ,/• The coordinates for TD given in Governmental don't match the coordinates for TD given in State Base Plane. Please check both for errors (Box 4a and Box 4b for Total Depth) ,�• Hours tested is ambiguous format. Does this mean 4 hours and 16 minutes? Please use decimal format for clarity. (Box 27) • The 24 hour calculated rate for production does not match the hours tested rates. The numbers reported suggest the test period was 5.625 hours (Box 27) �• The oil gravity says "No Data reportex". Please provide this measurement (Box 27) Please make these corrections and submit a revised signed original of the report. Huey Winston Statistical Technician Alaska Oil and Gas Conservation Commission hugh.winston@alaska.gov 907-793-1241 THE STATE P 0 F 1 1 GOVERNOR MIKE DUNLEAVY Stefano Pierfelici Well Ops Project Manager ENI US Operating, Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP03-NE2 Ll Alaska Oil and Gas Conservation Commission ENI US Operating, Co. Inc. Permit to Drill Number: 219-126 Surface Location: 4486' FSL, 1186' FEL, SEC. 19, T14N, R9E, UM Bottomhole Location: 252' FSL, 342' FEL, SEC. 35, T15N, R8E, UM Dear Mr. Pierfelici: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this 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 AOGCC 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 AOGCC 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, i ssie L. Chmielowski Commissioner DATED this f-'� day of September, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 SEP 1 1 2019 1 a. Type of Work: • 1 b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 a Specify if well is proposed for: Drill ❑ Lateral ❑� Stratigraphic Test ❑ Development - Oil Service - Winj ❑ Single Zone Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: ENI US Operating Co. Inc. Bond No. RLB0008627 SP03-NE2 L1 ' 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 6A 3800 Centerpoint Drive Suite 300, Anchorage 99503 MD: 22,106 ' TVD: 4,004 Nikaitchuq/S>sd'er Bluff hrc:dr� i- 4a. Location of Well (Governmental Section): 7. Property Designation:X Surface: 4486 FSL 1186 FEL S19 T14N R9E UM ADL 0391283,. 0388571 03885811 0388583,A 'q -"-Z' Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 4438 FSL, 4042 FEL, 7 T14N R9E UM ADL 417493 9/28/2019 ' 9. Acres in Property: 14. Dis nce to Nearest Property: Total Depth: 252 FSL 342 FEL S35 T1 5N R08E UM 10940 5 to unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 54.1 ft 15. Distance to Nearest Well Open Surface: x-511723 • y- 6053668 • Zone- 4 GL / BF Elevation above MSL (ft): 13.1 ft to Same Pool: 2410' to SP05 16. Deviated wells: Kickoff depth: 12563 feet 17. Maximum Pgtential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 87 degrees Downhole: /yt`5 Surface: 1376 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 124 36 36 160 160 Pre -Installed 16" 13-3/8" 68 L-80 BTC 2880 35 35 2880 2454 In Place /Completed 12-1/4" 9-5/8" 40 L-80 Hydril 563 12970 33 33 12970 4088 In Place /Completed 8-3/4" 5-1/2" 15.5 L-80 Hydril 521 1 9785 12320 3653 22106 4004 Sidetrack -Liner in open holt 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 160.00 20" 160.00 160.00 Surface 2,916.00 13-3/8" Lead 505 bbls 11 ppg 2,916.00 2,487.00 Tail 74 bbls 12.5 ppg Intermediate 12970' 9-5/8" Lead 240 bbl 12.5 ppg 12,970.00 4,097.00 Production Liner 9,250.00 5-1/2" Slotted liner 22,035.00 4,005.00 Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No 0 20. Attachments: Property Plat ❑ BOP Sketch Drilling Programv Time v. Depth Plot R Shallow Hazard Analysis 8 Diverter Sketch F Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Amjad Chaudhry Authorized Name: Stefano Pierfelici Contact Email: a_ m[ad _chaudhry(a)_eni.com Authorized Title: Well Operations Project Manage Contact Phone: 907-865-3379 t�Authorized Signature: Date: Commission Use Only Permit to Drill �� API Number: _ Permit Approval See cover letter for other Number: 50- vCJ Date: /� Il requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: 3 5ocl Samples req'd: Yes L]No [2' Mud log req'd: Yes ❑ No [� HzS measures: Yes ❑ No[No[-]Directional svy req'd: Yes No Spacing exception req'd: Yes ❑ No L,// Inclination -only svy req'd: Yes ❑ No Post initial injection MIT req'd: Yes ❑ No ❑ �,k 'L� APPROVED BY Approved by: _ J` COMMISSIONER THE COMMISSION Date: auomn rorm ano Form 10-401 Revised 5/2017 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate �4C, �/C /e7- 0, l�G 1NA1. l '�* • Einli Poetrolleuin-en 2no 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.pierfelici@eni.com September 11, 2019 Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill Producer SP03-NE2 L1 Dear Commissioners, Eni US Operating Co. Inc. hereby applies for a Permit to Drill (Sidetracking Existing Well SP03-Ne2) for the Offshore Producer well SP03-NE2 L1. This well will be drilled/sidetracked and completed using the rig Doyon 15. . The planned spud date could be as early as 09/28/2019. Please find attached for the review of the Commission forms 10-401, the information required by 20 ACC 25.005. If you have any questions or require further information, please contact Amjad Chaudhry at 907 8653379 Sincerely, Stefano Pierfelici Well Operations Project Manager Enli Pearolleuinn2n � Application for Permit to Drill SP03-NE2 Ll Saved: 10 -Sep -19 Application for Permit to Drill Document Producer Well SP03-NE2 L1 Table of Contents 1. Well Name................................................................................................................3 Requirementsof 20 AA 25.005 (f)........................................................................................................ 3 2. Location Summary..................................................................................................3 Requirements of 20 AA 25.005(c)(2).................................................................................................... 3 Please see Attachment 7.- Surface Platt.................................................................................................. 3 Requirements of 20 AA 25.050(6)......................................................................................................... 3 3. Blowout Prevention Equipment Information....................................................4 Requirements of 20 AA 25.005(c)(3).................................................................................................... 4 4. Drilling Hazards Information................................................................................4 Requirements of 20 AA 25.005(c)(4)................................................................................................... 4 S. Procedure for Conducting Formation Integrity Tests......................................4 Requirements of 20 AA 25.005(c)(5)................................................................................................... 4 6. Casing and Cementing Program..........................................................................5 Requirements of 20 AA 25.005(c)(6).................................................................................................... 5 7. Diverter System Information...............................................................................5 Requirements of 20 AA 25.005(c)(7).................................................................................................... 5 B. Drilling Fluid Program............................................................................................6 Requirements of 20 AA 25.005(c)(8).................................................................................................... 6 LateralMud Program............................................................................................................................... 6 (MI FazePro Mineral Oil Base)................................................................................................................. 6 9. Abnormally Pressured Formation Information.................................................6 Requirements of 20 AA 25.005(c)(9)................................................................................................... 6 10. Seismic Analysis...............................................................................................6 Requirements of 20 AA 25.005(c)(10)................................................................................................. 6 11. Seabed Condition Analysis.............................................................................6 AOGCC PERMIT Document Updated09_09 2019 Page 1 of 7 Printed: 10 -Sep -19 • Einli Petrolleum Orn 2rnn � Application for Permit to Drill SP03-NE2 L1 Saved: 10 -Sep -19 Requirements of 20 AA 25.005 (c)(11) 12. Evidence of Bonding........................................................................................6 Requirements of 20 AA 25.005(c)(12)................................................................................................. 6 13. Proposed Drilling Program.............................................................................7 Requirements of 20 AA 25.005(c)(13)................................................................................................. 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .............7 Requirements of 20 AA 25.005(c)(14)................................................................................................. 7 15. Attachments......................................................................................................7 Attachment 1 Drilling Procedure.............................................................................................................. 7 Attachment Directional Plan.................................................................................................................7 Attachment 3 Drilling Hazards Summary................................................................................................. 7 Attachment 4 BOP and Diverter Configuration ........................................................................................ 7 Attachment 6 Formation Integrity And Leak Off Test Procedure............................................................ 7 Attachment7 Surface Platt...................................................................................................................... 7 AOGCC PERMIT Document Updated09_09_2019 Page 2 of 7 Printed: 10 -Sep -19 011rn Eini• tird� 0 J� r D leum Application for Permit to Drill SP03-NE2 L1 Saved: 10 -Sep -19 1. Well Name Requirements of 20 AA 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique AN number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: SP03-NE2 Ll 2. Location Summary Requirements of 20 AA 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) pplication:(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 4486 FSL 1186 FEL S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 54.1' AMSL Northing: 6,053,667' ° Easting: 511,723' Pad Elevation 13.1' AMSL Location at Top of Productive Interval ("OA" Sand) 4438 FSL 4042 FEL 7 T14N R9EUM ASP Zone 4 NAD 27 Coordinates Northing: 6,064,147Ea5t1ng: 508,812' Measured Depth, RKB: 12,898 Total Vertical Depth, RKB. 4,094 Total Vertical Depth, SS: 4,039 Location at Total Depth 252 FSL 342 FEL 35 T15N R08E UM ASP Zone 4 NAD 27 Coordinates Northing: 6,070,543' Easting.• 502,189' Measured Depth, RKB: 22,106' Total Vertical De th, RKB: 4,004' Total Vertical De th SS., 3,950' Please see Attachment 7.• Surface Platt and (D) other information required by 20 AA 25.050(b); Requirements of 20 AA 25.050(b) if well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well, Please see Attachment 2: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail, or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. AOGCC PERMIT Document Updated09_09_2019 Page 3 of 7 Printed: 10 -Sep -19 2 n i Ein! PWtrolleurnin Application for Permit to Drill SP03-NE2 L1 Saved: 10 -Sep -19 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable, - Please see Attachment 4: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient, The expected reservoir pressure in the Schrader Bluff sand is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). W' 14 SPU 3-- �E 2- ~` /XZ1 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 = (4,046' TVDss)(0.45 - 0.11 psi/ft) = 1376 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 geopressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. S. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document Updated09_09_2019 Page 4 of 7 Printed: 10 -Sep -19 Ar~ cin i Enli Petrolleuinn Application for Permit to Drill SP03-NE2 L1 Saved: 10 -Sep -19 6. Casing and Cementing Program Requirements of 20 AA 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 AA 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 ary V r "E> C l 7. Diverter System Information Requirements of 20 AA 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AA 25.035(h)(2); Please see Attachment 4: BOP and Diverter Configuration. AOGCC PERMIT Document Updated09_09_2019 Page 5 of 7 Printed: 10 -Sep -19 Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD in in /b/ft Grade Connection tt ft ft Cement Program 20 Driven 178.89 X-65 Welded 124 36/36 160'/ 160' Pre -Installed 13-3/8 16 68 L-80 BTC 2916' 35/35 2916'/ 2487' In place / Completed 9-5/8 12-1/4 40 L-80 Hydril 563 12962' 33/ 33 12962'/ 4097' In place / Completed 8-3/4" OA 5-1/2 Sand 15.5 L-80 Hydril 521 9785' 12,320'/ 3653' 22,106'/ 4004' Liner in Open Hole - no cement Lateral V r "E> C l 7. Diverter System Information Requirements of 20 AA 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AA 25.035(h)(2); Please see Attachment 4: BOP and Diverter Configuration. AOGCC PERMIT Document Updated09_09_2019 Page 5 of 7 Printed: 10 -Sep -19 72no �Eni P Application for Permit to Drill SP03-NE2 Ll Saved: 10 -Sep -19 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) pplication:(8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.0.33, Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI FazePro Mineral Oil Base) HTHP Fluid loss Value Density 8.7 — 9.4 Plastic Viscostiy CP 15-25 Yield Point lb/100 s 15-20 HTHP Fluid loss (m1/30 min na <5.0 200psi & 100 °F Oil / Water 60/40 Ratio Electrical Stability >600 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.- (9) pplication:(9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geopressured strata as required by 20 AAC 25.033(1),• Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a), Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified /n the application.- (11) pplication:(11) for a well drilled from an offshore platform, mobile bottom -founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b),• Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified In the application., (12) evidence showing that the requirements of20 AAC25.025 {Bonding)have been met; Evidence of bonding for ENI is on file with the Commission. AOGCC PERMIT Document Updated09_09_2019 Page 6 of 7 Printed: 10 -Sep -19 eni Ein! Nm arco011eum Application for Permit to Drill SP03-NE2 L1 Saved: 10 -Sep -19 13. Proposed Drilling Program Requirements of 20 AA 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: Please refer also to Attachment 1 — Drilling Procedure 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AA 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point or Spy Island Class I disposal well. Alternative disposal method will include hauling the fluids to the Prudhoe Bay Grind and Inject Facility. 