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Home My WebLink About218-0841. 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: Replace Tubing 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 16014'feet None feet true vertical 4025' feet 7850'feet Effective Depth measured 16014'feet 7936', 8013', 8271'feet true vertical 4025'feet 3742', 3757', 3805'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" 4-1/2" 4-1/2" L-80 L-80 L-80 8049' 8302' 8491' 3764' 3810' 3846' Packers and SSSV (type, measured and true vertical depth)7936' 8013' 8271' 3742' 3757' 3805' 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: West Sak 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: Contact Name: Contact Email: Contact Phone: 1899' 1777' Burst Collapse Slotted Liner 5407' 7549' Casing 4086' 4026' 9493' 15994' 1859' 118'Conductor Surface Intermediate 20" 10-3/4" 78' measured TVD 7-5/8" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 218-014 50-029-23610-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025638, ADL0025639 Kuparuk River Field/ West Sak Oil Pool KRU 1H-104 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1746 Gas-Mcf MD 1171 Size 118' 2062 12661259 1185 3351017 348 324-079, 324-245 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 3196 Water-BblOil-Bbl N/A Packer: Baker Premier Packer: Baker ZXP Packer: Baker ZXP Sydeny Long sydney.long@conocophillips.com (907) 265-6312 Slotted Liner: 8445-15994' Slotted Liner: 3837'-4025' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name and Digital Signature with Date: Authorized Title: Senior RWO/CTD Engineer By Grace Christianson at 8:39 am, Jun 11, 2024 Page 1/8 1H-104 Report Printed: 6/7/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/4/2024 00:00 5/4/2024 02:00 2.00 MIRU, MOVE MOB P Raise C-Section and Cellar. Stomp out Motor Module, Casing Shed and Pump Module. Stage and Set up for Rig Move. 0.0 0.0 5/4/2024 02:00 5/4/2024 03:00 1.00 MIRU, MOVE MOB P Stomp Pump Complex away from Sub Base. Skid Rig Floor and Lower Derrick. 0.0 0.0 5/4/2024 03:00 5/4/2024 08:00 5.00 MIRU, MOVE MOB P Continue to stomp away and stage Pump Module and Pit Module. Set up and stage for trucks. Stomp Sub Base out from 2P-215. Simops: Clean Cellar area and Tree around Well 2P-215. 0.0 0.0 5/4/2024 08:00 5/4/2024 12:00 4.00 MIRU, MOVE MOB P Hook up Rig Move Trucks to Pipe Shed, Pit Module, Pump Module, and Casing Shed. Stage Modules. Stomp Sub Base into position and rig-up Jeep. 0.0 0.0 5/4/2024 12:00 5/4/2024 18:00 6.00 MIRU, MOVE MOB P Wait on NES Tire Tech. Continue to prepare for Rig Move. 0.0 0.0 5/4/2024 18:00 5/4/2024 21:30 3.50 MIRU, MOVE MOB P Move Pit Module, Pump Module, and Sub Base from 2P Pad to 2N Pad. 0.0 0.0 5/4/2024 21:30 5/4/2024 22:30 1.00 MIRU, MOVE MOB P Stage and check tires on 2N Pad, wait on NES Mechanic. Trouble with NES rig move Sow. Mechanic determined Sow engine was DBR. 0.0 0.0 5/4/2024 22:30 5/4/2024 23:30 1.00 MIRU, MOVE MOB P Stage and Rig down Sow from Pump Module. Remove Inop Sow from Sub Base. Rig up Sow from Pump Module to Sub Base. 0.0 0.0 5/4/2024 23:30 5/5/2024 00:00 0.50 MIRU, MOVE MOB P Continue Rig Move from 2N to 1H with Sub Base and Pit Module. 0.0 0.0 5/5/2024 00:00 5/5/2024 05:00 5.00 MIRU, MOVE MOB P Move Pit Module and Sub Base from 2L to C Pit Access Road. 0.0 0.0 5/5/2024 05:00 5/5/2024 09:30 4.50 MIRU, MOVE MOB P Lose Tire at C Pit Access Road. Creep forward with Pit Module and move Sub Base to allow for traffic. Change bad tires on Pit Module. 0.0 0.0 5/5/2024 09:30 5/5/2024 11:00 1.50 MIRU, MOVE MOB P Move Pit Module and Sub Base from KOC to 1H Pad. Stage and spot Sub Base and Pits on Well 1H-104. 0.0 0.0 5/5/2024 11:00 5/5/2024 16:00 5.00 MIRU, MOVE MOB P Stage and spot Sub Base and Pits on Well 1H-104. 0.0 0.0 5/5/2024 16:00 5/5/2024 18:00 2.00 MIRU, MOVE MOB P Prep and Stage Motor Module and Pipe Shed for rig move. 0.0 0.0 5/5/2024 18:00 5/5/2024 20:30 2.50 MIRU, MOVE MOB P Move Motor Module and Pipe Shed from 2P to 2N Pad. 0.0 0.0 5/5/2024 20:30 5/5/2024 21:30 1.00 MIRU, MOVE MOB P Stage Modules. Reposition Pump Module. Inspect TIres. NES Changeout. 0.0 0.0 5/5/2024 21:30 5/5/2024 23:30 2.00 MIRU, MOVE MOB P Move Pump Module, Motor Module, and Pipe Shed from 2N to 2M Pad. 0.0 0.0 5/5/2024 23:30 5/6/2024 00:00 0.50 MIRU, MOVE MOB P Stage Modules. Check Tires. Replace Tire on Pump Module. 0.0 0.0 5/6/2024 00:00 5/6/2024 01:30 1.50 MIRU, MOVE MOB P Stage Modules. Check Tires. Replace Tire on Pump Module. 0.0 0.0 5/6/2024 01:30 5/6/2024 03:00 1.50 MIRU, MOVE MOB P Mobilize Pump Module, Motor Module, and Pipe Shed from 2M to CPF2. 0.0 0.0 5/6/2024 03:00 5/6/2024 04:00 1.00 MIRU, MOVE MOB P Stop at CPF2 and inspect tires on Modules. Find Bad Rim on on Motor Complex, change out tire on Motor Module. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 5/13/2024 Page 2/8 1H-104 Report Printed: 6/7/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/6/2024 04:00 5/6/2024 06:00 2.00 MIRU, MOVE MOB P Continue Changing out tire on Motor Module. Wait on fuel for NES equipment and Field Operations Changeout. 0.0 0.0 5/6/2024 06:00 5/6/2024 18:45 12.75 MIRU, MOVE MOB P Finish working on tire for Motor Module and Field Operations Changeout while at CPF2. 2nd Convoy arrives at 1H Pad. Spot Complexes on 1H pad and send rig move trucks back to 2P Pad for 3rd Convoy. Simops: Stomp complexes into position on 1H Pad. 0.0 0.0 5/6/2024 18:45 5/7/2024 00:00 5.25 MIRU, MOVE MOB P 3rd Convoy departs 2P Pad arriving at 2M Pad. Simops: Stomp complexes into position on 1H Pad. 0.0 0.0 5/7/2024 00:00 5/7/2024 02:00 2.00 MIRU, MOVE MOB P 3rd convoy to CPF2. Continue RU on 1H-104. MU interconnects/Plug in power cables. 0.0 0.0 5/7/2024 02:00 5/7/2024 03:30 1.50 MIRU, MOVE MOB P 3rd convoy travelling f/ CPF2 to Y at toolhouse. Contin ue RU on 1H104. Raise derrick and skid rig floor to drilling position. 