15. Attachments Attachment 1 Drilling Procedure Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 BOP and Diverter Configuration Attachment 5 Formation Integrity And Leak Off Test Procedure Attachment 6 Surface Platt AOGCC PERMIT Document Updated09_09_2019 Page 7 of 7 Printed: 10 -Sep -19 Attachment 1 Drilling Procedure YMIN 2ni us open Hng WELL SP03-NE2 L1 Drilling Procedure SP03-NE2 L1 Spy Island Conductor slot #03 Reservoir location #NE2 L1 Producer (Schrader Bluff) Nikaitchuq Project SPO'-NE2 L1 Drilling Wellplan Page 1 of 21 09/11/19 gni us operrfing SP03-NE2 L1 North Slope - Alaska DIR / LWD DEPTH WELL7- SP03-NE2 L1 Spy Island Nikaitchuq Field SP03-NE2 L1 North Slope - Alaska DIR / LWD DEPTH HOLE CASING MUD INFO MWD FORM SIZE SPECS INFO MD TVD Cement to Surface 20" Hole Angle 0 a° X-65 0° 20" Conductor Shoe 160' ' 160' r f, Driven Welded N/A GR /Res Surface Csg 13-3/8" Dir /PWD FA 68# MW (ppg) Wellbore Stability Mud Motor B/ Permafrost 1,872' 1,764' L-80, BTC 8.8 - 9.5 Lost Circulation Hole Cleaning W in Casing Sections KOP: 250' Casing Wear DLS: Surface T/ Tail Cement 2,411' 2,187' 0-3.5 °/100' Hole Angle - 63.41 Deg 13-3/8" Csg 2,916' 2,487' 16" 50° F WBM GR / RES / PWD Inter. Casing Wellbore Stability 9-5/8" Lost Circulation Exceed900 40# MW (Ppg) Hole Cleaning L-80, Hydril 563 8.8-9.5 Torque & Drag Casing Sedans Tangent Angle: i Casing Wear 87.31 Deg "i BHA Expense Intermediate TOC 9,600' 3,698': Pick-up Top of Sand I� N Top 11,260' 3,953' Intermediate T/Tail Cement 13,012' 4,081' Hole Angle TOL 12,378' 4,015' -F! 87.31 Deg Base Whipstock 12,578' 4,078' I 12-1/4" 85" F WBM GR/RES j i Ecoscope/ PenSCOPE llll l��® I X I Wellbore Stability Lost Circulation I Slotted Liner Hole Cleaning 5-1/2" 1 I Torque & Drag 15.5# MW (PP9) Casing Sections Xceed 675 I I L-80, Hydril521 92-9.4 Casing Wear a BHA Expense I I I I I 1 I Liner shoe __--_TD 22,106 4,004' j i I I I I i Hole Angle 1 90.89 Deg ( 8-3/4" 85" F MOBM 2f�ln us operr Nng WELL SP03-NE2 L1 Table of Contents WELLPLAN SUMMARY.......................................................................................................... 4 WELLHISTORY......................................................................................................................... 6 RIH WHIPSTOCK AND 9 5/8" MILLING OPERATIONS ................................................... 7 Pick Up Production Drilling Assembly......................................................................... 9 PRODUCTION SECTION........................................................................................................ 10 ProductionDrilling........................................................................................................ 12 ProductionLiner........................................................................................................... 13 RIHESP Completion.................................................................................................... 15 Below the final planned schematic of the well after completion: ........................................... 15 ATTACHMENTS....................................................................................................................... 15 Recommended Drilling Practices................................................................................. 17 Health, Safety & Environment..................................................................................... 18 SafetyMeeting Topics................................................................................................... 19 Well Shut In Procedure While Running Production Tubing .................................... 21 SP03-NE2 L1 Drilling Wellplan Page 3 of 21 09/11/19 cin i Mss operr Vng WELL SP03-NE2 L1 WELL PLAN SUMMARY Rig: Doyon 15 Type of Well: Producer Well Design: 13-3/8" Surface x 9-5/8" Intermediate x 5-1/2" Liner Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. The directional program and a summary of close approaches can be found in the attachments. These close approaches will be in conformance with the minimum well separation criteria detailed by the Drilling Anti -Collision Analysis and Close Approach Guidelines. It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned, that the position of the well as it is drilled is monitored on an anti -collision diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planned well path as any major deviations from the profile may adversely affect the ability to drill future wells and still adhere to the current close crossing guidelines. Survev ProLyram & Procedures Take MWD surveys as frequently as needed, but no less than every 100 ft. Carefully review the anticipated close crossings with existing wellbores and future well paths. Make sure that directional drillers are aware of all drilling close crossing issues, hard lines and no-go lines. If a no-go or hard line has been or will be crossed, stop drilling immediately and contact the Drilling Superintendent to discuss options. Mud Logging Program Mudlogging will be utilized from spud to production hole TD. Refer to the Geological Mud Logging Procedure document. SP03-NE2 L1 Drilling Wellplan Page 4 of 21 09/11/19 2ni ass operrah*ng WELLT- SP03-NE2 L1 OBJECTIVES: 1. Drill the well at or under AFE cost and time. Perform work in a safe and professional manner meeting all ENI Petroleum Health, Safety, and Environmental requirements. 2. Cut window in the 9 5/8" casing and drill 2nd lateral per the well plan. Maximum dogleg severity in the landing shall be no greater than 3.5°/100' DLS. 3. Execute the setting and orientation of the whipstock per the wellplan. 4. Target Greater than 90% within the OA sand Reservoir. 5. 8-3/4" hole LWD Failure Requirements: GR/Res/Dir/PWD— Require GR/Res/Dir to achieve TD. SP03-NE2 Ll Drilling Wellplan Page 5 of 21 09/11/19 WELL HISTORY Current Status Well SP03-NE2 is currently being drilled. After the production phase a new lateral in 8 3/4" will be performed. Scope of Work Scope of this work is drill a new 83/4" lateral section, RIH a second 5 '/2" slotted liner and run in with a new ESP system to have a commingle production for both lateral.. General Well info Reservoir Pressure/TVD Wellhead type/pressure rating: BOP configuration: This well is expected to have a static max bottom hole pressure of approximately 1978 psi during the drilling time. Act- Vetco Gray, MB -247/5000 psi Annular/pipe/blind/pipe SP03-NE2 LI Drilling Wellplan Page 6 of 21 09/11/19 WELL SP03-NE2 L1 WELL HISTORY Current Status Well SP03-NE2 is currently being drilled. After the production phase a new lateral in 8 3/4" will be performed. Scope of Work Scope of this work is drill a new 83/4" lateral section, RIH a second 5 '/2" slotted liner and run in with a new ESP system to have a commingle production for both lateral.. General Well info Reservoir Pressure/TVD Wellhead type/pressure rating: BOP configuration: This well is expected to have a static max bottom hole pressure of approximately 1978 psi during the drilling time. Act- Vetco Gray, MB -247/5000 psi Annular/pipe/blind/pipe SP03-NE2 LI Drilling Wellplan Page 6 of 21 09/11/19 2n� us operac�ng WELL SP03-NE2 L1 Procedure: RIH WHIPSTOCK AND 9 5/8" MILLING OPERATIONS 1. RIH with a Drift/clean out BHA to the top of the previous 5 %" liner. 2. PU MLZXP LH assembly and sting in to the SLZXP. spV4osition hanger & packer at the desired depth. Use MWD to record orientation of MLZXP profile as this is W critical for future use. Repeat multiple times until all parties are in agreement on MLZXP hanger orientation. 4. POOH and LD running tool. Mill a window in 9 5/8" 40# casing. Notes: a) It is important that the whipstock assembly be spaced out to ensure that the entire window is milled between casing collars. b) The approximate overall length of the casing window to be milled is 14'-16' ft. c) All measurement and procedures are to be double-checked and approved by Co.Man prior to running the whipstock/window milling assembly in the hole. d) Ensure drill pipe pup joints are available for the correct space out e) After the window is milled, the upper watermelon mill should be gauged. If the upper watermelon mill is more that 1/8" under gauge a cleanup trip is recommended to ensure window is fully open. A back up set of mills should be on location. f) Ditch magnets should be placed in the flow line to recover all metal circulated out of the well Whinstock/Window Milling Guidelines: ➢ Check with Geologist to confirm if there is a concretion at the window milling depth. ➢ Never rotate a bit on the face of the whipstock ➢ Orient the BHA (if motor is used) above the window before attempting to exit the window. Bit rotation may "catch" the edge of the whipstock and damage the face making recovery operations more difficult. ➢ If at any time during operations a problem is encountered tripping through the window area, a watermelon or string mill should be run in the drilling assembly to clean up the window area ➢ Always trip slowly and carefully ( +/- 90 seconds per stand) with all BHA's through the milled window SP03-NE2 L1 Drilling Wellplan Page 7 of 21 09/11/19 y� eni us operr Vng WELL SP03-NE2 L1 Procedure: 1. Prior to mill the window, hold a Tech Planning meeting to discuss this phase of the well. Review the well plan and discuss any discrepancies or concerns with the drilling superintendent 2. RIH the whipstock assembly 3. At surface align the MWD with the whipstock face 4. Shallow test the MWD tools 5. RIH to setting depth 6. 45' above setting depth establish circulation and work torque out of string. 7. Orient the whipstock as per well plan. Once the correct orientation is confirmed, Slack off slowly to land the Anchor and latch to MLZXP. 8. Initiate circulation and obtain a survey of the installed whipstock orientation 9. Start 9 5/8" casing milling operation. Establish rotation to begin milling the window. 10. After the window is complete and before POOH, shut pumps and work milling assembly through window several times watching for drag. POOH and UD milling assembly. SP03-NE2 L1 Drilling Wellplan Page 8 of 21 09/11/19 2rni� us operrfing WELL SP03-NE2 L1 Pick Up Production Drilling Assembly 1. PU the 8-3/4" bit and the BHA assembly as per the BHA diagram. ➢ 8-3/4" PDC ➢ Rotary Steerable ➢ Flow rate: 550 GPM ➢ 120 — 140 RPM Oil Based Mud Fluid Dis>alacement 2. Drill 20'-50' of new hole usine the Oil Based Reservoir Drill -In fluid. 3. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ PU into casing and perform LOT. ➢ If the pressure continues to rise past 12.5 ppg EMW, shut down and call it a FIT per the FIT Guidelines (attached). '---� ➢ If LOT is unacceptable to drill ahead (less than 12.0 ppg EMW), contact Drilling Superintendent to discuss options. ➢ Do not pump more than 1/2 bbl after leak off is determined. There is no need to pump more than 1/2 bbl into the leak off and extend the fracture. ➢ Plot on LOT form in N drive SP03-NE2 L1 Drilling Wellplan Page 9 of 21 09/11/19 2ni FIs cop rrai�ng Measured Depth, ft TVD Depth, ft Comments SV -4 WELL SP03-NE2 L1 PRODUCTION SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberj4er Plan .; Formation Tops Measured Depth, ft TVD Depth, ft Comments SV -4 766 764 SV -3 1136 1118 SV -2 1441 1392 B/Permafrost 1864 1766 SV -1 2073 1943 UGNU TOP (UG4) 2526 2273 13-3/8" Csg 2916 2487 SCP UG -2 Coal Bed Marker 4215 2836 LOWER UGNU 8878 3582 Schrader Bluff 10738 3872 N Sequence Top 10940 3903 N Top 11260 3953 N Bottom 11472 3981 N Sequence Base 11803 4028 OA Top 12898 4094 9-5/8" Csg 12962 4097 In Place OA -2 Top 13436 4039 Base Window@12,578' 5-1/2" Liner 22106 4004 Total Depth SP03-NE2 L1 Drilling Wellplan Page 10 of 21 09/11/19 ok 2rnn g us operrWi�ng Tool Tool Make Upaci WELL SP03-NE2 L1 Production Mud Program: Fa_zePro Production Loedne/Formation Evaluation Program: Production: MWD Directional / PWD Pressure While Drilling) LWD GR / Res / Ecosco e/ PeriSCOPE Production Drill Pipe Tool Tool Make Upaci Electrical Body Density Tensile HTHP FL Joint Joint Interval (ppg) yp (ml/30min) Oil:water Stability (PPO ID (in) ) .lbs) mlvolts Production 9.4 15-20 <5.0 60:40 >600 Production Loedne/Formation Evaluation Program: Production: MWD Directional / PWD Pressure While Drilling) LWD GR / Res / Ecosco e/ PeriSCOPE Production Drill Pipe Production Section Notes: a. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher (attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. b. Shallow test MWD tools. c. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. d. Keep shut down times to a minimum during connections. When surveying in this hole section reciprocate the pipe slowly while the survey is transmitted uphole. Keep the pipe rotating whenever possible. e. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. Openhole Sidetracking Practices: f. Lowside in a fast drilling interval where the wellbore is heading up and where the ABI's show a good build rate. g. Orient within 15 degrees either side of lowside and trough with high rotary RPM's while reciprocating from the kickoff point back to the first stabilizer. Trough for approximately 30 minutes. h. Time drill at 4 to 6 feet per hour with high flow rates and rotary RPM'S for the first 5 feet. Gradually increase the penetration rate as the openhole sidetrack is achieved. i. If any openhole sidetracks are drilled, confer with Drilling Supt. and consider tripping without circulating or without rotating past the sidetrack point. SP03-NE2 L1 Drilling Wellplan Page 11 of 21 09/11/19 Tool Tool Make Upaci Joint Body DP Tensile Pipe Grade Conn. type Joint Joint Body Torque Torsionalrsion ty Capacity (PPO ID (in) ) .lbs) al Yield Yield w conn. (kips) in t lbs) t.lbs al /ft) 4.5" DP 16.6 S-135 Delta 425 5.25 3.00 3.826 35,000 43,450 43,500 .560 471 5" DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 1 74,100 .731 712 Production Section Notes: a. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher (attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. b. Shallow test MWD tools. c. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. d. Keep shut down times to a minimum during connections. When surveying in this hole section reciprocate the pipe slowly while the survey is transmitted uphole. Keep the pipe rotating whenever possible. e. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. Openhole Sidetracking Practices: f. Lowside in a fast drilling interval where the wellbore is heading up and where the ABI's show a good build rate. g. Orient within 15 degrees either side of lowside and trough with high rotary RPM's while reciprocating from the kickoff point back to the first stabilizer. Trough for approximately 30 minutes. h. Time drill at 4 to 6 feet per hour with high flow rates and rotary RPM'S for the first 5 feet. Gradually increase the penetration rate as the openhole sidetrack is achieved. i. If any openhole sidetracks are drilled, confer with Drilling Supt. and consider tripping without circulating or without rotating past the sidetrack point. SP03-NE2 L1 Drilling Wellplan Page 11 of 21 09/11/19 s FIs operrfing WELL SP03-NE2 Ll Production Drilling 1. Directionally drill the 8-3/4" hole to TD. ' ➢ Geosteering will be required to remain in the target boundary 100% of the time ➢ Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. ➢ Maintain proper Calcium Carbonate concentration per MI mud plan. ■ Ensure Centrifuges are operating effectively to remove fine drill solids 2. Backream at TD: ➢ At TD circulate 50% of calculated TAD cleanup cycle pulling 1 stand per bottoms up. Once the first 50% cleanup cycle is completed circulate the remaining 50% of the calculated cleanup cycle pulling 2 stands per bottoms up. Decrease backreaming speed as torque and pump pressure dictate. ■ 550 GPM ■ 120-140 RPM Backream to upper stabilizer +/- 100' window' below window. Take care when pulling into the window as cuttings accumulation is possible. > Do NOT ream across whipstock. • 550 GPM • 120-140 RPM • Pull with pumps only into the window and above the whipstock. Perform clean up cycle as needed observing cuttings volume at the shakers. • Decrease back reaming speed as torque and pump pressure dictate 3. Continue backreamin2 until depth at which it is possible to pull out on elevators at >9.1 swab EMW at 2.5 min/stand i. 550 GPM ii. 120-140 RPM 1. Determine depth at which swab can be kept >9.1 EMW as per K&M TAD Model. 4. Circulate until shakers are clean as per K&M. iii. 550 GPM iv. 120-140 RPM 5. Slug DP and trip out of hole on elevators. b. Utilize K&M's swab model to control trip speed and avoid swabbing the open hole below f9.1 ppg EMW. 6. Lay down BHA. ➢ c. When out of hole, download the recorded tool data and send to the Geologist in townWhen out of hole, down load the recorded tool data and send to the Geologist in town 3. RIH with retrieving tool assembly to retrieve the whipstock assembly I/ SP03-NE2 L1 Drilling Wellplan Page 12 of 21 09/11/19 en i us ap r Nng WT (pP� Grade Conn. Cplg OD WELL SP03-NE2 L1 Production Liner Completion DP RABBIT SIZE Will BE: 2-3/8" OD Production Liner OD WT (pP� Grade Conn. Cplg OD ID (in) Drift (in) Collapse Burst Tensile Yield in field (in) Type in Torque, ft- Make Up Make Up (psi) (psi) (kips) lbs Torque* Torque H521t1 5-1/2 15.5 L-80 H dril521 4600 8100 N/A 24,000 5-1/2 1.5.5 L-80 5.713 4.950 4.825 4990 7000 242 Production Liner Connection Make Up Torque (ft -lbs) * See attached TenarisHydril Guidelines for make-up torque recommendations Production Liner Centralization From To Quantity / JointF Min. HRD Running Tool Shoe OD WT Fixed Make Up Target Max. field (in) (ppfi Grade Conn. Type Torque, ft- Make Up Make Up Torque lbs Torque* Torque 5-1/2 15.5 L-80 H dril521 4600 8100 N/A 24,000 * See attached TenarisHydril Guidelines for make-up torque recommendations Production Liner Centralization From To Quantity / JointF / FloatingType HRD Running Tool Shoe Liner 1 /joint Fixed _ 5-1/2" x 7" to - Mid -joint - Crim ed on - H droform, Volant (Crim on) Liner Running Procedure Notes: • Ensure proper crossover from DP to slotted liner is on the rig floor in case of a well control situation. • Liner top should be placed a minimum of 200 ft above the intermediate casing shoe. • Ensure accurate torque and drag data is gathered. Record pick up and slack off weights every stand and free rotating torque every five stands. Data gathered will assist in future liner running operations throughout the project. • Perform visual inspection, measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional data is recorded for all equipment run in the well and recorded in WellView. • Ensure all equipment has been hydraulically and operationally tested. Also ensure all equipment to be run is dimensionally compatible with all other equipment. • Review all setting operations and shear pressures with Baker Oil Tools service hand. • Ensure that all workstring components have been rabbited as ball will be dropped to actuate downhole tools. Rabbit DP on last trip out of prior to running liner. • If any openhole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters the correct hole. • Torque ratings for string components: String Components Yield Torque ft -lb 5" 19.5# TT525 Drill Pie 74,100 HRD Running Tool 40,000 7" 29# Hydril 563 39,000 I/ SP03-NE2 L1 Drilling Wellplan Page 13 of 21 09/11/19 Frill eni uss aper Vnng Shear Value Shear Range HRD Running Tool, 7" 6795 mch rel, 3 pins Nominal - WELLT_ SP03-NE2 L1 15-1/2" 15.5# Hydril 521 I 24,000 • Shear pressures for liner hanger assembly: Item Description Shear Value Shear Range HRD Running Tool, 7" 6795 mch rel, 3 pins Nominal - 3192 psi 15%+ 3671 psi 15%- 2713 psi Pusher Tool Activation Nominal - 1986 psi 15%+ 2284 psi 15%- 1688 psi Pusher Tool Neutriz. Nominal - 3588si 15%+ 4126 psi 15%- 3050 q Ball Seat I I SOLID *****Make-up torque for liner hanger sub -assembly, including running tool connections, should be torqued to 14,000 ft -lbs prior to deliver to rig. Procedure: 1. Hold Pre job safety meeting to ensure all parties understand operation 2. PU the Liner Assembly and Running/Inner String as outlined above. 3. RIH with Liner Assembly. Record PU and SO weights as required. 4. Pick up liner hanger assembly and make up to proper torque. Fill Liner Tieback Sleeve with "pal mix" and ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 minutes for mixture to set up. 5. Trip in hole one stand and circulate 5 bbls to ensure all flow paths are free. Record ROTATE, PU and SO of liner assembly. 6. RIH in hole to casing shoe with DP. RIH with Liner Assembly as hole conditions allow, but do not exceed running speed of one stand per minute. Break circulation and fill DP as necessary. 7. Monitor mud flow while running in open hole and slow running speed if necessary. Circulate minimum of one DP volume and record ROTATE, PU and SO weights. 8. Record PU, SO, and Rotating torque in open hole every 500' to ensure friction factors are sufficient to run the liner to bottom successfully. If friction trend indicates liner will not go to bottom then call Drilling Supt. immediately. p' 9. Rotating liner 20-60 RPM will be necessary to run to bottom. 10. Continue RIH with Liner Assembly to proper setting depth. Liner should be spaced out to locate the liner top approximately 200 feet above 9-5/8" window. 11. Trip slightly deeper than desired liner top location with liner top. Last motion of the liner should be up to ensure it is set in tension. Ensure Liner Hanger assembly does not exit 9-5/8" Window. 12. Prior to setting the hanger & packer, double check all pipe tallies and record amount of drill pipe on location. 13. Rig up to pump down workstring with rig pumps. Pressure test lines. Bleed off test pressure. 14. Drop setting ball down the workstring and pump slowly (1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 15. Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger picker. Continue pressuring up in 500 psi increments holding for 5 minutes each up to 4000 psi. 16. Packer can now be pressure tested. Bleed DP pressure to zero, close annular preventer and test annulus to 1,500 psi for 10 minutes and chart. 17. Bleed off pressure and pickup to verify that the HRD running tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, 6,795 ft -lbs of left hand torque can mechanically release the tool. 18. Once running tool is free and packer is tested, Displace mud from liner top to surface with 9.0 ppg KCl brine per MI recommended pram. SP03-NE2 L1 Drilling Wellplan Page 14 of 21 09/11/19 TIM enli us oper Hng ' 5' MD/TVD swivel joint Tracers +J- 22,035 MD, . 4-1/V 12.6 ppf Production Tubing hydril W563 WELL SP03-NE2 L1 19. POOH and LD and inspect the liner running tools. RIH ESP Completion Prepare to RIH completion: MU ESP assembly and RIH to setting depth. 1. Land hanger, RILDS and test hanger. 2. Install BPV and nipple down BOP. 3. NU tubing adapter and tree. 4. Pull BPV , install test plug and test tree. 5. Circulate Freeze protect through tree down IA. 6. Shut in well Below the final planned schematic of the well after completion: Surf. Casings ' 5' MD/TVD swivel joint Tracers +J- 22,035 MD, . 4-1/V 12.6 ppf Production Tubing hydril W563 eni pekrWeaam 4-1,S" x-cplg cable clamps. for ESP Power Cable. (1) 318" Chem Inj Line SP03-NE2 L1 Dual with 1800 psi check valve at bottom �'— 3.68 Seal Bore, drift 3.63" Guide Closed Shoe ppf Lateral Producer with 63° Inc ESP Lift +/-22.100' MD. 4,004' L80 Slotted Liner LBO lotted? As Planned 11.482' MD, 3,984' TVD - Discharge Gauge Sub +/- 11,582' MD, 3,997' TVD, 82° Inc- Bottom of Motor Centralizer Centrilift, ESP, 66 stage FLEX 47 SXD 20 stage GINPSHH SXD, 513 GS83 seals, 350 HP MSP325 motor,538 gas separator --` Casing Exit Window1 +1_ 11,600' MD 32# Shroud Assembly with cable and chemical i injection line feed-thrus 3 5" Surf. Casings ' Packer Tracers +J- 22,035 MD, 13-318", 68 # 2,916" MD, 4 %" Lateral Entry Module (LEM) w/ Silver Bullet Ecc. Nose TD 8 314" 2,487 TVD _ �'— 3.68 Seal Bore, drift 3.63" Guide Closed Shoe ppf +1_ 22,106' 63° Inc +/-22.100' MD. 4,004' L80 Slotted Liner LBO lotted? MD, 901 Inc 4.004' TVD +i- 12,378' MD, 4,078' --` Casing Exit Window1 L TVD - L1 - Baker SLXP - Liner Hanger/Packer RAM Hanger 5.875 " Lateral Drift ID 4.825" Main bore Drift ID 4-'A" x 9.5/8" RAM N'�' Seal Bore Diverter p� 1 wl 3.64" Seal Bore 11�J Drift 3.65" Baker MLXP Liner Hanger/Packer Bottom of Seat Assembly Nikanchud Field -Sov Island kXSeaibore Receptacle i 4.75' ID NZ-4�T Interm, Casing 9.518"400 +/- 12.962' MD. 4.097' TVD 87° Inc. HAL 5-1W Oil Swell Resman Oil/Water TD 8 3/4" Packer Tracers +J- 22,035 MD, ,( r 4,006' TVD 91° Inc. � S-%'1&5 ppf L80 Slotted Liner Silver Bullet Nose Guide Shoe +!- 22,000' MD, 4.006' TVD. 90° Inc. SP03-NE2 L1 Drilling Wellplan Page 15 of 21 09/11/19 2nd us operr Vng WELL SP03-NE2 L1 ATTACHMENTS 1. Recommended Drilling Practices 2. Health, Safety, and Environment 3. Safety Meeting Topics 4. Well Shut In Procedure While Running Tubing SP03-NE2 Li Drilling Wellplan Page 16 of 21 09/11/19 Fyn e n i us opera Ling WELLT- SP03-NE2 L1 Recommended Drilling Practices Hole Cleaning With a deviated well path and potential for losses, hole cleaning will require special practices. Pipe rotation is critical for effective hole cleaning. The maximum string RPM, as determined by the BHA, is specified for each hole section in the detailed procedures. The shakers should be monitored as an indicator of adequate circulating time. If circulation is of long duration, then pipe movement to prevent casing wear is critical and a stand should be laid down occasionally to prevent excess hole erosion over the length of pipe reciprocation. In addition the following practices should be employed at all times: a) Use all available solids control equipment to keep mud as clean as possible. b) Emphasize proper hole cleaning after slides by rotating at maximum allowable RPM c) As the hole angle increases, hole cleaning practices must be altered. Maximum pipe rotating speeds along with maximum achievable flow rates will increase hole cleaning efficiencies. Circulating times prior to trips should be increased accordingly to account for longer times required to remove cuttings from higher angle wells. d) Use good connection practices while drilling. After reaching the bottom of a stand, allow a small amount of circulating time to allow cuttings to get above the BHA prior to picking up off bottom. Be sure to pick up slowly to prevent packing off the cuttings bed around the top of the drill collars. Slower Trip / Connection Speeds High POOH and RIH speeds can aggravate fragile shales/formations due to the pressure variations between surge/swab. PWD data shows that excessive tripping and reaming speeds can exert pressure spikes in excess of 2 ppg equivalent. Effective ROP Strive to find the maximum effective rate of penetration. That is, the maximum rate at which a clean hole can be produced. While on bottom ROPs in excess of 400 ftph may be possible, but such ROPs may load a high angle hole with cuttings that are not being removed fast enough. Using torque and drag trends, ECD and the shakers, establish a base line clean hole ROP, and then try to improve it by altering the hole cleaning practices. Slower Initial Pump Rates PWD data has shown that the most significant period for increased ECD occurs when the pumps are brought on at drilling rate while washing a connection to bottom. The study also concluded the least damaging procedure is if pump rates are held at 40% or less of drilling rate while reaming connections. SP03-NE2 L1 Drilling Wellplan Page 17 of 21 09/11/19 2rnl0 � us operaC�ng _F_ WELL SP03-NE2 L1 Health, Safety & Environment The following are part of the mitigation & contingency measures to be put in place in order to complete this project while helping to meet our HS&E goals. It is the Drilling Supervisor's responsibility that these measures are implemented and communicated to the relevant parties on location. Good communication when drilling is essential for increasing the safety of personnel and equipment. f H2S Contingency Measures Assume all locations have the potential for H2S. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Manual detectors in accordance with 20 AAC 25.065 will also be maintained on location. 3. Self-contained Breathing Apparatus for all rig personnel will be maintained on location. 4. All personnel engaged in the drilling operation will be trained in H2S emergency procedures and the use of proper personal protective equipment. 5. A standard H2S contingency plan will be posted at the rig. All rig personnel should read and familiarize themselves with this document and copies should be posted in the rig floor doghouse and in the camp on location. 6. H2S treating material for the drilling mud system will be available on location in the event that any H2S is encountered. It is expected that the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. If it becomes necessary to notify the AOGCC of an H2S encounter, drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures, full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49 and approval of the AOGCC. Lessons Learned Documentation of lessons learned has been proven to reduce downtime and increase efficiency of rig operations. It is expected that planning meetings, daily operations meetings and pre -tour meetings will be held on a regular and consistent basis and that the records of those meetings will be placed on the N drive in the appropriate folder for this well. SP03-NE2 L1 Drilling Wellplan Page 18 of 21 09/11/19 2n� uss operrMiong WELL SP03-NE2 L1 Safety Meeting Topics Move In, Rig Up ➢ Prior to spud, a safety meeting should be held with the rig crews to discuss open hole drilling procedures. - Subsidence around wellheads - use of buddy system, - Conductor broaching operations and contingencies, - Shallow gas hydrate drilling practices, - Proper tripping practices and hole fill calculations with various sizes of pipe and tubing, - Well control procedures, - Flow rates and hole cleaning, and - Diverter operation and crew responsibilities. ➢ A'Diverting Shallow Gas' drill should be held with rig crews prior to spud, unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ An 'Accumulator' drill should be held with rig crews prior to spud. Document drill and record on morning report. ➢ Shut-in drills should be held on a regularly scheduled basis. A suggested minimum is once per day on alternating tours. Document and record on morning report. ➢ Check trip tank for leaks and confirm gauges are calibrated. Complete trip sheets and submit to the Drilling Supervisor after each trip. ➢ Perform and document all drills. ➢ Designate crew member to control access at the pad entrance in case of diverter operation. Surface ➢ A 'Stripping' drill should be held with rig crews prior to drill out, unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A 'Well Kill' drill should be held with rig crews prior to drill out, unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A well kill sheet shall be posted in the doghouse and updated each tour. Intermediate ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight, Well control procedures. ➢ Hole cleaning best practices, flow rates. ➢ Stuck pipe, Lost circulation. ➢ Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Production ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss production hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight, Well control procedures. ➢ Hole cleaning best practices, flow rates. ➢ Stuck pipe, Lost circulation. ➢ Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. SP03-NE2 L1 Drilling Wellplan Page 19 of 21 09/11/19 2ni us ap r Vng WELL SP03-NE2 L1 Completion ➢ Operation of the control line spooler. ➢ Pinch points associated with tongs and slips. ➢ Proper tripping practices and hole fill calculations with tubing and control line. ➢ Well control practices while running production tubing with control line. ➢ Pressure testing and minimizing personnel exposure to pressurized lines. SP03-NE2 L1 Drilling Wellplan Page 20 of 21 09/11/19 2no us ®perrWHng WELL SP03-NE2 L1 Well Shut In Procedure While Running Production Tubing If well is suspected to be flowing: 1. Install TIW valve and pull back to the first banding point below the BOP stack. 