0.0 0.0 5/7/2024 03:30 5/7/2024 08:30 5.00 MIRU, MOVE MOB P Hook up steam and air lines. Raise cattle chute. Lower C section. Prep to scope derrick. Plug in power cables to sub and derrick. MU pits to sub interconnects. 3rd convoy arrived at 08:30hrs. 0.0 0.0 5/7/2024 08:30 5/7/2024 12:00 3.50 MIRU, MOVE RURD P Spool up drill line/manrider cable. Unpin blocks. Scope up derrick. RU derrick equpment. MU kelly hose. Clear casing shed of rig move items. Spot csg shed. Accept rig at 12:00hrs 5/7/24 0.0 0.0 5/7/2024 12:00 5/7/2024 14:00 2.00 MIRU, WELCTL RURD P MU standpipe/cement line connections. Clr rig floor. Test mud pumps/lines to 3500 PSi. Good test. 0.0 0.0 5/7/2024 14:00 5/7/2024 17:30 3.50 MIRU, WELCTL RURD P RU to bullhead well. Load pipeshed with 4 1/2" tbg. Take on fluid to pits. Change out rams on BOP to 2 7/8" x 5". 0.0 0.0 5/7/2024 17:30 5/7/2024 20:00 2.50 MIRU, WELCTL CIRC P Bullhead 200 BBLs 8.6ppg SW down tbg. Stage up to 6 BPM/435 PSI Mud Pump/252PSI IA. Bullhead 400 BBLS 8.6PPG SW Down IA. Stage up to 6 BPM/510 PSI Mud Pump/110 PSI IA. 0.0 0.0 5/7/2024 20:00 5/7/2024 20:30 0.50 MIRU, WELCTL OWFF P Flow check f/ 20 minutes. Well on vac. Fill w/ 8 BBLS. Loss rate = 24 BPH. Set fill schedule to fill w/ 15 BBLS every 20 minutes. 0.0 0.0 5/7/2024 20:30 5/7/2024 21:00 0.50 MIRU, WELCTL WWSP P Install BPV w/ prong in wellhead. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 5/13/2024 Page 3/8 1H-104 Report Printed: 6/7/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/7/2024 21:00 5/7/2024 21:30 0.50 MIRU, WELCTL PRTS P Perform rolling test on BPV. No visual leaks observed. 7 BPM 150 PSI on IA 675 PSI SPP. 0.0 0.0 5/7/2024 21:30 5/7/2024 22:00 0.50 MIRU, WELCTL PRTS P Test BPV from above to 2500 PSI. Good test. 0.0 0.0 5/7/2024 22:00 5/8/2024 00:00 2.00 MIRU, WHDBOP NUND P Line up to pump acros top of hole to keep hole full and confirm loss rate. Loss rate 150 BPH. ND tree an adapter flange. 0.0 0.0 5/8/2024 00:00 5/8/2024 05:00 5.00 MIRU, WHDBOP NUND P NU risers, BOPE, flow line. Seal Joes box. 0.0 0.0 5/8/2024 05:00 5/8/2024 07:00 2.00 MIRU, WHDBOP RURD P RU test equipment. Flood lines. Change out dart valve. 0.0 0.0 5/8/2024 07:00 5/8/2024 13:00 6.00 MIRU, WHDBOP BOPE P Test BOPE 250 PSI low/2500 PSI high f/ 5 min each w/ 4.5" test joint. Test annular,2 7/8" x 5" VBR UPR,2 7/8" x 5" VBR LPR, choke valves 1-5,choke and kill manual valves,HCRs, 4" FOSV #1 and #2, dart valve, upper and lower IBOP, and blind shear rams. Perfrom koomey drawdown- ACC 2925 PSI,ACC post function= 1750 PSI, Nitrogen 6 bottle average=1950 PSI, 200 PSI inc=14 seconds, Full recharge = 78 seconds, Closing times- Ann=35 sec,UPR=6 seconds, Blind/Shears= 5 seconds, LPRs= 5 seconds, Choke HCR=2 seconds, With 4" test joint test Annular,2 7/8" x 5" VBR UPR, 2 7/8" x 5" VBR LPR, 4" demco kill. Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms. Test witnessed by AOGCC represenative Josh Hunt. 0.0 0.0 5/8/2024 13:00 5/8/2024 13:30 0.50 MIRU, WHDBOP RURD P RD test equipment. 0.0 0.0 5/8/2024 13:30 5/8/2024 16:00 2.50 MIRU, WHDBOP RURD P RU handling equipment to pull 4.5" TBG. 0.0 0.0 5/8/2024 16:00 5/8/2024 17:30 1.50 COMPZN, RPCOMP RURD P Drain stack. Retrieve BPV. 0.0 0.0 5/8/2024 17:30 5/8/2024 18:30 1.00 COMPZN, RPCOMP THGR P MU landing joint. MU to hanger. Pull hanger to rig floor. Initial PU 169k. Decreased to 120k. LD landing joint and hanger. 8,016.0 7,975.0 5/8/2024 18:30 5/9/2024 00:00 5.50 COMPZN, RPCOMP PULL P POOH LD 4.5" TBG f/7975' to 3723'. Fill Pipe 19:00hrs- 170 BBLS. pipe full at 19:30hrs. 20:00hrs- 205 BBLS. pipe full at 20:30hrs. 21:00hrs-110 BBLs. pipe full at 21:20hrs. Pump across top of hole at 3 BPM and monitor. Fluid level staying at well head. 7,975.0 3,723.0 5/9/2024 00:00 5/9/2024 04:00 4.00 COMPZN, RPCOMP PULL P F/3,723' POOH laying down 4.5" H563 tubing and seal assembly, no abnormalties observed, strap all joints, 280 BPH loss rate 3,723.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 5/13/2024 Page 4/8 1H-104 Report Printed: 6/7/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/9/2024 04:00 5/9/2024 05:30 1.50 COMPZN, RPCOMP RURD P Rig down Halliburton spooler and casing running equipment, clean rig floor. Monitoring hole pumping 50 BBls every 30 minutes. 0.0 0.0 5/9/2024 05:30 5/9/2024 07:00 1.50 COMPZN, RPCOMP ELNE P Spot eline and RU Eline. MU caliper toolstring with tractor. Monitoring hole pumping 50 bbls every 30 minutes. 0.0 0.0 5/9/2024 07:00 5/9/2024 12:00 5.00 COMPZN, RPCOMP ELOG P Make caliper run on Eline. Made it to 7300' before using tractor. Log up from 8000'. Monitoring hole pumping 30 bbls every 30 minutes. 0.0 0.0 5/9/2024 12:00 5/9/2024 13:00 1.00 COMPZN, RPCOMP ELNE P RD Eline. Monitoring hole pumping 30 bbls every 30 minutes. 0.0 0.0 5/9/2024 13:00 5/9/2024 13:30 0.50 COMPZN, RPCOMP SVRG P Service Rig. Perform derrick inspection. Monitoring hole pumping 30 bbls every 30 minutes. 0.0 0.0 5/9/2024 13:30 5/9/2024 15:00 1.50 COMPZN, RPCOMP RURD P Load and process 4" DP. Monitoring hole pumping 30 bbls every 30 minutes. 0.0 0.0 5/9/2024 15:00 5/9/2024 15:30 0.50 COMPZN, RPCOMP OTHR P DHD performed a fluid level check. Fluid level at 582'. Monitoring hole pumping 30 bbls every 30 minutes. 0.0 0.0 5/9/2024 15:30 5/9/2024 16:00 0.50 COMPZN, RPCOMP BHAH P MU Baker G plug assembly. Monitoring hole pumping 30 bbls every 30 minutes. 0.0 0.0 5/9/2024 16:00 5/10/2024 00:00 8.00 COMPZN, RPCOMP PULD P RIH w/ G plug assembly singling in with 4" DP. T/6,190' 86K DN Monitoring hole pumping 30 bbls every 30 minutes. 0.0 6,190.0 5/10/2024 00:00 5/10/2024 02:30 2.50 COMPZN, RPCOMP PULD P RIH w/ G plug assembly singling in with 4" DP. F/6,190' T/7,955' 125K UP 93K DN Monitoring hole pumping 30 bbls every 30 minutes. 6,190.0 7,955.0 5/10/2024 02:30 5/10/2024 03:00 0.50 COMPZN, RPCOMP MPSP P Set Glock plug as per Baker Rotate to right 8 turns slck off set plug Set DN 30K, pick up pull 30K over to pack off elements Release off plug, lay down single of 4" DP T/ C.O.E.