2. Shut off air to control line spool and bleed off line pressure while checking well for flow. 3. If well is confirmed to be flowing, cut control line with bolt cutters directly above a banding point. 4. Slack off until full joint of pipe with no control line attached is spaced out across BOP stack. 5. Close annular and monitor pressure. If well is coming in rapidly and time is not permitted to complete above operations: 1. Install TIW and close annular around pipe and control line. 2. Shut off air to control line spool and bleed off line pressure while picking up a joint of drill pipe and making it up to TIW and top drive. 3. Close IBOP on top drive and open TIW valve. 4. Cut control line and strip the joint of drill pipe across stack for ram closure if needed. 5. If annular does not seal off around tubing and control line and the joint of drill pipe cannot be safely picked up, close blind/shear rams on production tubing. Notes: • Specify location of bolt cutters required to cut control line. • Need to have access to a joint of drill pipe and the appropriately sized elevators at all times. SP03-NE2 L1 Drilling Wellplan Page 21 of 21 09/11/19 Attachment 2 Directional Pla n Schlumberger Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI I API#: Survey Name: Survey Date: Tort / AHO I DDI I ERD Ratio: Coordinate Reference System: Location La t /Long: Location Grid N/E Y/X: CRS Grid Convergence Angle: Grid Scale Factor: Version / Patch wn SP03-NE21-1 (P7) Proposal Geodetic Report ani (Def Plan) September 05, 2019 - 01:55 PM Eni Petroleum Nikaitchuq Spy Island / SP03 SP03-NE2 SP03-NE2 L1 Unknown 150629236396100 SP03-NE21-1(P7) June 26, 2019 250.411 ' 120253.171 fl 17.437 14.940 NAD27 Alaska Slate Plane, Zone 04, US Feet N 70' 33'28.21524". W 149' 54'13,84572" N 6053667.950 ftUS, E 511723.300 flUS 0.0907 ° 0.99990016 2.10.544.0 Survey I OLS Computation: Vertical Section Azimuth: Vertical Section Origin: ND Reference Datum: ND Reference Elevation: Seabed I Ground Elevation: Magnetic Declination: Total Gravity Field Strength: Gravity Model: Total Magnetic Field Strength: Magnetic Dip Angle: Declination Date: Magnetic Declination Model: North Reference: Grid Convergence Used: Total Corr Mag NorthaTrue North: Local Coord Referenced To: Minimum Curvature/ Lubinski 0.000' (True North) 0.000 ft, 0.000 ft Rotary Table 53.600 ft above MSL 13.100 fl above MSL 16.268 ° 1002.0156mgn (9.80665 Based) DOX 57403.989 nT 80.968 ° December 31, 2019 BGGM 2018 True North - 0.0000 ° 16.2679 ° Well Head Nikaitchuq\Spy Island\SP03-NE2\SP03-NE2 L1\SP03-NE2L1 (P7) Drilling Office 2.10.544.0 Schlumberger -Private 9/5/2019 4:21 PM Page 1 of 3 MD Incl Azim True NDSS ND VSEC NS EW TF DL Directional Exclusion Exclusion ZoneS GeoMag Th Northing Easting Latitude Lon; Comments (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (°) (°/t00ff) Difficulty Index Zone Alert Angle AnIle (nT) (ftUs) (ftUS) (NIS ° - (EIW Top Whipstock 12563.00 87.00 315.00 4024.39 4077.99 10289.53 10289.53 -2639.54 301. 0.00 6.77 82.71 56974.22 6063952.24 509067.75 N 7035 9.40 W 149 55 31.88 Base Whipstock 12578.50 88.68 314.03 4024.97 4078.57 10300.39 10300.39 -2650.58 HS 12.50 6.78 84.51 57174.70 6063963.08 509056.69 N 7035 9.51 W 149 55 32.21 C,4/100 12598.50 88.68 314.03 4025.43 4079.03 10314.29 10314.29 -2664.96 85.77L 0.00 6.78 84.51 57174.71 6063976.96 509042.30 N 7035 9.65 W 149 55 32.64 12600.00 88.68 314.00 4025.47 4079.07 10315.33 10315.33 -2666.04 85.77L 2.00 6.78 84.51 57175.32 6063978.00 509041.22 N 7036 9.66 W 149 55 32.67 12700.00 88.83 312.01 4027.64 4081.24 10383.51 10383.51 -2739.15 85.73L 2.00 6.79 84.94 57214.69 6064046.06 508968.01 N 7035 10.33 W 149 55 34.83 12800.00 88.98 310.01 4029.56 4083.16 10449.11 10449.11 -2814.59 85.691. 2.00 6.80 85.37 57251.36 6064111.53 508892.47 N 7035 10.97 W 149 55 37.06 12900.00 89.13 308.02 4031.21 4084.81 10512.05 10512.05 -2892.27 85.65L 2.00 6.82 85.81 57285.14 6064174.34 508814.69 N 7035 11.59 W 149 55 39.36 12926.21 89.17 307.49 4031.60 4085.20 10528.10 10528.10 -2913.00 HS 2.00 6.82 85.93 57293.50 6064190.36 508793.94 N 70 35 11.75 W 149 55 39.97 13000.0089.17 307.49 4032.67 4086.27 10573.01 10573.01 -2971.53 HS 0.00 6.82 85.93 57293.51 6064235.17 508735.34 N 7035 12.19 W 149 55 41.70 13100.00 89.17 307.49 4034.12 4087.72 10633.87 10633.87 -3050.87 HS 0.00 6.83 85.93 57293.52 6064295.90 508655.92 N 7035 12.79 W 149 55 44.05 13200.00. 89.17 307.49 4035.56 4089.16 10694.73 10694.73 -3130.20 HS 0.00 6.84 85.93 57293.52 6064356.63 508576.50 N 7035 13.39 W 149 55 46.40 13300.00 89.17 307.49 4037.01 4090.61 10755.60 10755.60 -3209.53 HS 0.00 6.84 85.93 57293.53 6064417.36 508497.08 N 7035 13.99 W 149 55 48.74 13400.00 89.17 307.49 4038.46 4092.06 10816.46 10816.46 -3288.87 HS 0.00 6.85 85.93 57293.53 6064478.09 508417.66 N 7035 14.58 W 149 55 51.09 13427.61 89.17 307.49 4038.86 4092.46 10833.26 10833.26 -3310.77 178.611- 0.00 6.85 85.93 57293.54 6064494.86 508395.73 N 7035 14.75 W 149 55 51.74 NE21-7 Tgt 02 13436.08 89.00 307.49 4039.00 4092.60 10838.42 10838.42 -3317.49 87.38R 2.00 6.85 85.76 57281.41 6064500.00 508389.00 N 7035 14.80 W 149 55 51.93 13500.00 89.06 308.77 4040.08 4093.68 10877.87 10877.87 -3367.76 87.36R 2.00 6.86 85.63 57271.77 6064539.37 508338.67 N 7035 15.19 W 149 55 53.42 13600.00 89.15 310.77 4041.65 4095.25 10941.83 10941.83 -3444.62 87.33R 2.00 6.87 85.44 57256.46 6064603.20 508261.73 N 7035 15.82 W 149 55 55.69 13700.00 89.24 312.76 4043.04 4096.64 11008.43 11008.43 -3519.19 87.3R 2.00 6.88 85.25 57240.94 6064669.67 508187.05 N 7035 16.47 W 149 55 57.90 13796.79 89.34 314.70 4044.24 4097.84 11075.33 11075.33 -3589.13 HS 2.00 6.89 85.07 57225.79 6064736,46 508117.02 N 7035 17.13 W 149 55 59.97 13800.00 89.34 314.70 4044.28 4097.88 11077.58 11077.58 -3591.41 HS 0.00 6.90 85.07 57225.79 6064738.71 508114.73 N 7035 17.15 W 149 56 0.04 13900.00 89.34 314.70 4045.44 4099.04 11147.91 11147.91 -3662.49 HS 0.00 6.90 85.07 57225.80 6064808.92 508043.55 N 7035 17.84 W 149 56 2.14 13948.32 89.34 314.70 4046.00 4099.60 11181.90 11181.90 -3696.83 39.45R 0.00 6.90 85.07 57225.80 6064842.84 508009.16 N 7035 18.18 W 149 56 3.16 NE21-1 Tgt 03 13948.54 89.34 314.70 4046.00 4099.60 11182.05 11182.05 -3696.99 67.62L 2.00 6.91 85.07 57226.06 6064843.00 508009.00 N 7035 18.18 W 149 56 3.16 14000.00 89.73 313.75 4046.42 4100.02 11217.94 11217.94 -3733.86 67.611 2.00 6.91 85.59 57268.54 6064878.83 507972.07 N 70 35 18.53 W 149 56 4.25 141 00. 00 90.49 311.90 4046.22 4099.82 11285.91 11285.91 -3807.20 67.611 2.00 6.92 86.60 57337.74 6064946.68 507898.63 N 70 35 19.20 W 149 56 6.42 14200.00 91.26 310.05 4044.69 4098.29 11351.48 11351.48 -3882.69 67.64L 2.00 6.93 87.62 57389.10 6065012.11 507823.05 N 70 35 19.84 W 149 56 8.65 14230.29 91.49 309.49 4043.97 4097.57 11370.85 11370.85 -3905.97 HS 2.00 6.94 87.93 57401.10 6065031.44 507799.74 N 70 35 20.03 W 14956 9.34 14300.00 91.49 309.49 4042.16 4095.76 11415.16 11415.16 -3959.75 HS 0.00 6.94 87.93 57401.08 6065075.67 507745.90 N 70 35 20.47 W 149 56 10.93 14400.00 91.49 309.49 4039.57 4093.17 11478.73 11478.73 4036.90 HS 0.00 6.95 87.93 57401.05 6065139.11 507668.66 N 70 35 21.09 W 149 56 13.22 14410.73 91.49 309.49 4039.29 4092.89 11485.55 11485.55 -0045.17 90.88R 0.00 6.95 87.93 57401.05 6065145.92 507660.37 N 70 35 21.16 W 149 56 13.46 NE2L1 Tgt 04 14460.77 91.47 310.49 4038.00 4091.60 11517.70 11517.70 4083.50 93.87R 2.00 6.95 87.77 57395.05 6065178.00 507622.00 N 70 35 21.48 W 149 56 14.59 14500.00 91.39 311.66 4037.02 4090.62 11543.47 11543.47 4113.06 93.911 3.00 6.96 87.52 57384.92 6065203.72 507592.40 N 70 35 21.73 W 14956 14600.00 91.18 314.66 4034.77 4088.37 11611.85 11611.85 -4185.98 93.97R 3.00 6.97 86.90 57354.56 6065271.98 507519.38 N 70 35 22.40 W 14956 14700.00 90.98 317.65 4032.89 4086.49 11683.95 11683.95 4255.23 94.02R 3.00 6.98 86.29 57317.97 6065343.96 507450.02 N 70 35 23.11 W 14956 14795.25 90.77 320.50 4031.43 4085.03 11755.90 11755.90 -0317.61 HS 3.00 7.00 85.71 57277.69 6065415.81 507387.54 N 70 35 23.82 W 149 56 21.52 14800.00 90.77 320.50 4031.37 4084.97 11759.57 11759.57 -4320.63 HS 0.00 7.00 85.71 57277.69 6065419.47 507384.51 N 70 35 23.85 W 149 56 21.61 14900.00 90.77 320.50 4030.02 4083.62 11836.73 11836.73 -4384.23 HS 0.00 7.00 85.71 57277.68 6065496.52 507320.79 N 70 35 24.61 W 149 56 23.49 14925.66 90.77 320.50 4029.67 4083.27 11856.53 11856.53 4400.55 90.22R 0.00 7.00 85.71 57277.68 6065516.29 507304.45 N 70 35 24.81 W 149 56 23.98 NE2Li Tgt 05 14975.54 90.77 321.50 4029.00 4082.60 11895.29 11895.29 -4431.93 76.18L 2.00 7.01 85.58 57267.57 6065555.00 507273.00 N 70 35 25.19 W 149 56 24.90 15000.00 90.89 321.02 4028.65 4082.25 11914.37 11914.37 -4447.24 76.191. 2.00 7.01 85.76 57280.97 6065574.05 507257.67 N 70 35 25.38 W 149 56 25.36 15100.00 91.36 319.08 4026.68 4080.28 11991.01 11991.01 -4511.43 76.23L 2.00 7.02 86.48 57330.22 6065650.59 507193.36 N 70 35 26.13 W 149 56 27.26 15200.00 91.84 317.14 4023.89 4077.49 12065.42 12065.42 4578.17 76.28L 2.00 7.03 87.21 57370.45 6065724.88 507126.51 N 70 35 26.86 W 149 56 29.23 15274.72 92.19 315.69 4021.26 4074.86 12119.51 12119.51 -4629.65 HS 2.00 7.04 87.76 57394.49 6065778.88 507074.95 N 70 35 27.39 W 149 56 30.76 15300.00 92.19 315.69 4020.29 4073.89 12137.58 12137.58 4647.30 HS 0.00 7.04 87.76 57394.49 6065796.93 507057.27 N 70 35 27.57 W 149 56 31.28 15400.00 92.19 315.69 4016.47 4070.07 12209.08 12209.08 4717.11 HS 0.00 7.05 87.76 57394.45 6065868.31 506987.36 N 70 35 28.27 W 149 56 33.34 15490.39 92.19 315.69 4013.01 4066.61 12273.71 12273.71 4780.21 121.62R 0.00 7.05 87.76 57394.43 6065932.83 506924.17 N 70 35 28.91 W 149 56 35.21 NE2L1 Tgt 06 15490.62 92.19 315.69 4013.00 4066.60 12273.88 12273.88 4780.37 122.39R 2.00 7.05 87.76 57394.31 6065933.00 506924.00 N 70 35 28.91 W 149 56 35.22 15500.00 92.09 315.85 4012.65 4066.25 12280.59 12280.59 -4786.91 122.39R 2.00 7.05 87.64 57389.42 6065939.70 506917.45 N 70 35 28.97 W 149 56 35.41 15600.00 91.02 317.54 4009.94 4063.54 12353.33 12353.33 -4855.47 122.44R 2.00 7.06 86.34 57321.46 6066012.32 506848.78 N 70 35 29.69 W 149 56 37.44 15603.07 90.98 317.59 4009.89 4063.49 12355.60 12355.60 4857.54 HS 2.00 7.06 86.31 57318.91 6066014.59 506846.71 N 70 35 29.71 W 149 56 37.50 15700.00 90.98 317.59 4008.22 4061.82 12427.15 12427.15 -4922.90 HS 0.00 7.07 86.31 57318.90 6066086.03 506781.24 N 70 35 30.42 W 149 56 39.43 15800.00 90.98 317.59 4006.50 4060.10 12500.97 12500.97 4990.34 HS 0.00 7.08 86.31 57318.89 6066159.74 506713.70 N 70 35 31.14 W 149 56 41.43 15900.00 90.98 317.59 4004.78 4058.38 12574.80 12574.80 -5057.77 HS 0.00 7.08 86.31 57318.87 6066233.45 506646.15 N 70 35 31.87 W 149 56 43.43 16000.00 90.98 317.59 4003.07 4056.67 12648.62 12648.62 -5125.21 HS 0.00 7.09 86.31 57318.86 6066307.15 506578.61 N 70 35 32.59 W 149 56 45.42 16003.64 90.98 317.59 4003.00 4056.60 12651.31 12651.31 -5127.66 169.85R 0.00 7.09 86.31 57318.86 6066309.84 506576.15 N 70 35 32.62 W 149 56 45.49 NE2L1 Tgt 07 16003.86 90.98 317.59 4003.00 4056.60 12651.47 12651.47 -5127.81 10.72L 2,00 7.09 86.30 57318.58 6066310.00 506576.00 N 703532.62 W1495645.50 16065.27 92.19 317.36 4001.30 4054.90 12696.71 12696.71 -5169.30 HS 2.00 7.09 87.53 57384.75 6066355.17 506534.44 N 70 35 33.06 W 149 56 46.73 16100.00 92.19 317.36 3999.98 4053.58 12722.24 12722.24 -5192.81 HS 0.00 7.09 87.53 57384.74 6066380.66 506510.90 N 70 35 33.32 W 149 56 47.42 16200.00 92.19 317.36 3996.16 4049.76 12795.75 12795.75 -5260.50 HS 0.00 7.10 87.53 57384.71 6066454.06 506443.10 N 70 35 34.04 W 149 56 49.43 16300.00 92.19 317.36 3992.35 4045.95 12869.26 12869.26 -5328.18 HS 0.00 7.11 87.53 57384.68 6066527.45 506375.30 N 70 35 34.76 W 149 56 51.43 Nikaitchuq\Spy Island\SP03-NE2\SP03-NE2 L1\SP03-NE2L1 (P7) Drilling Office 2.10.544.0 Schlumberger -Private 9/5/2019 4:21 PM Page 1 of 3 Nikaitchuq\Spy Island\SP03-NE2\SP03-NE2 L1\SP03-NE2L1 (P7) Drilling Office 2.10.544.0 Schlumberger -Private 9/5/2019 4:21 PM Page 2 of 3 MD Incl Azim True NDSS ND VSEC NS EW TF DLS Directional Exclusion Exclusion Zone GeoMag Th Northing Eastlng Latitude Longitude Comments (ft) (') (°) (ft) (ft) (ft) (ft) (ft) (') (•/t00ff) DifficultyIndex Zone Alert Angle t'1 (nT) (ftUS) (ftUS) (NIS ° "') (ENV • "') 16400.00 92.19 317.36 3988.53 4042.13 12942.77 12942.77 -5395.87 HS 0.00 7.11 87.53 57384.65 6066600.85 506307.50 N 70 35 35.48 W 149 56 53.43 16500.00 92.19 317.36 3984.72 4038.32 13016.28 13016.28 -5463.56 HS 0.00 7.12 87.53 57384.62 6066674.24 506239.71 N 70 35 36.21 W 149 56 55.44 16518.57 92.19317.36 3984.01 4037.61 13029.93 13029.93 -5476.13 22.53L 0.00 7.12 87.53 57384.62 6066687.87 506227.12 N 70 35 36.34 W 149 56 55.81 NE2L1 Tgt 08 16518.74 92.19 317.36 3984.00 4037.60 13030.06 13030.06 -5476.25 177.27L 2.00 7.12 87.53 57384.76 6066688.00 506227.00 N 70 35 36.34 W 149 56 55.81 16600.00 90.57 317.28 3982.05 4035.65 13089.78 13089.78 -5531.31 177.27L 2.00 7.13 85.93 57293.41 6066747.62 506171.85 N 70 35 36.93 W 149 56 57.44 16690.72 88.75 317.20 3982.58 4036.18 13156.38 13156.38 -5592.90 HS 2.00 7.13 84.15 57138.80 6066814.12 506110.16 N 70 35 37.58 W 149 56 59.26 16700.00 88.75 31720 3982.78 4036.38 13163.19 13163.19 -5599.21 HIS 0.00 7.14 84.15 57138.81 6066820.92 506103.84 N 70 35 37.65 W 149 56 59.45 16800.00 88.75 317.20 3984.96 4038.56 13236.54 13236.54 -5667.14 HS 0.00 7.14 84.15 57138.83 6066894.15 506035.80 N 70 35 38.37 W 149 57 1.46 16900.00 88.75 317.20 3987.13 4040.73 13309.89 13309.89 -5735.07 HS 0.00 7.15 84.15 57138.85 6066967.39 505967.76 N 70 35 39.09 W 14957 3.47 17000.00 88.75 317.20 3989.31 4042.91 13383.24 13383.24 -5803.00 HIS 0.00 7.15 84.15 57138.87 6067040.63 505899.72 N 70 35 39.81 W 14957 5.48 17031.62 88.75 317.20 3989.99 4043.59 13406.43 13406.43 -5824.48 137.47R 0.00 7.15 84.15 57138.87 6067063.78 505878.20 N 70 35 40.04 W 149 57 6.12 NE2L7 Tgt 09 17031.92 88,75 317.20 3990.00 4043.60 13406.65 13406.65 -5824.69 52.09L 2.00 7.15 84.14 57138.37 6067064.00 505878.00 N 70 35 40.04 W 149 57 6.13 17100.00 89.59 316.13 3990.99 4044.59 13456.16 13456.16 -5871.41 52.07L 2.00 7.16 85.12 57229.82 6067113.43 505831.21 N 70 35 40.53 W 149 57 7.51 17200.00 90.82 314.55 3990.64 4044.24 13527.28 13527.28 -5941.70 52.08L 2.00 7.17 86.55 57334.22 6067184.44 505760.81 N 70 35 41.23 W 149 57 9.59 17300.00 92.04 312.97 3988.14 4041.74 13596.42 13596.42 -6013.89 52.12L 2.00 7.18 87.99 57402.74 6067253.45 505688.51 N 70 35 41.91 W 149 57 11.73 17374.29 92.96 311.80 3984.90 4038.50 13646.45 13646.45 -6068.71 HS 2.00 7.18 89.06 57430.31 6067303.39 505633.62 N 70 35 42.40 W 149 57 13.35 17400.00 92.96 311.80 3983.57 4037.17 13663.56 13663.56 -6087.86 HS 0.00 7.19 89.06 57430.29 6067320.47 505614.45 N 70 35 42.57 W 149 57 13.92 17500.00 92.96 311.80 3978.41 4032.01 13730.12 13730.12 -6162.31 HS 0.00 7.19 89.06 57430.25 6067386.90 505539.90 N 70 35 43.22 W 149 57 16.12 17546.52 92.96 311.80 3976.02 4029.62 13761.08 13761.08 -6196.95 54.311 0.00 7.19 89.06 57430.23 6067417.81 505505.22 N 70 35 43.52 W 149 57 17.14 NE2L1 Tgt 10 17546.81 92.96 311.80 3976.00 4029.60 13761.27 13761.27 -6197.16 151.35R 2.00 7.19 89.06 57430.27 6067418.00 505505.00 N 70 35 43.53 W 149 57 17.15 17600.00 92.03 312.31 3973.69 4027.29 13796.87 13796.87 -6236.62 151.38R 2.00 7.20 88.06 57405.18 6067453.53 505465.49 N 703543.88 W1495718.32 17700.00 90.27 313.27 3971.68 4025.28 1 3864. 78 13864.78 -6309.99 151.4R 2.00 7.21 86.19 57311.06 6067521.32 505392.02 N 703544.54 W1495720.49 17748.73 89.41 313.73 3971.82 4025.42 13898.32 13898.32 -6345.33 HS 2.00 7.21 85.28 57243.03 6067554.80 505356.63 N 70 35 44.87 W 149 57 21.54 17800.00 89.41 313.73 3972.34 4025.94 13933.77 13933.77 -6382.38 HS 0.00 7.21 85.28 57243.04 6067590.18 505319.53 N 70 35 45.22 W 149 57 22.63 17900.00 89.41 313.73 3973.36 4026.96 14002.90 14002.90 -6454.63 HS 0.00 7.22 85.28 57243.04 6067659.19 505247.18 N 70 35 45.90 W 149 57 24.77 18000.00 89.41 313.73 3974.38 4027.98 14072.03 14072.03 -6526.88 HS 0.00 7.22 85.28 57243.05 6067728.20 505174.83 N 70 35 46.58 W 149 57 26.91 18060.23 89.41 313.73 3975.00 4028.60 14113.66 14113.66 -6570.39 135.64L 0.00 7.23 85.28 57243.06 6067769.76 505131.25 ` N 70 35 46.99 W 149 57 2' - NEW NEW Tgt 11 18060.58 89.41 313.73 3975.00 4028.60 14113.90 14113.90 -6570.64 157.53L 2.00 7.23 85.27 57242.71 6067770.00 505131.00 N 70 35 46.99 W 149 57 18089.84 88.87 313.51 3975.44 4029.04 14134.09 14134.09 -6591.83 HS 2.00 7.23 84.77 57198.84 6067790.15 505109.79 N 703547.19 W 14957. 18100.00 88.87 313.51 3975.64 4029.24 14141.08 14141.08 -6599.20 HS 0.00 7.23 84.77 57198.84 6067797.13 505102.41 N 703547.26 W 149 57 29.05 18200.00 88.87 313.51 3977.61 4031.21 14209.91 14209.91 -6671.71 HS 0.00 7.24 84.77 57198.86 6067865.84 505029.79 N 70 35 47.93 W 149 57 31.20 18300.00 88.87 313.51 3979.59 4033.19 14278.74 14278.74 -6744.23 HS 0.00 7.24 84.77 57198.87 6067934.55 504957.17 N 70 35 48.61 W 149 57 33.35 18400.00 88.87 313.51 3981.56 4035.16 14347.57 14347.57 -6816.74 HS 0.00 7.25 84.77 57198.89 6068003.26 504884.56 N 70 35 49.29 W 149 57 35.49 18500.00 88.87 313.51 3983.53 4037.13 14416.40 14416.40 -6889.26 HS 0.00 7.25 84.77 57198.90 6068071.96 504811.94 N 70 35 49.96 W 149 57 37.64 18574.09 88.87 313.51 3985.00 4038.60 14467.40 14467.40 -6942.99 77.5R 0.00 7.25 84.77 57198.91 6068122.87 504758.14 N 70 35 50.46 W 149 57 39.23 NE2L1 Tgt 12 18574.28 88.87 313.51 3985.00 4038.60 14467.53 14467.53 -6943.12 172.041- 2.00 7.25 84.77 57198.94 6068123.00 504758.00 N 70 35 50.47 W 149 57 39.24 18600.00 88.36 313.44 3985.62 4039.22 14465.22 14485.22 -6961.78 172.04L 2.00 7.26 84.28 57151.63 6068140.66 504739.32 N 70 35 50.64 W 149 57 39.79 18665.85 87.06 313.26 3988.25 4041.85 14530.38 14530.38 -7009.63 HS 2.00 7.26 83.01 57011.15 6068185.74 504691.40 N 70 35 51.08 W 149 57 41.20 18700.00 87.06 313.26 3990.01 4043.61 14553.75 14553.75 -7034.47 HS 0.00 7.26 83.01 57011.16 6068209.07 504666.53 N 70 35 51.31 W 149 57 41.94 18800.00 87.06 313.26 3995.14 4048.74 14622.19 14622.19 -7107.20 HS 0.00 7.27 83.01 57011.20 6068277.38 504593.69 N 70 35 51.99 W 149 57 44.09 18900.00 87.06 313.26 4000.28 4053.88 14690.62 14690.62 -7179.94 HS 0.00 7.27 83.01 57011.24 6068345.70 504520.86 N 70 35 52.66 W 149 57 46.25 19000.00 87.06 313.26 4005.42 4059.02 14759.06 14759.06 -7252.67 HS 0.00 7.28 83.01 57011.28 6068414.01 504448.02 N 70 35 53.33 W 149 57 48.40 19089.00 87.06 313.26 4009.99 4063.59 14819.97 14819.97 -7317.40 46.5311 0.00 7.28 83.01 57011.32 6068474.81 504383.20 N 70 35 53.93 W 149 57 50.32 NE2L1 Tgt 13 19089.28 87.06 313.26 4010.00 4063.60 14820.16 14820.16 -7317.60 1.92R 2.00 7.28 83.01 57011.71 6068475.00 504383.00 N 70 35 53.93 W 149 57 50.32 19100.00 87.27 313.27 4010.53 4064.13 14827.50 14827.50 -7325.40 1.92R 2.00 7.28 83.22 57037.08 6068482.33 504375.19 N 70 35 54.00 W 149 57 50.55 19200.00 89.27 313.33 4013.54 4067.14 14696.04 14896.04 -7398.14 1.92R 2.00 7.29 85.19 57236.32 6068550.75 504302.35 N 70 35 54.68 W 149 57 52.71 19258.72 90.45 313.37 4013.69 4067.29 14936.38 14936.36 -7440.84 HS 2.00 7.30 86.35 57321.80 6068590.99 504259.59 N 70 35 55.07 W 149 57 53.97 19300.00 90.45 313.37 4013.36 4066.96 14964.70 14964.70 -7470.84 HS 0.00 7.30 86.35 57321.80 6068619.29 504229.55 N 70 35 55.35 W 149 57 54.86 19400.00 90.45 313.37 4012.58 4066.18 15033.38 15033.38 -7543.53 HS 0.00 7.30 66.35 57321.79 6068687.84 504156.76 N 70 35 56.02 W 149 57 57.01 19500.00 90.45 313.37 4011.80 4065.40 15102.05 15102.05 -7616.22 HS 0.00 7.31 86.35 57321.78 6068756.39 504083.97 N 70 35 56.70 W 149 57 59.17 19600.00 90.45 313.37 4011.02 4064.62 15170.72 15170.72 -7688.90 HS 0.00 7.31 66.35 57321.77 6068824.94 504011.18 N 70 35 57.37 W 149 58 1.32 19602.76 90.45 313.37 4011.00 4064.60 15172.62 15172.62 -7690.91 50.43L 0.00 7.31 86.35 57321.77 6068826.84 504009.17 N 70 35 57.39 W 149 58 1.38 NE2L1 Tgt 14 19603.00 90.45 313.37 40 11. 00 4064.60 15172.78 15172.78 -7691.08 7.94L 2.00 7.31 86.35 57322.00 6068827.00 504009.00 N 70 35 57.39 W 149 58 1.38 19608.47 90.56 313.35 4010.95 4064.55 15176.54 15176.54 -7695.06 HS 2.00 7.31 86.46 57328.87 6068830.75 504005.02 N 70 35 57.43 W 149 58 1.50 19700.00 90.56 313.35 4010.06 4063.66 15239.37 15239.37 -7761.61 HS 0.00 7.32 86.46 57328.86 6068893.47 503938.38 N 70 35 58.05 W 149 58 3.47 19800.00 90.56 313.35 4009.09 4062.69 15308.02 15308.02 -7834.32 HS 0.00 7.32 86.46 57328.85 6068962.00 503865.57 N 70 35 58.72 W 149 58 5.63 19900.00 90.56 313.35 4008.11 4061.71 15376.67 15376.67 -7907.03 HS 0.00 7.33 86.46 57328.84 6069030.52 503792.76 N 70 35 59.40 W 149 58 7.78 20000.00 90.56 313.35 4007.14 4060.74 15445.32 15445.32 -7979.73 HS 0.00 7.33 86.46 57328.63 6069099.05 503719.95 N 7036 0.07 W 149 58 9.93 20100.00 90.56 313.35 4006.16 4059.76 15513.97 15513.97 -8052.44 HS 0.00 7.34 86.46 57328.82 6069167.58 503647.14 N 7036 0.75 W 149 58 12.08 20116.41 90.56 313.35 4006.00 4059.60 15525.23 15525.23 -8064.38 70.74L 0.00 7.34 66.46 57328.81 6069178.82 503635.19 N 7036 0.86 W 149 58 12.44 NE2L7 Tgt 15 20116.67 90.56 313.35 4006.00 4059.60 15525.41 15525.41 -8064.56 3.48R 2.00 7.34 86.47 57328.96 6069179.00 503635.00 N 7036 0.86 W 149 58 12 - 20200.00 92.22 313.45 4003.98 4057.58 15582.65 15582.65 -8125.09 3.48R 2.00 7.34 88.10 57406.55 6069236.13 503574.39 N 7036 1.42 W 14958 20274.80 93.72 313.54 4000.10 4053.70 15634.06 15634.06 -8179.28 HS 2.00 7.35 89.57 57436.47 6069287.46 503520.13 N 7036 1.93 W 14958 20300.00 93.72 313.54 3998.47 4052.07 15651.39 15651.39 -8197.50 HS 0.00 7.35 89.57 57436.46 6069304.75 503501.88 N 7036 2.10 W 149581-- 20400.00 93.72 313.54 3991.98 4045.58 15720.13 15720.13 -8269.84 HS 0.00 7.36 89.57 57436.40 6069373.37 503429.44 N 7036 2.77 W 149 58 18.52 20500.00 93.72 313.54 3985.50 4039.10 15788.87 15788.87 -8342.17 HS 0.00 7.36 89.57 57436.34 6069442.00 503357.01 N 7036 3.45 W 149 58 20.67 20600.00 93.72 313.54 3979.02 4032.62 15857.62 15857.62 -8414.51 HS 0.00 7.36 89.57 57436.29 6069510.62 503284.57 N 7036 4.12 W 149 58 22.81 20630.49 93.72 313.54 3977.04 4030.64 15878.57 15878.57 -8436.56 9.73L 0.00 7.37 89.57 57436.27 6069531.54 503262.49 N 7036 4.33 W 149 58 23.46 NE2L1 Tgt 16 20631.16 93.73 313.54 3977.00 4030.60 15879.04 15879.04 -8437.04 175.121 2.00 7.37 89.58 57436.37 6069532.00 503262.00 N 7036 4.33 W 149 58 23.48 20700.00 92.36 313.42 3973.34 4026.94 15926.34 15926.34 -8486.92 175.13L 2.00 7.37 88.24 57410.69 6069579.22 503212.05 N 7036 4.80 W 149 58 24.95 20754.88 91.26 313.33 3971.61 4025.21 15964.01 15964.01 -8526.79 HS 2.00 7.38 87.17 57367.66 6069616.82 503172.13 N 7036 5.17 W 149 58 26.13 20800.00 91.26 313.33 3970.61 4024.21 15994.97 15994.97 -8559.61 HS 0.00 7.38 87.17 57367.65 6069647.72 503139.27 N 7036 5.47 W 149 58 27.11 20900.00 91.26 313.33 3968.41 4022.01 16063.57 16063.57 -8632.33 HS 0.00 7.38 87.17 57367.63 6069716.20 503066.44 N 7036 6.14 W 149 58 29.26 21000.00 91.26 313.33 3966.20 4019.80 16132.17 16132.17 -8705.05 HS 0.00 7.39 87.17 57367.61 6069784.68 502993.62 N 7036 6.82 W 149 58 MAI 21100.00 91.26 313.33 3963.99 4017.59 16200.77 16200.77 -8777.78 HS 0.00 7.39 87.17 57367.59 6069853.16 502920.79 N 7036 7.49 W 149 58 33.57 21144.80 91.26 313.33 3963.00 4016.60 16231.51 16231.51 -8810.36 176.0211 0.00 7.39 87.17 57367.58 6069883.85 502868.16 N 7036 7.79 W 149 58 34.53 NE2L7 Tgt 17 21145.03 91.26 313.33 3963.00 4016.60 16231.66 16231.66 -8810.52 143.0411 2.00 7.39 87.16 57367.36 6069884.00 502888.00 N 7036 7.80 W 149 58 34.54 21147.11 91.23 313.36 3962.95 4016.55 16233.09 16233.09 -8812.04 HS 2.00 7.39 87.13 57365.54 6069885.42 502886.49 N 7036 7.81 W 149 58 34.58 21200.00 91.23 313.36 3961.82 4015.42 16269.39 16269.39 -8850.49 HS 0.00 7.40 87.13 57365.53 6069921.66 502847.98 N 7036 8.17 W 149 58 35.72 21300.00 9123 313.36 3959.68 4013.28 16338.03 16338.03 -8923.18 HS 0.00 7.40 87.13 57365.51 6069990.18 502775.19 N 7036 8.84 W 149 58 37.88 21400.00 91.23 313.36 3957.54 4011.14 16406.67 16406.67 -8995.88 HS 0.00 7.40 87.13 57365.49 6070058.69 502702.39 N 7036 9.51 W 149 58 40.03 21500.00 91.23 313.36 3955.40 4009.00 16475.30 16475.30 -9068.57 HS 0.00 7.41 87.13 57365.47 6070127.20 502629.59 N 70 36 10.19 W 149 58 42.18 21600.00 91.23 313.36 3953.26 4006.86 16543.94 16543.94 -9141.27 HS 0.00 7.41 87.13 57365.45 6070195.72 502556.80 N 70 36 10.86 W 149 58 44.34 21658.50 91.23 313.36 3952.01 4005.61 16584.09 16584.09 -9183.79 56.97R 0.00 7.41 87.13 57365.44 6070235.80 502514.22 N 70 36 11.26 W 149 58 45.60 NE2L1 Tgt 18 21658.79 91.23 313.36 3952.00 4005.60 16584.29 16584.29 -9184.00 174.511 2.00 7.41 87.13 57365.57 6070236.00 502514.00 N 703611.26 W1495845.60 21700.00 90.41 313.44 3951.41 4005.01 16612.60 16612.60 -9213.94 174.51 R 2.00 7.42 86.31 57318.29 6070264.26 502484.02 N 70 36 11.54 W 149 58 46.49 21713.89 90.13 313.47 3951.34 4004.94 16622.15 16622.15 -9224.02 HS 2.00 7.42 86.03 57299.69 6070273.79 502473.93 N 70 36 11.63 W 149 58 46.79 21800.00 90.13 313.47 3951.14 4004.74 16681.39 16681.39 -9286.52 HS 0.00 7.42 86.03 57299.69 6070332.93 502411.34 N 70 36 12.21 W 149 58 48.64 21900.00 90.13 313.47 3950.91 4004.51 16750.18 16750.18 -9359.10 HS 0.00 7.43 86.03 57299.68 6070401.60 502338.66 N 70 36 12.89 W 149 58 50.79 22000.00 90.13 313.47 3950:68 4004.28 16818.97 16818.97 -9431.68 HS 0.00 7.43 86.03 57299.68 6070470.27 502265.98 N 70 36 13.56 W 149 58 52.94 Nikaitchuq\Spy Island\SP03-NE2\SP03-NE2 L1\SP03-NE2L1 (P7) Drilling Office 2.10.544.0 Schlumberger -Private 9/5/2019 4:21 PM Page 2 of 3 MD Incl Azim True NDSS ND VSEC NS EW TF DLExclusion Zone S Directional Exclusion GeoMag Th Northing Easting Latitude Longitude Comments (ft) (°) (°) (ft) (ft) (ft) (ft) (fry (°) (°It00fq Difficulty Index Zone Alert Angle ('1 (nT) (ftUS) (ftUS) (NIS °' ") (ENV 22056.08 90.13 313.47 3950.55 4004.15 16857.55 16857.55 -9472.38 0.26R 0.00 7.43 86.03 57299.68 6070508.77 502225.22 N 70 36 13.94 W 149 58 54.15 22100.00 91.01 313.47 3950.11 4003.71 16887.76 16887.76 -9504.26 0.26R 2.00 7.44 86.90 57353.44 6070538.93 502193.30 N 70 36 14.24 W 149 58 55.09 TD 22105.92 91.13 313.47 3950.00 4003.60 16891.84 16891.84 -9508.55 2.00 7.44 87.01 57359.68 6070543.00 502189.00 N 70 36 14.28 W 149 58 55.22 Survey Type: Def Plan Survey Error Model: Survey Program: Description ISCWSA Rev 0 "' Part 3-D 95.000% Confidence 2.7955 sigma MD From MD To (ft) (ft) EOU Freq (ft) Hole Size (in) Casing Expected Max Diameter Inclination (in) (deal Survey Tool Type Borehole/Survey 1 0.000 40.500 Act Sins 16.000 13.375 SLB_GWD70-Depth Only SP03-NE2 PBI / SP03-NE2 PBI 1 40.500 1238.780 Act Stns 16.000 13.375 SLB GWD70 SP03-NE2 PBI / SP03-NE2 PBI 1 1238.780 2509.950 Act Stns 16.000 13.375 SLB MWD+GMAG SP03-NE2 PBI / SP03-NE2 PSI 1 2509.950 2851.400 Act Stns 16.000 13.375 SLB_MWD+GMAG SP03-NE2 PH1 / SP03-NE2 PHI 1 2851.400 12563.000 Act Stns 30.000 30.000 SLB_MWD+GMAG SP03-NE2 / SP03-NE2 1 12563.000 12713.000 11100.000 12.250 9.625 SLB_MWD+GMAG SP03-NE2 L1 / SP03-NE21-7 (P7) 1 12713.000 13000.000 1/100.000 8.750 5.500 SLB_MWD-INC_ONLY_FILLER SP03-NE2 L1 / SP03-NE21-7 (P7) 1 13000.000 14000.000 1/100.000 8.750 5.500 SLB_MWD+SAG SP03-NE2 L1 / SP03-NE2L7 (P7) 2 13000.000 22105.921 1/100.000 8.750 5.500 SLB_MWD+GMAG SP03-NE2 L1 / SP03-NE21-7 (P7) Legal Description: Surface: 4486.0 FSL 1186.3 FEL S19 T14N R9E UM Id / BHL: 252 FSL 342 FEL 35 T1 5N RBEUM Northing (YI Easting E 6053667.950 511723,300 6070543.000 502189.000 Nikaitchuq\Spy Island\SP03-NE2\SP03-NE2 L1\SP03-NE2L1 (P7) Drilling Office 2.10.544.0 Schlumberger -Private 9/5/2019 4:21 PM Page 3 of 3 ScIYlnllepger Eni Petroleum I Borehole: ell: Field: Structure: SP03-NE2 L1 (P7) SP03-NE2 Nikaitchuq Spy Island (Gravity & Magnetic Parameters (Surface Location NAD27 Alaska State Plane, Zone 04, US Feet Miscellaneous M Model: BGG2018 Dip: 80.968° Dale: 31 -Dec -2019 Lat N 7033 28.22 Northing: 6053667.95ftUS Grid Com: 0.0907" Slot: SP03 TVD Ref: Rotary Table(53.6ft above MSL) Mag Dec: 16.268° FS: 57403.989nT Gravity FS: 100M16n,gn (9.80665 Based) Lon: W 149 54 13.85 Easting: 511723.3hUS Scale Fact: 0.99990016 Plan: SP03-NE21-1 (P7) 1000 2000 0 0 0 0 0 3000 C/ 4000 5000 8000 9000 10000 11000 12000 13000 14000 15000 16000 8000 9000 10000 11000 12000 13000 14000 15000 16000 Vertical Section (ft) Azim = 0.00° Scale= 1:1000.00(ft) Origin= ON/ -S, OE/ -W lDa 1 (P7) JE2 (P8) 4006 TVD 312.89 " ax ISchlumberger Eni Petroleum erg i Borehole: Well: Field: Structure: SP03-NE2 L1 SP03-NE2 Nikaitchuq Spy Island 8 Magnetic Parameter Surface Location NA027 Alaska State Plane, Zone 04, US FeatMiscellaneous IG—Ity Model: BGGM 1018 Dip: 80.868' Dau: 31 -Dec -2018 Lar N 70 33 28.22 NoMpq: 00.58867.45221 Grld Con,: 0.0907° Slat SP03 ND Ret Rotary TabM(53.6R above MSL) M.90—M.9016.206° FS: 57403,986.7 Gra,87 FS: 1001.016mgn (9,80665 8a..d) Lon: IN 149 54 13.85 Easeng: 5t1713,31tUS Scale Fact 0.99990018 Plan: SP03-NF2L1 (P7) -10000 -8000 -6000 -4000 -2000 0 18000TD 21659 MD4006TVD ENI ease Line -It 3 1 18000 22035 MD 4006 TVD 91.23 ° incl 313.6 ° az NE2L1 Tgt 14 9049°-1 312.89'sz N=16584 E=-9184 SP03-NE2(P8) 19603 MD 4065 TVD N=18949 E=-9420 9045 -incl 313.37 'a, 22106 MD 4004 T D NE21-7 Tgt 16 N=15173 E=-7691 D 91.13 °incl 313 47' az 20631 MD 4031 TVD N=16892 E=4 09 93.73' ind 31354' az N=15879 E=-8437 NE2L1 Tg112 SP03-NE2L1 (P7) 18574 MD 4039 TVD 16000 88.87 ° ina 31351 ' az 16000 1,1=14468 c=-6943 NE21-1 Tgt 10 17547 MD 4030 TVD NE2L7 Tgt 17 92.96 ° _1 31 t 80' az 21145 MD 4017 TVD N=13701 E=-8197 91 26' ind 313.33' az N=16232 E= -Bali NE21-1 Tgt 13 NE2L1 Tgt 08 NE2L1 Tgt 06 19 9 MD 4064 TVD 16519 MD 4038 TVD 15491 MD 4067 TVD 14000 e7 ° Incl 313 26 ' a: 92.19°ind 317.36'az 9219°ind 31169 NE2L1 T91 15 'az N=14820 E=-7318 N=1 3030 E=5476 N=12274 E=<780 14000 20117 MD 4060 ND 90 56 ° incl 313.6' az Projedion to TD N=15525 E=-8065 13970 MD 4214 TVD NE2L1 Tgt 11 NE2L1 Tgt 04 82.27 ° incl 354 18' az IBD61 MD 4029 TVD 14461 MD 4092 TVD N=12031 E=-1205 89.41 ° incl 313.73' az 91 47 ° incl 310.49' az N=14114 E=-8571 N=11518 E=4063 12000 134 61MDt02, 4093TVDFSP03-NNE2 12000 NE2L 1 Tgt 09 89.00 °incl 307 4917032MD 4044 ND N-10838 E-3317 8875' incl 317.20' az N=13107 E=-5825 9 5B' Casing anne 12977 MD 4083 ND a0 ° inc1317 00N=10541 E=-NE2L1 Tgt 07 16004 MD 4057 TVD 010000 90,96 °incl 317.59' u 10000 o 0 N=t 2651 E=-5128 v N 11 NIF L.1 Tgt 05 11 14976 MD 4083 TVD CO 90.77 `ud 321.50' az N=11895 E=-4432 Baca Whipzlock (n NE21-1 Tgt 03 12579 MD 4079 TVD 13949 MD 4100 TVD 68.88 °incl 314.03' az 8000 89.34' and 314.70' u N-10300 E=-2651 CO N-11182 E=-3897 Z 6000 ENI Lease Line T-14 (ADL388574) 4000 2000 0 -10000 -8000 -6000 -4000 -2000 EW (ft) Scale = 1:2140.00(ft) 0 8000 6000 4000 2000 SP03-NE2 PB1 RTE 0MO0 TVD 0 00 ° ind 0.X1' —."