@@ 7,950' 7,955.0 7,943.0 5/10/2024 03:00 5/10/2024 04:00 1.00 COMPZN, RPCOMP MPSP P Fill hole with 30 BBLS, get diesel back to surface 7,943.0 7,943.0 5/10/2024 04:00 5/10/2024 05:00 1.00 COMPZN, RPCOMP MPSP P R/U, flood lines test 7 5/8" casing to 2500 PSI F/10 Min - good test 7,943.0 7,943.0 5/10/2024 05:00 5/10/2024 09:30 4.50 COMPZN, RPCOMP DISP P Circulate out diesel and crude from well to tiger tank. Pump 335 BBLS total 7,943.0 7,943.0 Rig: DOYON 25 RIG RELEASE DATE 5/13/2024 Page 5/8 1H-104 Report Printed: 6/7/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/10/2024 09:30 5/10/2024 12:30 3.00 COMPZN, RPCOMP TRIP P POOH F/7,943' T/2,095' 77K UP 7,943.0 2,095.0 5/10/2024 12:30 5/10/2024 13:30 1.00 COMPZN, RPCOMP MPSP P M/U Baker EA storm packer, set at 105' C.O.E. Release from plug, stand back 1 stand DP Bit depth @ 2,202' 2,095.0 0.0 5/10/2024 13:30 5/10/2024 14:00 0.50 COMPZN, RPCOMP MPSP P Test plug to 2500 PSI F/10 min - good test 0.0 0.0 5/10/2024 14:00 5/10/2024 16:00 2.00 COMPZN, RPCOMP NUND P Drain stack, N/D BOP and riser 0.0 0.0 5/10/2024 16:00 5/10/2024 23:15 7.25 COMPZN, RPCOMP NUND P N/D Vetco tubing head, N/U Stream flo tubing head Test pack off, TBG head to casing head break to 3500 PSI F/15 min Install 2 1/16" IA valve N/U riser and BOP, install lines and joes box Install Wear ring while tightening up BOP bolts W/R - 13.45" OD, 9.875" ID 0.0 0.0 5/10/2024 23:15 5/11/2024 00:00 0.75 COMPZN, RPCOMP BOPE P Fill stack, rig up Test BOP breaks and casing valves to 2500 PSI F/5 Min 0.0 0.0 5/11/2024 00:00 5/11/2024 00:30 0.50 COMPZN, RPCOMP BOPE P Test BOP breaks to 250/2500 PSI F/5 min each, blow down and rig down lines 0.0 0.0 5/11/2024 00:30 5/11/2024 01:45 1.25 COMPZN, RPCOMP MPSP P M/U retrieving head for storm packer, RIH to 91', make up twin thread over shot to equalizing valve and open, check for trapped pressure Unset packer, pull to rig floor and lay down 0.0 2,091.0 5/11/2024 01:45 5/11/2024 04:15 2.50 COMPZN, RPCOMP TRIP P RIH F/2,091' T/7,934' 121K UP 91K DN 2,091.0 7,934.0 5/11/2024 04:15 5/11/2024 05:00 0.75 COMPZN, RPCOMP MPSP P Slack off set DN 10K open un loader valve on GLock plug, check for pressure, fluid falling Unset plug, let elements relax 7,947.0 7,955.0 5/11/2024 05:00 5/11/2024 07:30 2.50 COMPZN, RPCOMP PULD P POOH F/7,955' T/4,930' L/D 4" DP to pipe shed Fill hole with 26 BBLS every 30 min 7,955.0 4,930.0 5/11/2024 07:30 5/11/2024 08:30 1.00 COMPZN, RPCOMP OTHR P Perform well bore fluid check with DHD, inclusive top of fluid Pump 100 BBLS down backside, recheck fluid level in IA, fluid level at ~450 - 500' MD 4,930.0 4,930.0 5/11/2024 08:30 5/11/2024 14:30 6.00 COMPZN, RPCOMP PULD P POOH F/4,930' T/25' Fill hole with 30 BBLS every 30 min 4,930.0 25.0 5/11/2024 14:30 5/11/2024 15:00 0.50 COMPZN, RPCOMP BHAH P L/D Baker GLock plug 25.0 0.0 5/11/2024 15:00 5/11/2024 16:00 1.00 COMPZN, RPCOMP RURD P Pull wear ring and lay down running tool Clean clear rig floor 0.0 0.0 5/11/2024 16:00 5/11/2024 16:30 0.50 COMPZN, RPCOMP WWWH P Flush stack and lay down stack washing tool 0.0 0.0 5/11/2024 16:30 5/11/2024 18:45 2.25 COMPZN, RPCOMP RURD P Rig up to run 4 1/2" completion Bring up Halliburton spoolers for chemical injection and gauge mandrel lines, hang sheaves in derrick, R/U Doyon casing running equipment Fill hole with 30 BBLS every 30 min 0.0 0.0 5/11/2024 18:45 5/11/2024 19:15 0.50 COMPZN, RPCOMP SFTY P PJSM, run 4 1/2" completion 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 5/13/2024 Page 6/8 1H-104 Report Printed: 6/7/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/11/2024 19:15 5/11/2024 21:45 2.50 COMPZN, RPCOMP PUTB P Run 4 1/2" completion as per detail T/256' Hook up chemical injection line, confirm valve opens and hold pressure Valve open at 2500 PSI, hold 1000 PSI RIH T/313', hook up gauge mandrel line, test to 10K F/10 min, intail readings on gauge mandrel Volts = 38.95, Current = 9.88 MAX, PSI = 15.32, Temp = 50.59° Fill hole with 30 BBLS every 30 min TQ turn 4 1/2" HYD 563 connections to 3800 FT/LBS TQ turn 4 1/2" Vamtop connections to 4440 FT/LBS 0.0 313.0 5/11/2024 21:45 5/12/2024 00:00 2.25 COMPZN, RPCOMP PUTB P Run 4 1/2" completion as per detail F/313' T/1,415' 50K DN Fill hole with 30 BBLS every 30 min TQ turn HYD 563 connections to 3800 FT/LBS TQ turn Vamtop connections to 4440 FT/LBS Test TEC wire every 25 JTS 313.0 1,415.0 5/12/2024 00:00 5/12/2024 09:00 9.00 COMPZN, RPCOMP PUTB P Run 4 1/2" completion as per detail F/1,415' T/8,030' 115K UP 77K DN Fill hole with 30 BBLS every 30 min Spot CI brine while pumping 30 BBLS every 30 min TQ turn HYD 563 connections to 3800 FT/LBS Test TEC wire every 25 JTS 1,415.0 8,030.0 5/12/2024 09:00 5/12/2024 11:30 2.50 COMPZN, RPCOMP HOSO P Slack off F/8,030' T/8,052' Locate out in ZXP, set DN 10K confirm located Drop ball and rod, space out old seals 2' off located inside ZXP, pressure up to 3300 PSI, set packer, see shear at 3200 PSI Bleed off pressure, pick up out of PBR, slack off confirm no go, lay down JTS #189,188,187 for space out, pick up space out pups ( 9.76', 6.76') and JT 187 T/7,990' Spot CI brine while pumping 30 BBLS every 30 min - pump a total of 300 BBLS 8,030.0 7,990.0 5/12/2024 11:30 5/12/2024 13:00 1.50 COMPZN, RPCOMP THGR P Pick up hanger and landing joint Terminate TEC wire and chemical injection line, test fittings to 5000 PSI F/10 min Readings for TEC wire before landing out 1660 PSI, 64.7°, 39.58 Volts, 10.59 Current Fill IA for testing, take 9.6 BBLS to fill 7,990.0 7,990.0 5/12/2024 13:00 5/12/2024 13:30 0.50 COMPZN, RPCOMP THGR P Slack off land hanger in well head F/7,990' T/8052' 115K UP 77K DN Test hanger seals to 5000 PSI F/10 min Spaced out 1.37' from fully located 7,990.0 8,052.0 Rig: DOYON 25 RIG RELEASE DATE 5/13/2024 Page 7/8 1H-104 Report Printed: 6/7/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/12/2024 13:30 5/12/2024 16:00 2.50 COMPZN, RPCOMP PRTS P R/U, purge lines, test TBG to 3000 PSI F/30 min, bleed TBG down to 1500 PSI, Test IA T/2500 PSI