=D E=O 0 Schluderger Eni Petroleum ena Borehole: Well: Field: Structure: SP03-NE2 L1 SP03-NE2 Nikaitchuq Spy Island Gravity E Magnetic Parametersurface Location NAD27 Alaska State Plane, Zone 04, US Feet Miscellaneous 6053687.95RU Madel: BOOM 2018 Dip: 60.968° Data: 31 -Dec -2019 Lat: N 70 33 28.22 Northing: S Grid Con, 0.0907° Slot: SP03 ND Ref: Rotary Table(SJ.eR above MSL) MagDec: 18.268° FS: 57403.989nT Gravity FS: 1002.Ot8mgn (9.8068,5 Lon: W1d95417.85 Eaating: 511723.JRU3 Scala Fact: 0.99980016 Plan: SPo3NE2L1 (P7) EOU Computation Based On 2-D 95% Confidence 2.44775 sigma -8000 -4000 NN02 (P1b) TI 20000 20000 0 6300N True ENI Lease Line T-11 (ADL388571) Grid SI06 NE1 (P3) Mag NN01PB1 SP03-NE20 (P7) SP03-N (P8) True North cl° No Tot Corr (M ->T 16.268°) 5gp0 Mag Dec (16.268°) Grid Conv (0.091°) �o 16000a� 16000 SP05-FN71-1 (2) o Wry � �'P NN01 ST00 BP01 SPOS N7 r z Sill-1`146� Ab SI' y e5� �a� \� If, SP10-FN5° SP03-NE2 PH1 12000 q � SPOS- 7P8 ° 4z200T 12000 q A� � Y q A I A d10D q�S113-Fy\rc(0 e t N4 y � i O�6�° �° -40 e "o \� �° IOD p I1 'Sq AN'! ° N N�T TVD SP16-FN3 \ titQ \ a� aq �10 CL \y�y SI15-N8 (P1) Je oND -8000 -4000 EW (ft) Scale = 1:1600.00(R) Schlumher9er SP03-NE«1 (P7) Anti -Collision Summary Report - QM -,;an ani Analysis Date-24hr Time: September 05, 2019 - 15:40 Analysis Method: 3D Least Distance Client: Eni Petroleum Reference Trajectory: SP03-NE2L1 (P7) (Def Plan) Field: Nikaitchuq Depth Interval: Every 10.00 Measured Depth (ft) Structure: Spy Island Rule Set: D&M Am Collision Standard S002 v5.1/5.2 Slot: SP03 Min Pts: All local minima indicated. Well: SP03-NE2 Version / Patch: 2.10.544.0 Borehole: SP03-NE2 L1 Database l Project: localhost\drilling4est Scan MD Range: 12563 00f - 22105.92ft ISCWSAO 3-D 95.000% Confidence 2.7955 sigma, for subject well. For Traiectory Error Model: offset wells, error model version is specified with each well respectively. Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Restricted within 63116.42 ft Selection filters: Definitive Surveys - Definitive Plans - Definitive surveys exclude definitive plans - All Non -Det Surveys when no Det -Survey is set in a borehole - All Non -Det Plans when no Def -Plan is set in a borehole Offset Trajectory Se aration Allow Sep. Controlling Reference Tralecta Risk Level Alert Status Ct-Cl ft MAS ftEOU K Dev. tt Fact. Rule MD ff TVD ft Alert Minor Ma'or SP03-NE2 (P8) (Def Plan) Fail Major 11797 266.33 -59.91 -148.36 0.66 OSF1.50 12553.00 407799 OSF<5.6 OSF<1.50 OSF<1.00 Enter Mair 65.56 293.2 -130.26 227.68 0.33 OSF7.50 13010.00 408641 MlnPts 21.48 293.37 -174.43 -271.89 0.11 OSF1.50 13280.00 409032 MinPt-O-ADP 19.97 291.6 -174.80 -271.70 0.10 OSF150 13290.00 4090.47 MINPT.O-EOU 11.10 233.86 -145.14 -222.76 0.07 OSFISO 13360.00 4091.48 MinPt-O-SF 9.51 157.16 -95.59 -14765 0.08 OSF1.50 13390.00 4091.92 Min%-CICt 12.23 173.96 -104.07 -161.73 0.1 OSF1.50 13440.00 4092.67 MinPt-O-SF 28.39 259. -145.05 -231.28 0.16 OSF1.50 13570.00 4094.79 MINPT-O.EOU 3486 267.74 -143.% -232.87 0.19 OSF1.50 13630.01) 4095.68 Min R -O -ADP 54.24 288. -138.41 -234.24 028 OSFISO 13990.00 4099.96 MINPT-O-EOU 54.75 289.23 -138.39 -234.47 0.28 OS F 1.50 1460.6 410002 MinPt-O-ADP 55.89 284.56 -134.14 -22867 0.29 OSFISO 14020.00 410008 MinPt-O.ADP 116.64 316.14.94,451.199.501 0.551 OSF1.50 14750.00 408568 MinPts 96.54 310.12 -110.53 -213.58 0.46 OSF150 15180.00 4078.11 MinPt-CtCt 96.54 310.20 -110.58 -21366®0. OSF1.50 15190.00 4077.80 MinPt-O-SF 96.58 310.2811"-110.6 -213.70 0.46 OSF1.50 15200.00 4077.49 MINPT-0-EOU 9&64 310.36 -11059 -213.71 0.46 OSF1.50 15210.00 4077.16 MInPt.O-ADP 10303 329.8 -117.11-226.78 04711O5F1.50 16250.6 4047.85 MinPts 102.75 324. -114.18 -222.15 0.47 OSF1.50 1653001 4037.19 MinPts 102-4 325,68 -115.19 -223.42 0.47 OSF1.50 1667000 4035.81 MinPt-CtCt 102.36 326.18 -115.42 223.8 047 OSF 1,50 16740.00 403725 MinPI-O-SF 102.61 326. -115.56 -224.16 0.47 OSF1,50 16830.00 4039.21 MINPTC-EOU 102.64 326.82 -115.56 22417 047 OSFi SO 16840.00 4039.43 MinPt-O-ADP 10210 328.28 -11708 226.18 046 0S1`150 17040.00 404377 MinPt-O-ADP 97.74 328.18 -121.37 -230.44 0.44 OSF150 17300.00 4041.74 MinPt-Ctct 97.76 328.31 -121.45-230.55 0.44 OSF150 17310.00 4041.37 MinPt-O-SF 97.81 328.41 -121.4,3 -26.6 0.44 OSF1.50 17320.00 4040.91 Mirpts 10686 329.21 -112.93 -222.34 0.481 OSF1.50 17740.00 4025.34 MinPts 100. 355.86 -136.61 -254.90 0.42 OSFlS0 18810.00 4049.26 MinPt-Cict 101.50 361.32 139.71 -259.82 0.4 0 1`1.50 18970.00 4057.47 MinPt-O-SF 101.98 362. -260.62 0.42 OSF1.50 19030.00 4060.56 MINPT-O-EOU 102.27 363 -14008 140.06 -26.73 042 OSF1.50 190,30.00 4062.10 MINPT-O-EOU 103. 36.55 -150.78 -277.30 0.40 OSF1.50 19840.00 4062.30 MinPt-CICt 102.7 390.41 -157.88 -287.69 0.39 OSF150 203600 405207 MinPt-CICt 102.72 390.44 -157.89 -287.71 0.39 OSF1.50 20310.6 4051 42 Minors 105.48 397.81 -16.6 -292.33 0.39 OSF1.50 21060.6 4018.48 MinPt-CtCt 10565 399.71 -161.15 -294.06 039 OS F 1.50 21120.6 4017.15 MinPt-O-SF 101. 437.21 -189.90 .335.31 0.35 OSFISO 22080.6 46399 MinPt-CtCt 102.28 445.32 -194.93 -343.04 0.34 OSF150 22(190.6 43.87 6 MinPt-O-SF 103.63 449.54 -19638 -345.90 034 OSF1.50 221 DOW 46371 MinPts 104.88 450.22 -1%.6 -345.34 0.35 OSF7.50 22105.92 463.6 TO SI06-NEI (P3) (Def Plan) Warning Alen 1138.51 325.471 920,991 813.041 5.2 OSF1.50 1406.6 41602 MinPts 1082.62 326.30 864.55 756.32 4.99 OSF150 14410.6 46291 OSF<5.00 Enter Alen 1050.71 330. 835.8 72,3.18 4.81 OSF150 14730.6 4085.99 MinPts 1056.76 330.56 835.85 726.20 681 OSF150 147406 6 45.84 MInPt-O-SF 1054.17 332.87 831.72 721.30 4. 0BF1.50 15540.6 4064.94 MinP1-O-SF 105361 332.72 631.46 721.10 477 OSF150 15580.6 463.93 MinPt-CtCt 1053.85 332.85 831.41 721.6 4.77 OSF1.50 15600.6 406354 MINPT-O-EOU 1055.76 335.51 831 511 720.201 47 03F1.50 15930.6 4057.87 MinPis 1102.24 347.08 870.32 755.16 4.78 OSF1S0 17640.6 4026.12 MinPt-CtCt 1102.49 347.7 870.1 754.71 477 OSF1.50 17690.6 4025.34 MINPT-O-EOU 1102.71 34807 870.13 754.,35 4.77 OSF1.50 17710.6 4025.25 Min PI.O-ADP 1119.76 366.2 875.07 753.53 4.6 OSF1.50 18770.6 4047.20 MINPT-O-EOU 1126.58 376.5d7-875 D4 76.6 4.6 OSF1.50 19290.6 467.04 MINPT-O-EOU 1157.29 435. 866.33 721.66 3.99 OSF150 21700.00 6 45.01 MINPT-EOU C 1163.14 446. 865.13 716.93 3.92 OSF1.50 22105.92 463.6 MinPis NN02 (P7 b) (Def Plan) Pass 1117.23 248.56 1650.% 1568.67 11.03 OSF1.50 13490.6 463.52 MinPt-O-SF 1811.84 247.83 164608 1564.01 11.0 OSF1.50 13510.6 4093.85 MmPt-O-SF 1710.50 230.95 1556.6 1479.55 11.18 OSF1.50 14010.6 416.02 MinPt-O-ADP 1616.51 188.% 1490.6 1427.56 12.93 OSF1.50 148906 4083.75 MinPt-O-ADP 1613.87 185.83 1489.44 1428.04 13.13 OSF1.. 1560.6 4082.25 MINPTC-EOU 1611.78 179.45 149161 1432.33 1358 OSF1.50 15210.6 4077.16 Min%-Ctct 2516.69 403.19 224735 2113.49 9.39 OSF1.50 20170.6 468.58 MinPt-O-SF 3243.89 501.36 2903.12 2742.53 9.73 OSF150 22105.92 463.6 TO SP03-NE2 Phil (Def Survey) Pass 1612.6 470751 1298.61 1142.051 OSF1.50 125636 4077.99 MinPts 3112.90 49&08 2781.86 2616.82 914J OSF1.50 14770.6 4085.39 MinPt-O.SF 9623.79 406.39 935254 9217.40 3560 OSF1.50 22105.92 463.6 TO NNO7 P81 (Def Survey) Pass 3554.25 251441 3385,421 3301.81 21. OSF150 14010.6 416.02 Min% 2178.71 318.02 1966.16 186069 11332 OSF1.50 22105.92 463.6 MlnPts NNOt ST6 BPOt (Def Survey) Pass 3554.25 252A41 3385.421 3301.8121.2 OSF1.50 14010.6 6.0 412 MinP. 2239.% 319.56 2025.% 1920.6 1056 OSF1.50 21640.6 466.6 MinPt-O-SF 2231.06 316.83 2019.31 1914.24 1061 0111.50 21800.6 464.74 MInPt-O-ADP 2230.73 31643 2019.23 1914.29 1062 OSF1.50 21820.6 464.70 MINPT-O-EOU 2230.56 315.6 2019.49 1914.76 1064 OSF1.50 21850.6 464.63 MInPt-CtCt 2245.83 308.49 2039.63 1937.34 10.97 OSF1.50 22105.92 463.6 TO Nikaitchuq\Spy Island\SP03-NE2\SP03-NE2 L1\SP03-NE2L1 (P7) Drilling Office 2.10.544.0 Page 1 of 1 Attachment 3 Drilling Hazards Summary Drilling Hazards Sum"qLrj 8-3/4" Open Hole / 5-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud 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), um ing out, backreaming Drilling Hazards Summary 7/9/2014 11:58:00 AM Attachment 4 BOP & Diverter Configuration HYDRIL 13-5/8" ANNULAR "GK" 5000 PSI STUD x FLANGE BX -160 HYDRIL MPL SINGLE GATE 13-5/8" 5000 PSI FLANGE x FLANGE BX -160 10" OPERATORS VARIABLE PIPE RAMS HYDRIL MPL SINGLE GATE 13-5/8" 5000 PSI FLANGE x STUD BX -160 14" OPERATORS BLIND/SHEAR RAMS HYDRIL MPL SINGLE GATE 13-5/8" 5000 PSI FLANGE x FLANGE BX -160 10" OPERATORS VARIABLE PIPE RAMS RIG 15 BOP STh�K HYD�R ISL •.• 52.325' 36.250' 30.125' 36,250' 00' SID PLANT NORTH NO?Uf ON, PREVAILING N WINDS I l' I I I I I I I I NO D2N PAD I DBN19 E) D2M2D SOUTH PAD I I i I b b b b I I I I ,___________J____ ____________1________________ L____________, I � I 7 18 BFNCX 1 Y.t I xt I I •,`.�\�-.`�,�\__ CV9MU NEA-mWOE1BYDWAY- \\JJ --- ---- - --�--- --- i --" I Target Tee's Diverter line on top of well house I �F}��[T� DOI- rTOPOF PNIIIABE NEVATpN 100Y�1 i' 'UW_W _ •tU'BPYN INJECTION P, Rb 1fi0A I eri�Nv Y • • • • i�. 111 �1�/�/�1 .,►_•►•� ►�►_�►_•►_•1►__. EBE ` ... --I W, 11, Prevailing Wnd \ xt \1 la 1 I I� I I BOOB ®NOryS12 E, {gy1911.86 IRO1 - ro 6493116.91 I 1N I I AI xo BENCH x1 3:1 SLOPE NORTH PAD D2N19 '�— DNRD SOUTH PAD -PI RECEIVED �in Document Control Ism It 11 01.24.2011 ISSUED FOR PROJECT USE January 24 2011 (.CPASRC EnAryvS—i-, EnyinPxriny I 117 I� 02111 1•' / I ® —t -----T-- 1 END DF SUBSEAra'WoeROAEWAY- FIBER OPTI; GB I xt 1 xt i I TOP BLOPE \ T �e. �.I ��'i 11100'-0•TiP \ _______ TOE OF BLOB \ 105-1' i \ I I I OW _ -m WGEIMUTABAT' ! # --------- IseeNCHI ' R1W-0•I I I NOTES: J st i 30'— T01 I. COORDINATES SHOWN ARE ALASKA STATE I------- --1-- - NO BENCH SLOPE PLANE, OPUS ZONE 4 NAD 87 SIB 2. ELEVATIONS SHOWN ARE LOCAL DATUM BASED LLy� I�But1EB SUB -SEA a IMPERHEABLE LINER,o b = ON AN ASSUMED FINISHED PAD ELEVATION OF RIVERtBLES FIBER PER NANtIO INSTALL 100' = 12.4' BPMSL OP71C CAS-BUILT SURVEY, HA-BU M2t, RDO9. 7. ELEVATIONS LISTED IN THE MODULE TFORM 6O 0 6O 120 228 -t TABLE ARE AT THE TOP OF STRUCTURE ISLAND SITE PLAN UNLESS NOTED OTHERWISE. Scale: 1 Inch = 60 Feet LEGEND DENOTES UNDER2LOUND UDE ELECTRICAL RIMER h FIBER OPTIC CABLES ® DENOTES ELECTRICAL MODULES AND OR PLATFORMS DENOTES MODULE DENOTES FUTURE MODULE ® DENOTES PLATFORM 360 DECREE LANTERN l$1 FOGHORN ® PILE ONLY AREA ONLY ARE ® TYPICAL PIPERAO( ® DENOTES TRUCK TURNING RADIUS d RIG ACCESS ASPIC eni Attachment 6 FIT & LOT Procedure 13. Leak -Off Test Procedure A Leak -Off Test (LOT) should be performed at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. The LOT and the Formation Integrity Test (FIT), also termed the "Limit Test", are tests performed to assess the formation strength pressure, 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, higher mud weights and alternatives during well control operations. Collect regional data on formation strength and stress magnitude for different applications, including optimization of future wells planning, wellbore stability analysis and modelling, reservoir exploitation. Prior to starting 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 (as in case of a FIT). It should be noted that: An 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 FIT is required, the maximum pumping pressure is often expressed in terms of "Equivalent Mud Weight" (EMW), that is: EMW = P + MW 0.052 x TVD Z p p W a ON 0W Z6 J � 0U GO mK 0 I STAP-P-1-M-26537 - rev. 01 page 221 of 401 in Imperial units. Using the SI units, the formula is: EMM= PX10+MW TVD where: EMW = Equivalent Mud Weight, ppg or kg/L P = Pumping Pressure, psi or kg/cm2 TVD = True Vertical Depth, ft or m MW = Actual Mud Weight, ppg or kg/L LOTS 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 perform it some metres (6-15 m) below the casing shoe. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper; the sand will be certainly more permeable than the shale and the test has the function to ascertain the maximum pressure this sand can hold. If the LOT or FIT values of this sand are lower than those of the shale immediately below the casing shoe, 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. 13.1. Test Procedure Prior to performing a formation strength test, a graph recording the pressure versus the cumulative mud volume shall be prepared. In order to properly perform the test, the following procedure should apply: 1) Drill out the float equipment, clean the rat hole and drill 5 m (15 ft) of new hole. 2) Circulate a mud volume equal to the internal string volume plus the new hole plus 50 m internal casing volumes. This mud shall be cleaned and shall have Z 0 W CL Oy 0 W 2 R' �Jy � ¢U 00 mK oa STAP-P-1-M-26537 - rev. 01 page 222 of 401 -- ... .. Z 0 w a ON U' W Z a' J Rh W mu 00 mm oa the same density and filtrate of the mud to be used in the next hole section, as indicated in the Mud Programme. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the DP and to the casing -DP annulus. The unit shall be equipped with high precision, low pressure gauges. The pressure range of the gauges 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 preventer. 8) In both flanged and multistage surface wellheads, open the annulus of the previous casings. With subsea wellheads, pay attention not to exceed the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until the pressure builds up approximately to half of the maximum anticipated surface pressure. 10) Once this pressure is reached, pump uniform volumes of mud and wait for the time required for the pressure to stabilize. The flow rate may range from 1/8 bbl/min (20 L/min) up to a maximum of 1 bbl/min (160 L/min); however, values of 0.25 bbl/min (for 12 1/4" and smaller holes) or 0.50 bbl/min (for 17 1/2" hole) are commonly used. 11) Record the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat the step 9 and step 10 and plot the pressure versus the cumulative mud volume for each increment of pumped volume. 13) Continue this procedure until: - two or three points on the plot are observed 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 STAP-P-1-M-26537 - rev. 01 page 223 of 401 _ _ z 0 a Ce W n ON L7 W 26 J � H W n' U 00 W CC on begins to bend away from the straight line is called the "Leak -Off Point" (ref. to Figure 13.1), or - the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot the pressure versus time, until stabilization (usually it takes 15-20 min). In the early stage (2-3 min), one value every 15-30 s should be collected, while for the remaining part of the test a value of pressure every 30-60 s 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 the leak -off point pressure and the stabilized 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). Lad STAP-P-1-M-26537 - rev. 01 page 224 of 401 Note: The LOT pressure shall not exceed the pressure, which the casing was tested to. Note: When a good zonal isolation behind the casing is imperative, the LOT should be carried out with a retrievable packer to avoid pressurizing the casing, which may cause possible permanent damage to the cement bond by the creation of microannuli in the cement sheath. 