F/30 min, bleed off TBG PSI, shear out SOV, circulate confirm flow path 8,052.0 8,052.0 5/12/2024 16:00 5/12/2024 16:30 0.50 COMPZN, RPCOMP OWFF P Flow check 30 min 8,052.0 8,052.0 5/12/2024 16:30 5/12/2024 17:30 1.00 COMPZN, WHDBOP MPSP P Lay down landing joint, set H-BPV, test from below to 1000 PSI F/10 min Bleed off pressure and rig down lines 8,052.0 0.0 5/12/2024 17:30 5/12/2024 18:00 0.50 COMPZN, WHDBOP RURD P Clear rig floor 0.0 0.0 5/12/2024 18:00 5/12/2024 20:30 2.50 COMPZN, WHDBOP NUND P N/D BOP, riser and lines 0.0 0.0 5/12/2024 20:30 5/12/2024 21:45 1.25 COMPZN, WHDBOP NUND P Install test dart in BPV, Install CSBS in hanger neck, Install TBG head adaptor and terminate TEC wire and gauge line 0.0 0.0 5/12/2024 21:45 5/12/2024 23:30 1.75 COMPZN, WHDBOP NUND P N/U 4 1/16" FMC tree and tighten up bolts on tubing head adaptor and tree Sim Ops - B/D steam and secure racking board in derrick, change out saver sub to 4 1/2" IF 0.0 0.0 5/12/2024 23:30 5/13/2024 00:00 0.50 COMPZN, WHDBOP PRTS P Test TBG head adaptor flange break, hanger neck seals and CSBS to 5000 PSI F/10 min Cont change out saver sub, rigging up for F/P 0.0 0.0 5/13/2024 00:00 5/13/2024 01:00 1.00 COMPZN, WHDBOP PRTS P Finish testing TBGhead adaptor and hanger neck seals to 5000 PSI F/10 min, terminate TEC wire and Chem injection lines at well head and secure fittings Final readings on TEC wire after terminating at well head 1718.21 PSI,67.8°, 39.26 Volts, 10.16 Max Amps SimOPS - R/U for pumping freeze protect and change out saver sub 0.0 0.0 5/13/2024 01:00 5/13/2024 03:00 2.00 COMPZN, WHDBOP PRTS P R/U for freeze protect well, spot LRS and hook up lines, fill tree with diesel and fluid pack lines Test tree to 250 PSI F/5 min, 5000 PSI F/10 min - good test 0.0 0.0 5/13/2024 03:00 5/13/2024 03:30 0.50 COMPZN, WHDBOP MPSP P Check IA for pressure, zero pressure on gauge, open to atmosphere, slight flow, line up to tiger tank, flow stopped Pull test dart, check for pressure under BPV, observe fluid come up TBG/tree due to well being out of balance 0.0 0.0 5/13/2024 03:30 5/13/2024 04:00 0.50 COMPZN, WHDBOP RURD P Mobilize lubricator from valve shop to rig Sim Ops - break apart interconnects in pump room and pits 0.0 0.0 5/13/2024 04:00 5/13/2024 05:00 1.00 COMPZN, WHDBOP MPSP P R/U lubricator and pull BPV, observe 20 PSI on TBG R/D lubricator 0.0 0.0 5/13/2024 05:00 5/13/2024 06:00 1.00 COMPZN, WHDBOP FRZP P Pump 92 BBLS diesel down IA take returns up TBG to tiger tank ICP 2 BPM 1300 PSI, FCP 2.6 BPM 2250 PSI SimOps - Scope derrick down, remove bridal lines, secure top drive 0.0 0.0 5/13/2024 06:00 5/13/2024 07:30 1.50 COMPZN, WHDBOP FRZP P Blow down line to tiger tank, R/D LRS, line up U tube diesel from IA to TBG 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 5/13/2024 Page 8/8 1H-104 Report Printed: 6/7/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/13/2024 07:30 5/13/2024 09:00 1.50 DEMOB, MOVE RURD P Secure well, obtain final pressures TBG = 300 PSI, IA = 300 PSI, OA = 20 PSI Lower cattle chute Rig release 09:00 HRS 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 5/13/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG: 1H-104 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Install post rig GLD. Pull B&R, RHC 1H-104 5/16/2024 fergusp Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 40.4 118.5 118.5 94.00 L-80 Welded SURFACE 10 3/4 9.95 40.3 1,899.3 1,777.4 45.50 L-80 Hydril 563 INTERMEDIATE 7 5/8 6.88 37.5 9,493.2 4,086.2 29.70 L-80 Hyd 563 SLOTTED LINER (MAIN WELLBORE) 4 1/2 3.96 8,444.9 15,993.8 4,025.8 12.60 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.4 Set Depth 8,048.8 String Max No 4 1/2 Set Depth 3,763.7 Tubing Description Tubing Completion Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.4 35.4 0.00 Hanger 13.475 Streamflo hanger 4" H BPV, 6.25" acme lift threads StreamF lo DMLX 3.900 2,541.4 2,199.4 60.25 Mandrel - SOV 4.500 4-1/2" x 1" KBMG GLM w/ 2000 psi SOV, W/BEK Latch SLBG 4.5" x 1" KBMG 3.865 5,749.6 3,152.9 73.81 Mandrel GAS LIFT 4.500 4-1/2" x 1" KBMG GLM w/ DV,W/BK Latch SLBG 4.5" x 1" KBMG 3.865 7,309.2 3,592.3 75.96 Mandrel GAS LIFT 4.500 4-1/2" x 1" KBMG GLM w/ DV W/BK Latch SLBG 4.5" x 1" KBMG 3.860 7,742.3 3,696.9 76.20 Gauge / Pump Sensor 4.500 Gauge Mandrel 9CR HES MXM 19367- 04 3.904 7,799.1 3,710.4 76.27 Mandrel INJ 4.500 Chem Injection Mandrel 13CR HES Mandrel 3.907 7,863.8 3,725.6 76.66 Nipple - X 4.500 3.813 X nipple 13Cr VAMTOP HES 3.813" X nipple 3.813 7,921.1 3,738.5 77.49 Locator 4.500 Baker Locater W/9.69' seal assy Locater = 1.67' - 1.37' F/located Baker 192-47 13 CR 3.910 7,924.2 3,739.1 77.56 PBR 6.260 Baker 192-47 PBR - W/9.13' of seal bore Baker 192-47 13 Cr 4.750 8,003.1 3,755.2 78.86 Nipple - X 4.500 3.813 X nipple HES 3.813" X nipple 3.813 8,020.1 3,758.4 79.12 Locator 4.500 Locater - spaced out 2' from fully located in ZXP @ 8,023.91' 3.958 8,021.9 3,758.8 79.14 Wireline Guide 4.500 Seal Assembly - reran from 2022 7ES work over - no seals Baker GBH-22 3.880 Top (ftKB) 8,012.7 Set Depth 8,302.0 String Max No 4 1/2 Set Depth 3,810.4 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP-M ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,012.7 3,757.0 79.00 PACKER 6.540 Baker ZXP Liner Top Packer 5.5" x 7.63", 5-1/2" H563 Baker ZXP LTP PN: H296-45 -0131, Control # 1062955 66-01 4.920 8,032.7 3,760.8 79.31 SBE 6.250 Baker 190-47 Seal Bore Extension, 5-1/2" Baker SBE PN: H02 -43317- A1 SI# 700886 4.750 8,052.3 3,764.4 79.50 CROSSOVER (XO) BUSHING 5.500 Reducing Crossover sub 5½" Hyd 563 X 4-1/2" TXP 3.950 8,100.7 3,773.2 79.44 NIPPLE 5.200 Camco 4-1/2" x 3.750" DB-6 Nipple, TXP-m SN# 4053-1R Camco DB 6 SN# 4053-1R 3.750 8,159.8 3,784.0 79.36 TRIPPLE CONNECT BUSHING 6.610 Baker 4.5" x 7.63"LEM #1 (Above Hook hanger) SN # 106290368-02 Baker LEM Pos 2 PN: H289-18 -0037, Control # : 1062903 68-02 3.700 8,163.0 3,784.6 79.39 TRIPPLE CONNECT BUSHING 6.610 Baker 4.5" x 7.63" LEM #1 (Below Hook Hanger @ 8162.94') Baker LEM Pos 2 PN: H289-18 -0037, Control # : 1062903 68-02 3.688 8,298.7 3,809.8 79.18 SEAL ASSY 4.500 Baker 190-47 GBH-22, 4-1/2", L-80 Straight Non-Locating Seal Assy Baker 190-47 GBH-22 3.870 Top (ftKB) 8,271.4 Set Depth 8,490.5 String Max No 4 1/2 Set Depth 3,845.5 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP-m BTC ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,271.4 3,804.6 79.00 PACKER 6.550 Baker ZXP Liner Top Packer 5.5" x 7.63", 5-1/2" H563 Baker ZXP LTP PN H296 -45- 0131, CN 1064274 53 4.920 HORIZONTAL, 1H-104, 6/7/2024 8:18:19 AM Vertical schematic (actual) SLOTTED LINER (MAIN WELLBORE); 8,444.9-15,993.7 INTERMEDIATE; 37.5-9,493.2 NIPPLE; 8,439.9 NIPPLE; 8,100.7 Wireline Guide; 8,021.9 Nipple - X; 8,003.1 Packer (Tubing); 7,936.3 Nipple - X; 7,863.8 FISH; 7,850.0 Mandrel INJ; 7,799.1 Gauge / Pump Sensor; 7,742.3 Mandrel GAS LIFT; 7,309.2 Mandrel GAS LIFT; 5,749.6 Mandrel - SOV; 2,541.4 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 35.4 KUP PROD KB-Grd (ft) 38.89 RR Date 9/18/2018 Other Elev 1H-104 ... TD Act Btm (ftKB) 16,014.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292361000 Wellbore Status PROD Max Angle & MD Incl (°) 97.52 MD (ftKB) 14,589.00 WELLNAME WELLBORE1H-104 Annotation LAST WO: End Date 5/14/2024 H2S (ppm) DateComment SSSV: NONE Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,291.2 3,808.3 79.12 SBE 6.250 Baker 190-47 Seal Bore Extension, 5-1/2" Baker PN H02- 43317- A1, WO 4509345 733 4.750 8,310.8 3,812.0 79.26 CROSS OVER (XO) BUSHING 5.500 Reducing Crossover sub 5½" Hyd 563 X 4-1/2" TXP 3.960 8,325.8 3,814.8 79.34 TRIPPLE CONNECT BUSHING 6.600 Baker 4.5" x 7.63"LEM #1 (Above Hook hanger) SN # 106290791-02 Baker PN H289 -18- 0036, CN 1062907 91-02 3.700 8,329.0 3,815.4 79.36 TRIPPLE CONNECT BUSHING 6.600 Baker 4.5" x 7.63" LEM #1 (Below Hook Hanger @ 8328.95) Baker PN H289 -18- 0036, CN 1062907 91-02 3.688 8,439.9 3,835.8 79.38 NIPPLE 5.450 Camco 4-1/2" x 3.563" DB-6 Nipple, TXP-m SN# 5773-2 Camco DB 6 PN: 1028455 30, SN 5773-2 3.563 8,487.3 3,844.8 78.30 SEAL ASSY 4.500 Baker 190-47 GBH-22, 4-1/2", L-80 Straight Non-Locating Seal Assy Baker PN H453 -01- 0033, CN: 1064161 81-01 3.890 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,850.0 3,722.4 76.58 FISH 6 SLIPS FROM TEST PACKER LEFT IN HOLE. 2.19" X 1.49" X 0.53". 4 Slips recovered 2 left in the hole. 4/17/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,541.4 2,199.4 60.25 1 GAS LIFT GLV BK 6.38 1,490.0 5/14/2024 SLBG KBG 4-5 0.250 5,749.6 3,152.9 73.81 2 GAS LIFT DV BK 6.35 0.0 5/12/2024 SLBG KBMG 0.000 7,309.2 3,592.3 75.96 3 GAS LIFT OV BK 6.39 5/16/2024 SLBG KBGM 0.375 7,742.3 3,696.9 76.20 4 5.68 3 5/12/2024 Opsis Gaug e mandr el Halliburt on Opsis Gauge 0.250 7,799.1 3,710.4 76.27 5 CHEM 5.57 5/12/2024 Chemi cal injecti on line 1100 PSi to open Halliburt on Chem injection 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,464.9 3,840.4 79.03 NIPPLE 6.060 Baker 5.5" "RS" Packoff Seal Nipple 17# L-80 Hyd 563 box x box Baker PN: H294- 01-0656, Control No.: 106296385- 02 4.880 8,497.1 3,846.9 77.82 XO REDUCING 5.500 5.5" Hyd 563 15.5 # box x 4.5" 12.6# TXP- pin Crossover 3.970 10,718.1 4,096.2 91.79 SWELL PACKER 6.010 Baker 6.0" OD Swell Packer #6 (3) SN: 052826-001-21 Baker PN H301-87 -0397, SN: 052826-001 -21 3.940 11,012.3 4,093.3 88.99 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #5 (2) SN: 052826-001-32 Baker PN H301-87 -0397, SN: 052826-001 -32 3.940 11,585.5 4,076.7 92.81 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #4 (1) SN: 052826-001-5 Baker PN H301-87 -0397, SN: 052826-001 -5 3.940 11,944.0 4,047.9 94.83 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #3 (C) SN: 054009-010-18 Baker PN H301-87 -0450, SN: 054009-010 -18 3.950 13,574.7 4,008.8 91.99 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #2 (B) SN: 054009-010-20 Baker PN H301-87 -0450, SN: 054009-010 -20 3.940 13,904.4 4,013.9 82.07 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #1 (A) SN: 054009-010-14 Baker PN H301-87 -0450, SN: 054009-010 -14 3.940 HORIZONTAL, 1H-104, 6/7/2024 8:18:20 AM Vertical schematic (actual) SLOTTED LINER (MAIN WELLBORE); 8,444.9-15,993.7 INTERMEDIATE; 37.5-9,493.2 NIPPLE; 8,439.9 NIPPLE; 8,100.7 Wireline Guide; 8,021.9 Nipple - X; 8,003.1 Packer (Tubing); 7,936.3 Nipple - X; 7,863.8 FISH; 7,850.0 Mandrel INJ; 7,799.1 Gauge / Pump Sensor; 7,742.3 Mandrel GAS LIFT; 7,309.2 Mandrel GAS LIFT; 5,749.6 Mandrel - SOV; 2,541.4 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 35.4 KUP PROD 1H-104 ... WELLNAME WELLBORE1H-104 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com HORIZONTAL, 1H-104, 6/7/2024 8:18:21 AM Vertical schematic (actual) SLOTTED LINER (MAIN WELLBORE); 8,444.9-15,993.7 INTERMEDIATE; 37.5-9,493.2 NIPPLE; 8,439.9 NIPPLE; 8,100.7 Wireline Guide; 8,021.9 Nipple - X; 8,003.1 Packer (Tubing); 7,936.3 Nipple - X; 7,863.8 FISH; 7,850.0 Mandrel INJ; 7,799.1 Gauge / Pump Sensor; 7,742.3 Mandrel GAS LIFT; 7,309.2 Mandrel GAS LIFT; 5,749.6 Mandrel - SOV; 2,541.4 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 35.4 KUP PROD 1H-104 ... WELLNAME WELLBORE1H-104 By Samantha Carlisle at 8:35 am, Jul 21, 2022 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\NPKVI7IS\2025-06-25_23082_KRU_1H-104_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23082 KRU 1H-104 50-029-23610-00 Caliper Survey w/ Log Data 25-Jun-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 218-084 T40629 7/2/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.02 08:06:23 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-02-06_24003_KRU_1H-104_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 24003 KRU 1H-104 50-029-23610-00 Caliper Survey w/ Log Data 06-Feb-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 218-084 T40077 2/14/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.14 08:14:58 -09'00' Originated: Delivered to:9-Jul-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1H-10 