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, 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. PM- STAP-P-1-M-26537 - rev. 01 page 225 of 401 einQ LEAK -OFF TEST REPORT Report N° Date: WELL N1Yu1E: WELL CODE: CONTRACTOR: RIG NAME: RIG CODE: Open holed e th m : 825 Mud T e: FWGELS Rig tt e: J.UPs Na le Ctameter(In): t2114 Weight (1<9.4): 1.3 R.K.B. ele�eti on (m): 26 Last Csg, Shoe m): 797 Marsh Mscos seo/00 44 Warer Depth m): 24 C,m,diameter(n: 13'13/8 P.V.c s: 19 Pumps: 12-P•160 Grade: .155 1 .Qbt100 it•): 5 Liners(in): 8.5' Weight obit): 61 Gels bt100 t : 2r3 Flour Fare I): 0.25 Max, Bunt pres sit: 3103 W.L (ec.00 min : 10.5 Liiholo Shale Expected EMW 1.68 Kgtcm /10 m Time Volume Pressure Time min bd) (Psil mint Volume Pressure bbl) Psi Time Volume Pressure min (bbl) (PsiI 1 025 50 9 2 400 18 2 435 050 100 95 2 480 3 0.75 200 10 2 470 4 100 00 10.5 5 125 400 11 2 1 455 6 150 $00 11,5 2 450 7 1715 370 12 2446 3 200 600 13 2 440 3 200 1 550 1 14 2 1 437 8.5 200 1 $DS 1 15 2 435 Nd e: Pumped wah a content tow rate of (bbl): glume pumped (bbl} ',blume remm ed (bbl} (psi) 1000 900 800 P 700 stop pumR r e 600 S 500 S U 400 shut in Cura e r 300 8 m in es e 200 100 0 0 0,25 0,5 0,75 1 1,25 1,5 1,75 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume (bbo A 1 0 Time mins RESULTS: (Press. e„ + Press. ,m. )x10A)epthuj(1.3 x 797 110) + (430 x 0.07A x 101797.1.68 (Kglcmafl 0 m) Note: Company Re reseMati�e Figure 13.1 - Leak -Off Test Report STAP-P-1-M-26537 - rev. 01 page 226 of 401 Attachment Surface REV DATE BY I CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION rC _ C VN' ,Cs VICINITY MAP S,A_� _ 2 V'Ies 711 THIS SURVEY � � X � A. S.P NA083, .i. r IC W�„I. T14NT14N Y__._- Tl 3N TI 3N a UKTOK POINT oAD OLIKTOK -. OO CK , I ,..._ f T Otw UN[ WE DS_ R, V .� �� s YOK PINIAHEA MPU DS 30, I Y _. r • Mine_ Si(e' r� t_ Ds 3M 1 V I i E qI J P u MPU PA i I IDS 13N i { j �� U PAl7 ,� a.....•�° l r i, P�D i G P It _ i- ;I viEsrlsAK +a i� � Y \ r r. ��ii�" YIEST K 2a" l RAD r�IMFD DRAWING NOTES; 1- GRID COORDINATES SHOWN ARE ALAKA STATE PLANE, ZONE 4, NAD83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES, 2, GEODETIC COORDINATES SHOWN ARE NAD83. 3. BASIS OF LOCATION DERIVED FROM GPS STATIC OBS. PROCESSED INTO OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 19, TOWNSHIP 14 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. S. ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. ALL SECTIONS SHOWN AND/OR REFERENCED IN THIS DRAWING ARE 'PROTRACTED SECTIONS'. 7. REFERENCE LOUNSBURY DOCUMENT E-087 FOR COORDINATE VALUES IN NAD27. s!QFA too SURVEYOR'S CERTIFICATE r 49tr `�:� ••••.••..•.•• 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF % �.... " �..—:�+i::Yrs"::..11n.aK:....% THAT '; ALASKA AND THIS PLAT REPRESENTS A SURVEY 1 c FRANCIS J, CORNING ;� 6 ♦ �% DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AV ♦ Ji '•., LS -106©5 r ♦ ��,. ., AS OF OCTOBER 01, 2010 Jr ♦i FFA''•. '+,R4 �SSION4v�+•`• s SPY ISLAND DRILL SITE WELL CONDUCTORS {� AS -BUILT LOCATIONS 2111111 La�i.�` e�` CAD FII.E:EN13543D9 DAT 0/01/2Dt0 DRAWING N0: �ni-3543-d9 PART: 3 REV. O us (CQ� error jfjj10 A.S.P. NAM.% 74, - , ('4 L4 (.4W til C;600c� "I L,4 C;c�ooc� OD 00 ob �o I-CA3 W co DETX� A. SCAL;: o OIETA't. A SPY ISLAND DRILL SITE (SID) SCALI_,' LEGEND 200 Do 200 0 = WELL, CONDUCTOR AS—BUILT THIS SURVEY �?00' gso Spa SPY ISLAND DRILL SITE WELL CONDUCTORS •1wi, wl AS -BUILT LOCATIONS AW. @nn CA.') us operafifflIg DATE: DRAWING NO: PART: REV: 10/01/2010 Eni-3543-d9 1 2 OF 3 0 Protracted Section 19, T. 14 N., R. 9 E., Umiat Meridian Well No, Alaska State Plane, NAD83 GRID NAD83 Geographic Section Line Offset Pad 'Y' 'X' Latitude (N) Longitude (W) F.N.L F.E_L Elev. (US ft.) (US ft.) 1 6053423.20 1651769.82 70°33'27.209" 149"54'24.765" 797 1171 12.4 2 6053421.65 1651761.87 70°33'27.194" 149°54'25.000" 798 1179 12.4 3 6053420.07 1651754.10 70°33'27.179" 149°54'25.229" 800 1186 12.4 4 6053418.56 1651746.17 70"33'27.164" 149°54'25,463" 801 1194 12.4 5 6053417.03 1651738.44 70°3.3'27.149" 149°54'25.692" 803 1202 12.4 6 6053415.54 1651730.54 70°33'27.134" 149°54'25.925" 804 1210 12.4 7 6053412.44 1651714.77 70`33'27.104" 149°54'26.391" 807 1226 12.4 8 6053410.91 1651706.96 70°33'27.089" 149°54'26.622." 809 1 1234 12.4 9 6053409.39 1651699.11 70°33'27.074" 149054'26.853" 810 1241 12.4 10 6053407.94 1651691.31 70°33'27.060" 149°54'27.084" 812 1249 12.4 11 6053406.32 1651683.39 7033'27.044" 149"54'27.318" 813 1257 12.4 12 6053404.80 1651675.51 70"33'27.029" 149°54'27.551" 815 1265 12.4 13 6053400.38 1651652.80 70°33'26.986" 149°54'28.221" 819 1288 12.4 14 6053398.83 1651644.95 70°33'26.971" 149°54'28.453" 821 1296 12.4 15 6053397.31 1651637.12 70°33'26.956" 149"54'28.685" 822 1304 12.4 16 6053395.82 1651629.26 70°33'26.942" 149°54'28.917" 824 1311 12.4 17 6053394.32 1651621.47 70°33'26.927" 149°54'29.147" 825 1 1319 12.4 18 6053392.78 1651613.58 70033'26.912" 149°54'29.380" 827 1327 12.4 19 6053389.63 1651597.90 70°33'26.881" 149°54'29.843" 830 1343 12,4 20 6053388.17 1651590.00 70"33'26.867" 149°54'30.076" 831 1351 12.4 21 6053386.60 1651582.24 70°33'26.852" 149°54'30.306" 833 1358 12.4 22 6053385.19 1651574.35 70'33'26.838" 149°54'30.538" 834 1366 12.4 23 6053383.64 1651566.41 70033'26.823" 149°54'30.773" 836 1374 12.4 24 6053382.12 1651558.61 70033'26.808" 149°54'31.003" 837 1382 12.4 25 6053377.65 1651535.94 70°33'26.764" 149°54'31.673" 842 1405 12.4 26 6053376.14 1651528.13 70°33'26.750" 149"54'31.904" 843 1413 12.4 27 6053374.53 1651520.23 70°33'26.734" 149°54'32.137" 845 1421 12,4 28 6053373.11 1651512.46 70°33'26.720" 149"54'32.366" 846 1428 12.4 29 6053371.56 1651504.49 70°33'26.705" 149°54'32.602" 848 1436 12.4 30 6053370.06 1651496.66 70°33'26.690" 149"54'32.833" 849 1444 12.4 31 6053367.05 1651480.97 70`33'26,661" 14954'33.296" 852 1460 12.4 32 6053365.47 1651473.16 70°33'26.646" 149"54'33.527" 854 1468 12.4 33 6053363.93 1651465.22 70°33'26.631" 149°54'33.762" 855 1476 12.4 34 6053362.44 1651457.37 70033'26.616" 149°54'33.993" 857 1483 12.4 35 6053360.91 1651449.52 70°33'26.601" 149°54'34.225" 858 1491 12.4 36 6053359.33 1651441.62 70°33'26.586" 149°54'34.459" 860 1499 12.4 37 6053356.19 1651425.30 70"33'26.555" 149"54'34.941" 863 1516 1 12.4 38 6053354.74 1651417.32 1 70033'26.541" 149°54'35.177" 864 1524 12.4 Se�ty &asoc SPY ISLAND DRILL SITE s WELL CONDUCTORS AS -BUILT LOCATIONS 2n n CAA : E^1354309 US OpefaHn� DA�iO/Otj2(iip DRAWING N0: En1-3543-d9 PA T: 3 REO Compiled By: CC SPY ISLAND DRILL SITE Lounsbury & Associates Date: 10/01/10 Eni-Nikaitchuq Checked BY: DHS Conductor As-Builts Doc. E-087 Date: 10/03/10 Alaska State Plane NAD83 & NAD27 Rev.0 DocE-087 Conductor Asbuilts NAD27_NAD83.xlsx 1 of 2 11/2/2010 Alaska State Plane, NAD83 GRID NAD83 Geographic Alaska State Plane, NAD27 GRID NAD27 Geographic Section Line Offset Pad Well No. 'Y' X' Latitude (N) Longitude (W) 'Y'I 'X' Latitude N Longitude W F.N.L F.E.L Elev. (US ft.) (US ft.) 1 6,053,423.20 1,651,769.82 70°33'27.209" 149°54'24.765" 6,053,671.08 511,739.02 70'33'28.246" 149°54' 13.383" 797 1171 12.4 2 6,053,421.65 1,651,761.87 70°33'27.194" 149°54'25.000" 6,053,669.53 511,731.06 70'33'28.231" 149°54' 13.618" 798 1179 12. 3 6,053,420.07 1,651,754.10 70°33'27.179" 149°54'25.229" 6,053,667.95 511,723.30 70°33' 28.216" 149°54' 13.847" 800 1186. 12.4 4 6,053,418.56 1,651,746.17 70°33'27.164" 149°54'25.463" 6,053,666.44 511,715.38 70'33'28.201" 149°54' 14.081" 801 1194 12.4 5 6,053,417.03 1,651,738.44 70°33'27.149" 149°54'25.692" 6,053,664.91 511,707.64 70°33' 28.186" 149°54' 14.309" 803 1202 12.4 6 6,053,415.54 1,651,730.54 70°33'27.134" 149°54'25.925" 6,053,664.91 511,699.74 70'33'28.171" 149°54' 14.543" 804 1210 12.4 7 6,053,412.44 1,651,714.77 70°33'27.104" 149°54'26.391" 6,053,660.34 511,683.97 70°33' 28.141" 149°54' 15.009" 807 1226 12.4 8 6,053,410.91 1,651,706.96 70°33'27.089" 149°54'26.622" 6,053,658.80 511,676.16 70°33' 28.126" 149°54' 15.239" 809 1234 12.4 9 6,053,409.39 1,651,699.11 70°33'27.074" 149°54'26.853" 6,053,657.28 511,668.32 70°33' 28.111" 149°54' 15.471" 810 1241 12.4 10 6,053,407.94 1,651,691.31 70°33'27.060" 149°54'27.084" 6,053,655.83 511,660.51 70°33' 28.097" 149°54' 15.702" 812 1249 12.4 11 6,053,406.32 1,651,683.39 70°33'27.044" 149°54'27.318" 6,053,654.21 511,652.60 70°33' 28.082" 149°54' 15.935" 813 1257 12.4 12 6,053,404.80 1,651,675.51 70°33'27.029" 149°54'27.551" 6,053,652.82 511,644.69 70°33' 28.067" 149°54' 16.168" 815 1265 12.4 13 6,053,400.38 1,651,652.80 70°33'26.986" 149°54'28.221" 6,053,648.26 511,622.00 70°33' 28.023" 149°54' 16.839" 819 1288 12.4 14 6,053,398.83 1,651,644.95 70°33'26.971" 149°54'28.453" 6,053,646.72 511,614.15 70'33'28.008" 149°54' 17.071" 821 1296 12.4 15 6,053,397.31 1,651,637.12 70°33'26.956" 149°54'28.685" 6,053,645.20 511,606.32 70'33'27.993" 149°54' 17.302" 822 1304 12.4 16 6,053,395.82 1,651,629.26 70°33'26.942" 149°54'28.917" 6,053,643.71 511,598.46 70°33' 27.979" 149°54' 17.534" 824 1311 12.4 17 6,053,394.32 1,651,621.47 70°33'26.927" 149°54'29.147" 6,053,642.21 511,590.68 70°33' 27.964" 149°54' 17.764" 825 1319 12.4 18 6,053,392.78 1,651,613.58 70°33'26.912" 149°54'29.380" 6,053,640.67 511,582.79 70°33' 27.949" 149°54' 17.997" 827 1327 12.4 19 6,053,389.63 1,651,597.90 70°33'26.881" 149°54'29.843" 6,053,637.52 511,567.11 70'33'27.919" 149°54' 18.460" 830 1343 12.,'-" 20 6,053,388.17 1,651,590.00 70°33'26.867" 149°54'30.076" 6,053,636.06 511,559.21 70°33' 27.904" 149°54' 18.694" 831 1351 12., 21 6,053,386.60 1,651,582.24 70°33'26.852" 149°54'30.306" 6,053,634.49 511,551.44 70'33'27.889" 149°54' 18.923" 833 1358 12.4 22 6,053,385.19 1,651,574.35 70°33'26.838" 149°54'30.538" 6,053,633.08 511,543.56 70'33'27.875" 149°54' 19.156" 834 1366 12.4 23 6,053,383.64 1,651,566.41 70°33'26.823" 149°54'30.773" 6,053,631.53 511,535.62 70°33' 27.860" 149°54' 19.391" 836 1374 12.4 24 6,053,382.12 1,651,558.61 70°33'26.808" 149°54'31.003" 6,053,630.01 511,527.82 70°33' 27.845" 149°54' 19.621" 837 1382 12.4 25 6,053,377.65 1,651,535.94 70°33'26.764" 149°54'31.673" 6,053,625.54 511,505.15 70'33'27.802" 149°54' 20.291" 842 1405 12.4 26 6,053,376.14 1,651,528.13 70°33'26.750" 149`54'31.904" 6,053,624.03 511,497.34 70°33' 27.787" 149°54' 20.521" 843 1413 12.4 27 6,053,374.53 1,651,520.23 70°33'26.734" 149`54'32.137" 6,053,622.43 511,489.44 70°33' 27.771" 149°54' 20.754" 845 1421 12.4 28 6,053,373.11 1,651,512.46 70°33'26.720" 149°54'32.366" 6,053,621.01 511,481.67 70°33' 27.758" 149°54' 20.984" 846 1428 12.4 DocE-087 Conductor Asbuilts NAD27_NAD83.xlsx 1 of 2 11/2/2010 Compiled By: CC SPY ISLAND DRILL SITE Lounsbury & Associates Date: 10/01/10 Eni-Nikaitchuq Checked BY: DHS Conductor As-Builts Doc. E-087 Date:10/03/10 Alaska State Plane NAD83 & NAD27 Rev.0 Well No. Alaska State Plane, NAD83 GRID NAD83 Geographic Alaska State Plane, NAD27 GRID NAD27 Geographic Section Line Offset Pad 'Y' X' Latitude N Longitude W 'Y' 'X' Latitude (N) Longitude W F.N.L F.E.L Elev. 29 6,053,371.56 1,651,504.49 70°33'26.705" 149°54'32.602" 6,053,619.45 511,473.70 70'33'27.742" 149'54'21.219" 848 1436 12.4 30 6,053,370.06 1,651,496.66 70°33'26.690" 149°54'32.833" 6,053,617.96 511,465.87 70°33' 27.728" 149°54' 21.451" 849 1444 12.4__ 31 6,053,367.05 1,651,480.97 70°33'26.661" 149°54'33.296" 6,053,614.95 511,450.17 70°33' 27.698" 149'54'21.914" 852 1460 12. 32 6,053,365.47 1,651,473.16 70°33'26.646" 149°54'33.527" 6,053,613.37 511,442.37 70°33' 27.683" 149°54' 22.145" 854 1468 12.4 33 6,053,363.93 1,651,465.22 70°33'26.631" 149°54'33.762" 6,053,611.83 511,434.43 70°33' 27.668" 149°54' 22.379" 855 1476 12.4 34 6,053,362.44 1,651,457.37 70°33'26.616" 149°54'33.993" 6,053,610.33 511,426.58 70°33' 27.653" 149°54' 22.611" 857 1483 12.4 35 6,053,360.91 1,651,449.52 70°33'26.601" 149°54'34.225" 6,053,608.81 511,418.73 70°33' 27.638" 149°54' 22.843" 858 1491 12.4 36 6,053,359.33 1,651,441.62 70°33'26.586" 149°54'34.459" 6,053,607.23 511,410.83 70°33' 27.623" 149°54' 23.076" 860 1499 12.4 37 6,053,356.19 1,651,425.30 70°33'26.555" 149°54'34.941" 6,053,604.09 511,394.51 70°33' 27.592" 149°54' 23.558" 863 1516 12.4 38 6,053,354.74 1,651,417.32 70°33'26.541" 149°54'35.177" 6,053,602.64 511,386.54 70°33' 27.578" 149°54' 23.794" 864 1524 12.4 DocE-087 Conductor Asbuilts NAD27_NAD83.xlsx 2 of 2 11/2/2010 Attachment 8 1/4 Mile Scan Report Schlumherger E n i Petroleum eno Borehole: Well: Field: Structure: SP03-NE2 L1 SP03-NE2 Nikaitchuq Spy Island Gravity d Magnetic Parameters urlace Location NAD27 Alaska State Plane, Zone 04, US Feet Miscellaneous 6053887.95ftU Model: 8110M 2018 Di,: 80.958° Data: 31-13 -2019 Lal: N 70 33 28.22 Northing: S Grid Conv: 0.0907" Slot. SP03 ND Rel: Rotary Table(53.6ft above MSL) MagDec: 18.255° FS: 57403.9890 GravityFS: 1002.018mgn (9.808115 Lon: W 14954 13.85 Eacting: 511723.3ftUS Scab Fact: 0.99880018 Plan: SP03-NE21-1 (P7) EOU Computation Based On 2-D 95% Confidence 2.44775 sigma -8000 -4000 NN02 (Ptb) T! 20000 20000 �No True ENI Leese Line T-11 (ADL388571) Grid S106 NE1 (P3) Mag NN01PB1 SP03-NE21-1 (P7) SP03-N (P8) True North cF ro Tot Corr (M -T 16.268°) 5gp0 Mag Dec (16.268°) Grid Conv (0.091°) �o 16000 a 16000 SP05-FN71.1 (2) oM1 NN01 ST00 BP01 SP05 N7 op C y z SI11-FN6 °d z jop� SP10-FNS��yo� SP03-NE2 PH1 V ,\ IQ* p SPOS- 7P8 �q ° Vpt azry 12000 12000 C' I S113-FN4 �',c "10 Y1I11 3 ND 4° 1 SP16-FN3 \l S115 -N8 (P1) 30 ONO -8000 -4000 EW (ft) Scale = 1 1600.00(ft) Schlumherger SP03-NEZL1 (P7) Anti -Collision Summary Report - QM Scan en i Analysis Date-24hr Time: September 05, 2019 - 15:40 Analysis Method: 3D Least Distance Client: Eni Petroleum Reference Trajectory: SP03-NE2Ll (P7) (Def Plan) Field: Nikaitchuq Depth Interval: Every 10.00 Measured Depth (ft) Structure: Spy Island Rule Set: D&M AntiCollision Standard 5002 v5.1/5.2 Slot: SP03 Min Pts: All local minima indicated. Well: SP03-NE2 Version / Patch: 2.10.544.0 Borehole: SP03-NE2 L1 Database \Project: localhost\drilling-test Scan MD Range: 12563.00ft - 22105.92ft ISCWSAO 3-D 95.000% Confidence 2.7955 sigma, for subject well. For Tralectory Error Model: offset wells, error model version is specified with each well respectively. Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Restricted within 63116.42 It 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. Controlling Reference TrajectoryRisk Level Alert Status Ct-Ct tt MAS ft EOU fi Dev. tt Faot. Rule MD ft ND tt Alert Minor Ma'or SPO3-NE2 (P8) (Def Plan) Fail Major 117.97 256.33 -5997 148.36 0.50 OSF1.50 1256300 4077.99 OSF<5.00 OSF<1.50 OSF<1.00 Enter Major 65.56 293.2-130.2fi 227.68 0.33 OSF1.50 13010.00 4086.41 MinPts 27 48 293.37 -176A3 -271. 0.11 OSF1 50 13280.00 4090.32 Min PI -O -ADP 79.97 291.6 -17480 271.70 0.10 OSF7.50 13290.00 4090.47 MINPT-O-EOU 11.10 233.86 -145.14 -222,76 0.07 OSF7.50 13360.00 4091.48 MInPt-O-SF 9.51 157.16 -95.59 -147.65 0.08 OSF1.50 13390.00 4091.92 MinPt-CtCt 12.23 173.96 -104.07 .161.73 0.1 0 F15 13440.00 4092.67 MinPI-O-SF 28.39 259.6 -14505 -231.28 0.16 OSFlSO 1357000 403479 MINPT-O-EOU 3486 267.74 -14396 .232.871 0.19 OSF1.50 1363000 4095.68 MinPI-0-ADP 5424 288. -138.41 -234.24 0.28 OSF1.50 13990.00 4099.96 MINPT-O-EOU 54.75 289.23 -1 38.39F 234.47 0.28 OSF1.50 14000.00 4100.02 Min Pt -O -ADP 5589 284.56 -134.74 -22867 0.29 OSF7.50 14020.00 4100.08 MinPt-O-ADP 116.64 316.1 -94.45-799.50 0. OSF7 50 14750.00 4085.68 MInPIs 96.54 310.12 -110.53 -213.58 046 OSF150 1518000 4078.11 MInPt-CtCt 96.54 31020 -11058 -213,66 0.4 OSF1.50 15190.00 4077.80 MinPI-O-SF 96.58 310.28 -11060 -213.70 046 OSFlSO 1520000 4077.49 MINPT-O-EOU 96.64 310.36 -710.59 .213.711 0.46 OSF1.50 15210.00 4077.16 MinPt O.ADP 103.03 329.8 -117.17 -22fi.78 0.4 OSF1.50 16250.00 4047.85 MinPts 102.75 324. -114.18 -222.15 0.47 OSF1.50 16530.00 4037.19 MinPts 70226 325.68 -115.19 -223.42 0.47 OSF7.50 16670.00 4035.81 MinPt-CtCt 102.36 326.18 -115.62 223.8 00 0SF/50 16740.00 4037.25 MInPt-0-SF 102.61 326. -115.56 -224,16 0.47 0SF150 16830.00 4039.21 MINPT-O-EOU 102.64 326.82 -115.56 22417 0.47 OSF7.50 16840.00 4039.43 MinPt-O-ADP 702.70 328.28 -117.09 226.78 0.46 OSF1.50 17040.00 4043.77 MinPt-O-ADP 97,71 328.18 -121.37 -230.44 044 OSF1.50 1730000 404174 MinPt-Ctct 9776 328.31 -121.45 -230.55r 0.44 OSF1.50 1731000 4041.37 MinPI-0-SF 9781 328.41 -12146 -230.60 044 OSF1.50 17320.00 4040.98 MinPts 10686 329.21 -112.93 -M.34J 0SF1.50 17740.00 4025.34 MinPts 100. 