50-029-22346-00 909358839 Kuparuk River Patch Setting Record Field- Final 27-May-24 0 1 2 1H-104 50-029-23610-00 909292908 Kuparuk River Leak Detect Log with ACX Field & Processed 22-Apr-24 0 1 3 1L-06 50-029-21164-00 n/a Kuparuk River Leak Detect Log Field- Final 7-May-24 0 1 4 1L-06 50-029-21164-00 909298478 Kuparuk River Multi Finger Caliper Field & Processed 8-May-24 0 1 5 1L-06 50-029-21164-00 n/a Kuparuk River Plug Setting Record Field- Final 7-May-24 0 1 6 1L-24 50-029-22170-00 909422478 Kuparuk River Multi Finger Caliper Field & Processed 4-Jul-24 0 1 7 1L-24 50-029-22170-00 909422478 Kuparuk River Patch Setting Record Field- Final 6-Jul-24 0 1 8 1R-35 50-029-23050-00 909353301 Kuparuk River Multi Finger Caliper Field & Processed 29-May-24 0 1 9 2A-14 50-103-20040-00 909382630 Kuparuk River Patch Setting Record Field- Final 13-Jun-24 0 1 10 2B-11 50-029-21089-00 n/a Kuparuk River Plug Setting Record Field- Final 11-May-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39155 T39156 T39157 T39157 T39157 T39158 T39158 T39159 T39160 T39161 193-030 218-084184-133 191-066201-210 185-145184-035 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:13:09 -08'00' 1H-104 50-029-23610-00 909292908 Kuparuk River Leak Detect Log with ACX Field & Processed 22-Apr-24 0 1 T39156 193 030 218-084184 133 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\I1OGWE08\2024-05-09_22600_KRU_1H-104_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22600 KRU 1H-104 50-029-23610-00 Caliper Survey w/ Log Data 09-May-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 218-084T38814 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.17 10:46:22 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV U WSAK 1H-104 JBR 06/12/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 4" & 4.5" Test joints. 4 alarms stations tested. PVT alarms tested. Precharge Bottles: 22 @ 1000 PSI. Good test. Revised report shows two kill line valves which is correct fore future reference. Operator had some pushback about which valves were to be tested or not. Shouldn't be an issue again. Failure on the Annular control system response time - Annular smaller than 18 3/4" required close time is less than or equal to 30 seconds. Test Results TEST DATA Rig Rep:Roy FritsOperator:ConocoPhillips Alaska, Inc.Operator Rep:Johnathan Benedict Rig Owner/Rig No.:Doyon 25 PTD#:2180840 DATE:5/8/2024 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopJDH240508163557 Inspector Josh Hunt Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5 MASP: 1778 Sundry No: 324-079 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 2-7/8"x5"P #2 Rams 1 Blind / Shear P #3 Rams 1 2-7/8"x5"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"P Kill Line Valves 2 3-1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P2925 Pressure After Closure P1750 200 PSI Attained P14 Full Pressure Attained P78 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6 / 1950 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer F35 #1 Rams P5 #2 Rams P5 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9 9 9999 9 9 9 9 MEU two kill line valves Failure on the Annular control system response time - Annular smaller than 18 3/4" required close time is less than or equal to 30 seconds. 35 F 13-5/8" From:Regg, James B (OGC) To:Hobbs, Greg S Cc:DOA AOGCC Prudhoe Bay Subject:RE: [EXTERNAL]Doyon 25 05-08-24 revised Date:Wednesday, June 12, 2024 9:45:02 AM Thank you for reiterating the Annular preventer close time requirements with Company reps, Toolpushers, and Superintendents. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 -----Original Message----- From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Wednesday, June 12, 2024 8:01 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Rig 25 <rig25@doyondrilling.com>; Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com>; Operations Engineer, Doyon 25 <Doyon25.OperationsEngineer@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com> Subject: FW: [EXTERNAL]Doyon 25 05-08-24 revised 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. Jim, Thanks for the mail and call yesterday on the Doyon 25 BOPE test of 5/8/24. As we discussed, I reviewed the annular closing times for all the BOPE tests this year and this one does not make sense. Johnson Njoku, the Superintendent, was at the rig and discussed it with the Toolpusher and the Company Representative and they were thinking it had to be a typographical error but had no proof of it after looking at other records. Johnson and I discussed whether this test was around the time that the system fluid was contaminated, and it was not. As you requested, the rig sent an updated report with the failure this morning, and Johnson discussed the passing criteria for the closing time for the annular with Doyon 25, and he will be sure the information is reiterated to all of the Company Representatives and Toolpushers for that rig. I will also send a note to all of our superintendents about the issue and the annular closing time passing criteria to reiterate to our other rig personnel. Greg Doyon 25 Annular Closing Times 1/15/24- 26 seconds 2/16/24- 22 seconds 3/3/24- 22 seconds 3/12/24- 23 seconds 4/14/24- 26 seconds 4/22/24- 22 seconds 5/8/24- 35 seconds 5/20/24- 16 seconds 6/3/24- 19 seconds MEU 9 9 $2*&&,QVS5SWERS-'+ .58+37' discussed theyq g p p passing criteria for the closing time for the annular with Doyon 25 all of the Company Representatives and Toolpushers gg send a note to all of ourg superintendents about the issue and the annular closing time passing criteria to reiterate to our other rig personnel py p p -----Original Message----- From: Rig 25 <rig25@doyondrilling.com> Sent: Wednesday, June 12, 2024 7:36 AM To: AOGCC <AOGCC.Inspectors@alaska.gov>; jim.regg <jim.regg@alaska.gov>; Brooks, Phoebe L)CED <phoebe.brooks@alaska.gov> Cc: Drilling Supervisor, Doyon 25 <d25cm@conocophillips.com>; Operations Engineer, Doyon 25 <Doyon25.OperationsEngineer@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: [EXTERNAL]Doyon 25 05-08-24 revised CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Roy Fritts Rig 25 Toolpusher rig25@doyondrilling.com 907-670-4971 'R\RQ%23(7HVW $2*&&,QVS5SWERS-'+ .58+37' 'R\RQ%23(7HVW $2*&&,QVS5SWERS-'+ .58+37' 1H-104 5-8-24 Tested 250 / 25OOPSI/ 5 MIN EA. 4.5” Test Joint 1. Annular Preventer, Valves: 1, 13, 14, 15, 4” DART 2. UPR (2 7/8” x 5”), Valves: 10, 12, 2, HCR Kill, 4” FOSV #1. 3. Valves: 6, 9, 11, Manual Kill, 4” FOSV #2. 4. Valves: 5,7,8, UPR IBOP 5. Valve: 3, LWR IBOP 6. LPRS (2 7/8” x 5”) 7. Blind Rams, Valve:4 8. A – Manual Choke B – Hydraulic Choke 4” Test Joint 9. Annular, HCR Choke 10.UPR (2 7/8” x 5”), Manual Choke 11.LPRS (2 7/8 x 5”) 12. Kill line Demco 'R\RQ%23(7HVW $2*&&,QVS5SWERS-'+ .58+37' 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: Replace Wellhead 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 16014' 7850' Casing Collapse Structural Conductor Surface Intermediate Production Slotted Liner (Main Wellbore) Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 265-6312 Senior RWO/CTD Engineer KRU 1H-104 4025' 16014' 4025' 1778 psi None N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: sydney.long@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8013' MD and 3757' TVD 8271' MD and 3805' TVD N/A Sydney Long STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025638, ADL0025639 218-084 P.O. Box 100360, Anchorage, AK 99510 50-029-23610-00-00 Kuparuk River Field West Sak Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY West Sak Oil Pool TVD Burst 8302' MD MD 118' 1777' 4086' 118' 1899' 20" 10-3/4" 78' 7-5/8"5407' 1859' 9493' Slotted Liner: 8445-15994' 4-1/2" Slotted Liner : 3837-4025' Perforation Depth TVD (ft): 5/1/2024 15994'7549' 4-1/2" 4026' Packer: Baker ZXP Liner Top Packer Packer: Baker ZXP Liner Top Packer SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:03 pm, Apr 24, 2024 SFD 4/24/2024 DSR-4/29/24VTL 5/6/2024 X BOP test to 2500 psig Annular preventer test to 2500 psig 10-404X JLC 5/6/2024 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for a Changed to Approved Sundry #324-079 to work over West Sak Producer 1H-104 (PTD# 218-084). This well was planned for the tubing to be pulled from seals, a new wellhead put on the well, then a new 4.5" completion run with seals stung back into the original seal-bore. However, in its pre-rig well work, 1H-104 failed an MIT-IA. An acoustic log was run, and a leak was found at the packer depth. It is requested that the completion for the 1H-104 rig workover be modified to include a stacked packer to restore integrity to the IA. If you have any questions or require any further information, please contact me at 907-265-6321. Sydney Long Senior Rig Workover Engineer CPAI Drilling and Wells 1H-104 West Sak Producer Pull and Replace Tubing Procedure PTD: 218-084 Page 1 of 2 Pre-Rig Work -Completed 1. T-PPPOT and T-POT tests. 2. Obtain new SIBHP 3. Set plug at 8,439 RKB in DB Nipple. CMIT - Fail 4. MIT-T - Pass 5. MIT-IA -Fail 6. Acoustic Leak Detect Log Pre-Rig Work Outstanding 1. Dummy off upper GLMs and leave deepest GLM open for circulations 2. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Doyon 25 on 1H-104. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2 tubing down to seals. Install New Wellhead 6. RIH with DP and set G-plug and/or storm packer. Test same to confirm as barrier. 7. ND BOPs. ND horizontal wellhead tubing spool. NU new vertical tubing spool. NU BOPs. Test same. 8. Pull plugs/storm packers from wellbore. Circulate out packer gas as needed. Install new 4-½ Tubing 9. MU 4 ½ completion with packer, PBR and seals, gauge, nipples, Chem Injection, and GLMs. 10. RIH with completion. Once on depth, sting into SBE and set packer. Pick up and space out seals. 11. Space out as needed. Circulate CI brine at opportune time. Land tubing and RILDS. Test packoffs. 12. Drop ball and rod. Pressure test tubing to 3000 psi for 30 minutes and chart. 13. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 14. Confirm pressure tests, then shear out SOV with pressure differential. 15. Install BPV. Test BPV as needed. ND BOPE. NU tree. 16. Pull BPV, freeze protect well if necessary. 17. RDMO. 1H-104 West Sak Producer Pull and Replace Tubing Procedure PTD: 218-084 Page 2 of 2 Post-Rig Work 18. Retrieve ball and rod from tubing string and install GLD. 19. Turn over to operations. General Well Information: Estimated Start Date: 5/1/2024 Current Operations: Shut In Well Type: Producer Wellhead Type: VetcoGray MB222A 5M BOP Configuration: Annular / Pipe Rams / Blind Rams Static BHP: 1,272 PSI at 3,745 TVD on 4/20/2024 MPSP: 897 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 4-1/2 completion from seals. Change wellhead to a vertical configuration. Run new 4-1/2 completion with a stacked packer. Personnel: Workover Engineer: Sydney Long (265-6321 / Sydney.Long@conocophillips.com) Reservoir Surv. Engineer: Marina Krysinski Production Engineer: Will Parker 1H-104 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 119 119 20 19.12 78.7 B Welded Welded Surface 1899 1777 10.75 9.95 45.5 L80 HYD563 HYD563 Production 9493 4086 7.625 6.88 29.7 L80 HYD563 HYD563 Laterals 15994 4025 4.5 4 11.6 L80 TXP TXP Tubing 8043 3762 4.5 3.96 12.6 L80 HYD563 HYD563 PROPOSED COMPLETION 4-1/2" 12.6# L-80 Hyd 563 Tubing to surface 4-1/2" L-80 Camco KBMG gas lift mandrels @ TBD 4-1/2" 12.6# 13Cr VamTop Tubing from Lowest GLM to Seals Gauge Mandrel (TEC wire with Clamps to Surface) 13Cr Chem Injection Mandrel (1/4" Line to Surface) 13Cr 3.813" X-Nipple 13Cr 4-1/2" Seals 13Cr 4-1/2" Polished Bore Receptacle 4-1/2" x 7-5/8" Baker Premier Packer 3.813" X Nipple 4-1/2" Stripped Seal Assembly REMAINING COMPLETION LEFT IN HOLE ZXPN Liner Top Packer (8012' RKB) Seal Bore Extension. 