355.86 -136.61 -254.90 0.42 OSF1.50 18810.00 4049.26 MinPt-CICt 101.50 361.32 13971 -259.82 0.4 OSF 1.50 18970.00 4057.47 MinPt-0-SF 101.98 362SOr 140.08 -250.62 0.42 0SF7.50 1903000 4500.56 MINPT-0-EOU 702.27 363 00= -260.73 0.42 OSF7.50 19060.00 4062.10 MINPT-O-EOU 703.25 380.55 -150.78 -277.301.40 OSF7.50 19840.00 4062.30 Minpt-ctct 102. 390.41 -157.88 -287.69 0.39 OSF150 20300.00 405207 MinPI-CtCt 102.72 390.44 -157.89 -287.71 0. OSF150 2031000 405142 MinPls 105. 397.81 -160.06 -292.33 0.39 OSF1.50 21060.00 4018.48 MinPt-CtCI 105.65 399.71 .161.15 -294.06 0.3 0SF150 21120.00 4017.15 MinPt-0-SF 101'a 437.21 -18990 -335.31 0.35 OSFlSO 2208000 4003.99 MinPt-CtCI 10228 445.32 -19493 -343.04 0. OSF1.50 22(19000 4003.87 MinPt-O-SF 10363 449.54 -196.38 -345.90 0.34 OSF1.50 2210000 4003.71 MinPls 10488 450.22 -195.50 -345.34 0.35 OSF1.50 2210592 4003.50 TD S106-NE1 (P3) (Def Plan) Warning Alert 1138.51 325AJ 92094 813.041 527 OSF1.50 14000.00 4100.02 MinPts 108262 32&30 86455 756.32 4.99 OSF1.50 14410.00 4092.91 OSF<5.00 Enter Alen 1056.71 330. 8358 726.18 4B7 OSF7.50 14730.00 4085.99 MinPts 1056.76 330.56 835.85 726201 0SF7.50 14740.00 4085.84 MInPt-O-SF 1054.17 332.87 831.72 72t3OF 4. OS F 1.50 15540.00 4064.94 MInPt-O-SF 1053.81 332.72 831.46 721.10 4.77 OSF7.50 15580.00 4503.93 Min%-Ctct 1053.85 332.85 831.41 721.00 4.77 OSF7.50 15600.00 4063.54 MINPTA-EOU 105576 335.4 831.511 720.20 4.7 0 F15 15930.00 4057.87 MinPls 1102.24 347.08 870.32 755.16 4.78 OSF1 SO 1764000 4026,12 MinPt-ctct 1102.49 347.7 870.10 754.71 4.77 OSF1.50 17690.00 4025.34 MINPTA.EOU 1702.71 348.07 870.13 754. 4.77 OSF1.50 17710.00 4025.25 MinPI-O-ADP 1119.76 366.2 875.07 753.53 6.60 OSF1.50 1877000 404720 MINPT-0-EOU 1126.58 376. 87504 750.08 6.50 OSF1.50 1929000 406704 MINPT-O-EOU 1157.29 435.64 866.33 721.66 3.99 0SF150 2170000 400501 MINPT-O-EOU 1163.14 446. 865.13 716.93 3.92 OSF1.50 22105.92 400360 MinPts N NO2 (Pi b) (Def Plan) Pass 181723 248.55 1650.98 7568.67 11. OSF1.50 13490.00 409352 MhPt-0-SF 181754 247.83 7646.08 1564.01 17. 0SF1SO 13510.00 403385 MinPI-0-SF 1710.50 230.95 7556.00 7479.55 17.78 OSFlSO 14000.00 4100.02 MinPt O.ADP 1616.51 188.95 1490.00 7427.56 12.93 OSFISO 1489000 408375 MinPt-0-ADP 1613.87 185.83 1489.44 1428.04 13.13 OSFISO 15000.00 408225 MINPT-O-EOU 1611.78 179.45 1.1.61 7432.33 13.58 OSF1.50 15210.00 4077.16 MinPt-CtCt 2516.69 403.19 2247.35 2113.49 9.39 OSF1.50 20170.00 4058.58 MhPt-0-SF 3243.89 501.36 2903.12 2742.53 9.73 OSF1.50 22105.92 4003.50 TD SPO3�NE2 Pbl1 (Def Survey) Pass 1612.80 470.751 1298.611 1142.05 5.15 081`1.50 12563.00 4077.99 MinPts 3112.90 496.082781.66 2616,82L_9.431 OSF1.50 14770.00 4085.39 MinPt-0-SF 9623.79 406.39 9352.54 9217.40 35.50 OSF1.50 22105.92 4003.50 TO NNO1 PB1(Def Survey) Pass 3554.25 252.44 3385.42 3301.81 27. OSFISO 14000.00 4100.02 MinPts 2178.77 318.02 1966.76 1860.69 10.32 OSF1.50 2210592 4003.50 MinPts NNO1 STOO BP01(Def Survey) Pass 3554.25 252.441 3385.42 3301.81 21. OSF1.50 14000.00 4100.02 MinPts 2239.56 319.56 2025.98 1920.00 10.56 OSF1.50 2164000 4006.00 MinPt-0-SF 2231.06 316.83 2019.31 1914.24 10.61 OSF1.50 2180000 4006.74 MInPt-O-ADP 2230.73 316.43 2019.23 1916.29 10.62 OSF1.50 2182000 400d.70 MINPT-O-EDD 2230.56 315.80 2019.49 1914.76 10.64 OSF1.50 21850.00 4004.63 MinPt-CICt 2245.83 308.49 2039.63 1937.34 10.97 OSF1.50 22105.92 4003.60 TD Nikaitchuq\Spy Island\SP03-NE2\SP03-NE2 L1\SP03-NE2L1 (P7) Drilling Office 2.10.544.0 Page 1 of 1 Schlumhrger Eni Petroleum 0� eni Borehole: Well: Field: Structure: SP03-NE2 L1 (P7) SP03-NE2 Nikaitchuq Spy Island Gravity & Magnetic Parameters Surface Location NAD27 Alaska State Plane, Zone 04, US Feet (Miscellaneous Model: BGGM 2018 Dip: 80.968° Date: 31 -Dec -2019 Let: N 70 33 28.22 Northing: 6653667.9511US Grid Com: 0.0907° Slot: SP03 TVD Ref: Rotary Table(53.6ft above MSL) MagDec: 16.268' FS: 57403.989nT Gravity FS: 1002.016mgn (9.80665 Based) Lon: W 149 54 13.85 Eaeting: 511723.3ftUS Scale Fact: 0.99990016 Plan: SP03-NE2L1 (P7) 1000 2000 II � o` 0 'o 0 0 3000 a1 m U 4= 4000 5000 8000 9000 10000 11000 12000 13000 14000 15000 16000 8000 9000 10000 11000 12000 13000 14000 15000 16000 Vertical Section (ft) Azim = 0.00° Scale = 1:1000.00(ft) Origin = ON/ -S, OE/ -W �—Schlumhepqep Eni Petroleum * enn Borehole: Well: Field: Structure: SP03-NE2 L1 SP03-NE2 Nikaitchuq Spy Island Gravity & Magnetic Parameter. Surface Location NAD27 Ala.ka State Plane, Zone 04, US Feet MI. Uaneou. Model: BGGM 2010 Dip. 80.998° Dale: 31.0..2049 Lot'. N703328.22 Northin: 833067.98ftU Grid C._. 0.0907° 9101 8103 NDRat Rotary Taele(33,eRab—MSL) Ma9Dec: 18.268' FS: 87403.989nT Gravity F9: 1002.016,gn (9.80888 Saudi Lon: W 149 54 13.85 Ease.: 811723.JRU9 Scale Fac[: 0.98990018 Plan: 8Po341E21.1 (17) 4000 1 w 1 1 4000 2000 2000 SP03-NE2 PB1 RTE 0 MO 0 TVD 0 00' inc10 00 ° 0 N=0 E 0 0 -10000 -8000 -6000 -4000 -2000 0 EW (ft) Scale = 1:2140.00(ft) -10000 -8000 -6000 -4000 -2000 0 18000TO 21659 MD 4008 ND ENI ease Line -11 388571 18000 22035 MD 4006 ND 91.23 ° incl 313.36' az 90.49° inc1312.89' u N=16584 E=-9184 NE2L1 Tgt 14 SP03-NE2 (P8) N=16949 E=-9420 19603 MD 4065 TVD 90.45' inc1313.37' az N D NE2L1 Tgt 16 N=15173 E=-7691 22100 MO 4004 D 20631 MD 4031 ND 91.13' incl 313 47 az 9373- in 313.54 ' az N=16892 E=-9 09 N=15879 E=-8437 NE2L1 Tyt 12 SP03-NE2L1 (P7) es7aMD4631TVo 16000 86 87 °incl 313. 51 ' az 16000 N=14468 E=-6943 NE2L1 Tgt 10 17547 MD 4030 TVD NEW Tgt 17 9296' inc131'1.80az 21145 MD 4017 ND N=13781 E=-6197 91.26 ° incl 313.33 '-f N=16232 E=-8811 NEV Tgt 13 NE2L1 Tgt OB NE2L1 Tgt 08 19 9 MD 4064 TVD 16519 MO 4038 TVD 15491 MO 4067 TVD 14000 87. ° 'rd 313.26' az 92.19 ° incl 317.36 '.z 92.19' inc1315.09 ' az 14000 NE2L1 Tgt 15 N=14820 E=-7318 N=13030 E=-5476 N=12274 E=4780 20117 MD 4060 ND 90.56' incl 313.35' az Projertlon to TO N=15525 E=-8065 13970 MD 4214 TVD NE21,1 T9t 11 NE21-1 Tgt 04 82.27 ° Incl 354.18' az 18061 MD 4029 TVD 14461 MD 4092 TVD N=12031 E=-1205 8941 " inc1313. 73'w 91 47°incl 310.49 ' az N=14114 E=-6571 N=11518 E=4083 12000 NEW Tgt 02 SP03-NE2 PHI 12000 NEW Tgt 09 13430 MD 4093 TVD 89.00 °incl 307,49' az 17032 MO 4044 TVD 8875- incl 317.20' az N=10838 E-3317 N=13407 5=-5825 9 5l8' Casing shoo 12977 MD 4083 ND 87.10' Incl 317 00 a N-10541 E=-3033 NE21,1 Tgt 07 16004 MD 4057 ND _ 01000090.98 °Incl 317.59' az 10000 CD N=12651 E=-5128 ZD N II NE.2L.1 T91 05 14976 MD 4083 TVD U 90.77' Incl 321.50' u N=11695 E=-0432 Base Wnpstack (n NE21-1 T9t 03 12579 MD 4079 ND 8000 13949 MO 4100 TVD 88.68' Incl 314,03' az 89.34' Ind 314.70' az N=10300 E=-2651 8000 1n N=11182 E-3897 Z 6000 ENI Lease Line T-14 (ADL388574) 6000 4000 1 w 1 1 4000 2000 2000 SP03-NE2 PB1 RTE 0 MO 0 TVD 0 00' inc10 00 ° 0 N=0 E 0 0 -10000 -8000 -6000 -4000 -2000 0 EW (ft) Scale = 1:2140.00(ft) Davies, Stephen F (CED) From: Chaudhry Amjad <Amjad.Chaudhry@eni.com> Sent: Thursday, September 12, 2019 9:48 AM To: Davies, Stephen F (CED) Subject: RE: Nikaitchuq SP03-NE21_1 (PTD 219-126) - Question Hello Steve, yes I confirm that we are about 550' away from the lease line, thanks Best regards Amjad Chaudhry Sr. Drilling Engineer eni us operating co. inc. 3800 Centerpoint Dr. Suite 300 Anchorage, AK, 99503 W:907-865-3379 D 2: 907-346-0591 M Email: amiad.chaudhry@eni.com us operating Please note that my email address has been updated, it is now amlad.chaudhry@eni.com. Please update the email you have in your records. This document and any files or e-mail messages attached to it contain data or information that is confidential, privileged or otherwise restricted from disclosure. If you are not the intended recipient, be aware that any disclosure, copying, distribution or use of any of the data or information contained herein or in any of the attachments is strictly prohibited. If you have received this document or transmission in error, please immediately notify the sender and destroy, delete or erase this document and all attachments. From: Davies, Stephen F (CED) [mailto:steve.davies@alaska.gov] Sent: Thursday, September 12, 2019 9:35 AM To: Chaudhry Amjad <Amjad.Chaudhry@eni.com> Subject: Nikaitchuq SP03-NE21_1 (PTD 219-126) - Question Amjad, Please confirm that at total depth, Eni's planned SP03-NE21-1 well branch will be located more than 500' away from the US Federal Government's acreage to the northwest. Thank you, Steve Davies AOGCC Remark: AOGCC PTD No. 219-126 - Coordinate Check 12 September 2019 INPUT Geographic, NAD27 OUTPUT State Plane, NAD27 5004 - Alaska.4, U.S. Feet SP03-NE2 Z./ 1/1 Latitude: 70 33 28.21524 NorthingN: 6053667.952 Longitude: 149 54 13.84572 Easting/X: 511723.300 Convergence: 0 05 26.41590 Scale Factor: 0. 999900156 Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD:L�-- V Development _ Service Exploratory Stratigraphic Test _ Non -Conventional F FIELD: r f=' j POOL:�1� Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 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 Pilot Hole name ( PH) and API number (50--- 50-- from from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool NIKAITCHUQ, SCHRADER BLUFF OIL - 561100 Well Name: NIKAITCHUQ SP03-NE2L1 Program DEV Well bore seg PTD#: 2191260 Company Eni US Operating Company Inc. Initial Class/Type DEV/PEND GeoArea 890 Unit 11400 On/Off Shore On Annular Disposal ❑ Administration 1 Permit. fee attaohed- - - - _ - - _ - - - - - _ NA- - - - - e 2 Lease number appropriate- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - Yes - . _ - - -- Surface location in ADL391283, well_ passes thru ADL388583, top prod int in - - 3 Unique well name and number _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Yes - - - - ADL388581,-TD in ADL 388571._ - . _ - 4 Well located in a_definedpool - - - - - - - - - - - - - - - - - - - - - - - - - - Yes NIKAI_TCHUQ, Schrader Bluff_ Oil -_561100, governed_ by CO 639_ - 5 Well located proper distance from_ drilling unit-boundary -- - - - - - - - - - - - - - - - - - Yes CO 639, Rule 3: There shall be norestrictions as to well spacing except that no pay shall . 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - . - - - - be opened_in a well-within_500 feet of an external property line where the owners and- _ - _ - 7 Sufficient acreage available in_cMing unit - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - Yes . - - - - - landowners are not the same on both sides of the -line. As planned, --- 8well-conforms 8 -if-deviated, is wellbore plat-included _ - _ _ . - _ Yes - - - - - - - to spacing requirements. - - - - - - - - - - - - - - - - - - - - - - - - - 9 Operator only affected party - - - - - - - - - - - - - - -Yes -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 10 Operatorhas-appropriate_bondinforce-- ------------------------- - - - - -- Yes ----------------------- ------- --_------. _ 11 Permit_ can be issued without conservation order_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - -- - - - -- - - - - - - - - - - - - - - - - Appr Date12 Permit_Gan be issued without administrative-approval _ - _ _ - - - . - - Yes _ - - 13 Can permit be approved before 15-day wait- - - - - - - - - - - - - - - - - - - - -- - - - - - - - - Yes - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - SFD 9/12/2019 14 Well located within area an_d strata authorized by Injection Order # (put 10# in_comments)_(For_ NA_ 15 All wells within 1/4_mile-area-of review identified (For service well only) - - - - - - - - - - - - - - NA_ - _ - - - - - - - - - - - . _ - - - - - - - - - - - - - 16 Pre-produced injector: duration-of pre production less than 3 months_ (For service well only) NA_ 17 Nonconven. gas conforms to AS31.05.030Q.1_.A),0.2_.A-D) - - - - - - - - - - - - - - - - - - - - - NA_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductor string_ provided - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ - - - - - - - Lateral drilled from mainbore._ _ _ - - - - - - - - - - - - - - - - - - - - - - Engineering 19 Surface casing-protects all-known_ USDWs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ - Window cut in-9 5/8" casing using RAM_ junction_ system._ 20 CMT_ vol_ adequate_ to circulate on conductor_& surf_csg - - - - - - - - NA_ 21 CMT-vol adequatetotie-in long String to surf csg_ - _ - - _ - NA_ - - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT_will cover all known productive horizons- - - - - - - - - - - - - NA_ - 23 Casing designs adequate for C, J, B &- permafrost - _ - - - . _ - - - - Yes _ - 24 Adequatetankage- orreservepitYes -------------------- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - . - . 25 -If-a- re-drill, has_a_ 10-403 for abandonment been approved - . - - NA_ _ . _ - _ - - drilling companion lateral next to mainbore_ OA-sand target-.. 26 Adequate wellbore separation proposed- - _ _ - _ --------- - - - -------- Yes - - - - - - - No issues ..._ parallels mainbore.- - - - - _ 27 If_diverter required, does it meet regulations_ NA_ using_B_OPE_... wellhead in place. Appr Date 28 Drilling fluid_ program schematic-& equip list-adequate -- - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Max fm-pressure = 1800 psi will drill with 8.5- 9.5 ppg mud_ ._ - - GLS 9/16/2019 29 BOPEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - --- -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - 30 BOPE_pr - -rating appropriate; test to_(put prig in comments)_ Yes MASP = 1370_psi_ ,will-test BOPE to 3500 psi 31 Choke mam o complies w - - - - 'S ay es -------- - 32 Work will occur without operation shutdown- - - - - - - - - - - - - _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ Yes - - _ - --------------------- - - - - . _ - - - -- 33 JS presence- of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ - - - - - - - - - - . - - - 34 Mechanical-condition of wells within AQR verified (For_service well only _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ 35 Permit can be issued w/o hydrogen_ sulfide measures - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - H2S not expected. Rig- has sensors and alarms,_ and H2S sequestering materials are onsite._ - Geology 36 Data _— - - - -ted on_ potential overpressure zones Yes - - - _Expected r_eservoirpressu_re is 8.6. 9.3_ppg EMW; will_be drilled using 9.2 to 9.5 ppgmu_d, Appr Date 37 Seismic analysis of shallow gas-zones ----------------------------------- NA_ - - - - - - - - - - - - - - - - SFD 9/16/2019 38 Seabed condition survey (if off_-shore) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 39 Contact name/phone for weekly-progress reports [exploratory only] - - - - - - - - - - - - - - - - NA_ - - - - - - - - - - - - - - - - - - - _ - - - - - - - - - - - - - - - - - - - - - - _ - - _ - _ - - - - Geologic Engineering Public Currently drilling the Mainbore SP03-NE2 . Commissioner: Date: I O� Commissioner: Date Commissioner Date e