4.750" ID (8032' RKB) West Sak Laterals Production Casing Conductor West Sak Liners/Laterals Surface Casing Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added packer leak at 8012' RKB 1H-104 4/22/2024 jconne Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 40.4 118.5 118.5 94.00 L-80 Welded SURFACE 10 3/4 9.95 40.3 1,899.3 1,777.4 45.50 L-80 Hydril 563 INTERMEDIATE 7 5/8 6.88 37.5 9,493.2 4,086.2 29.70 L-80 Hyd 563 SLOTTED LINER (MAIN WELLBORE) 4 1/2 3.96 8,444.9 15,993.8 4,025.8 12.60 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.1 Set Depth 8,043.5 Set Depth 3,762.8 String Max No 4 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 12.60 Grade L80 Top Connection H563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 33.1 33.1 0.00 Hanger 10.875 Vetco Grey offset hanger w/ false bowl (w/ bowl 13.375" OD) Vault MB222A offset 3.958 2,556.9 2,207.0 60.71 Mandrel 4.500 Camco 4-1/2" x1" KBMG Mandrel, DMY, BK Latch, SN 21752-21 Camco KBMG 3.865 5,759.9 3,155.7 73.82 Mandrel 4.500 Camco 4-1/2" x1" KBMG Mandrel, DMY, BK Latch, SN 21752-08 Camco KBMG 3.865 7,169.3 3,554.8 73.65 Mandrel 4.500 Camco 4-1/2" x1" KBMG Mandrel, SOV, BEK Latch, SN 21752-25 Camco KBMG 3.865 7,806.0 3,712.1 76.32 Sleeve - Sliding 5.570 SLB Nexa-2 CMU with 3.812" "X" with RHC plug (Closed on 4/17/24) SLB Nexa-2 CMU 3.813 7,953.7 3,745.3 78.15 Gauge Mandrel 5.685 HES 4 1/2" gauge SN 4790912911- 01-01 HES Gauge 3.920 8,014.6 3,757.4 79.03 Locator 5.360 Baker 5 1/2" Locator Baker Locator 3.900 8,016.4 3,757.7 79.06 Seal Assembly 4.740 Baker 4.75" GBH-22 Seal Assembly 192-47 w/ spacer tubes. .5' from fully located Baker 192-47 Seal Assembl y 3.870 Top (ftKB) 8,012.7 Set Depth 8,302.0 Set Depth 3,810.4 String Max No 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP-M ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,012.7 3,757.0 79.00 PACKER 6.540 Baker ZXP Liner Top Packer 5.5" x 7.63", 5-1/2" H563 Baker ZXP LTP PN: H296-45 -0131, Control # 1062955 66-01 4.920 8,032.7 3,760.8 79.31 SBE 6.250 Baker 190-47 Seal Bore Extension, 5-1/2" Baker SBE PN: H02 -43317- A1 SI# 700886 4.750 8,052.3 3,764.4 79.50 CROSSOVER (XO) BUSHING 5.500 Reducing Crossover sub 5½" Hyd 563 X 4-1/2" TXP 3.950 8,100.7 3,773.2 79.44 NIPPLE 5.200 Camco 4-1/2" x 3.750" DB-6 Nipple, TXP-m SN# 4053-1R Camco DB 6 SN# 4053-1R 3.750 8,159.8 3,784.0 79.36 TRIPPLE CONNECT BUSHING 6.610 Baker 4.5" x 7.63"LEM #1 (Above Hook hanger) SN # 106290368-02 Baker LEM Pos 2 PN: H289-18 -0037, Control # : 1062903 68-02 3.700 8,163.0 3,784.6 79.39 TRIPPLE CONNECT BUSHING 6.610 Baker 4.5" x 7.63" LEM #1 (Below Hook Hanger @ 8162.94') Baker LEM Pos 2 PN: H289-18 -0037, Control # : 1062903 68-02 3.688 8,298.7 3,809.8 79.18 SEAL ASSY 4.500 Baker 190-47 GBH-22, 4-1/2", L-80 Straight Non-Locating Seal Assy Baker 190-47 GBH-22 3.870 Top (ftKB) 8,271.4 Set Depth 8,490.5 Set Depth 3,845.5 String Max No 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP-m BTC ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,271.4 3,804.6 79.00 PACKER 6.550 Baker ZXP Liner Top Packer 5.5" x 7.63", 5-1/2" H563 Baker ZXP LTP PN H296 -45- 0131, CN 1064274 53 4.920 8,291.2 3,808.3 79.12 SBE 6.250 Baker 190-47 Seal Bore Extension, 5-1/2" Baker PN H02- 43317- A1, WO 4.750 INTERMEDIATE; 37.5-9,493.2 NIPPLE; 8,439.9 NIPPLE; 8,100.7 Seal Assembly; 8,016.4 LEAK - PACKER; 8,012.0 FISH; 7,850.0 Sleeve - Sliding; 7,806.0 Mandrel; 7,169.3 Mandrel; 5,759.8 Mandrel; 2,556.9 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 33.1 8,325.8 3,814.8 79.34 TRIPPLE CONNECT BUSHING 6.600 Baker 4.5" x 7.63"LEM #1 (Above Hook hanger) SN # 106290791-02 Baker PN H289 -18- 0036, CN 1062907 91-02 3.700 8,329.0 3,815.4 79.36 TRIPPLE CONNECT BUSHING 6.600 Baker 4.5" x 7.63" LEM #1 (Below Hook Hanger @ 8328.95) Baker PN H289 -18- 0036, CN 1062907 91-02 3.688 8,439.9 3,835.8 79.38 NIPPLE 5.450 Camco 4-1/2" x 3.563" DB-6 Nipple, TXP-m SN# 5773-2 Camco DB 6 PN: 1028455 30, SN 5773-2 3.563 8,487.3 3,844.8 78.30 SEAL ASSY 4.500 Baker 190-47 GBH-22, 4-1/2", L-80 Straight Non-Locating Seal Assy Baker PN H453 -01- 0033, CN: 1064161 81-01 3.890 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,850.0 3,722.4 76.58 FISH 6 SLIPS FROM TEST PACKER LEFT IN HOLE. 2.19" X 1.49" X 0.53". 4/17/2024 0.000 8,012.0 3,756.9 78.99 LEAK - PACKER LEAK IDENTIFIED ON HES ACX LOG PERFORMED 4/22/24 AT 8012' RKB (LOCATION OF BAKER ZXP PACKER) 4/22/2024 4.920 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,556.9 2,207.0 60.71 1 GAS LIFT DMY BK 1 4/19/2024 9:00 Camco BK 0.000 5,759.9 3,155.7 73.82 2 GAS LIFT DMY BK 1 4/19/2024 5:00 Camco BK 0.000 7,169.3 3,554.8 73.65 3 GAS LIFT OPEN BK 1 4/23/2024 Camco BKO-3 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,464.9 3,840.4 79.03 NIPPLE 6.060 Baker 5.5" "RS" Packoff Seal Nipple 17# L-80 Hyd 563 box x box Baker PN: H294- 01-0656, Control No.: 106296385- 02 4.880 8,497.1 3,846.9 77.82 XO REDUCING 5.500 5.5" Hyd 563 15.5 # box x 4.5" 12.6# TXP- pin Crossover 3.970 10,718.1 4,096.2 91.79 SWELL PACKER 6.010 Baker 6.0" OD Swell Packer #6 (3) SN: 052826-001-21 Baker PN H301-87 -0397, SN: 052826-001 -21 3.940 11,012.3 4,093.3 88.99 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #5 (2) SN: 052826-001-32 Baker PN H301-87 -0397, SN: 052826-001 -32 3.940 11,585.5 4,076.7 92.81 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #4 (1) SN: 052826-001-5 Baker PN H301-87 -0397, SN: 052826-001 -5 3.940 11,944.0 4,047.9 94.83 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #3 (C) SN: 054009-010-18 Baker PN H301-87 -0450, SN: 054009-010 -18 3.950 13,574.7 4,008.8 91.99 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #2 (B) SN: 054009-010-20 Baker PN H301-87 -0450, SN: 054009-010 -20 3.940 13,904.4 4,013.9 82.07 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #1 (A) SN: 054009-010-14 Baker PN H301-87 -0450, SN: 054009-010 -14 3.940 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com INTERMEDIATE; 37.5-9,493.2 NIPPLE; 8,439.9 NIPPLE; 8,100.7 Seal Assembly; 8,016.4 LEAK - PACKER; 8,012.0 FISH; 7,850.0 Sleeve - Sliding; 7,806.0 Mandrel; 7,169.3 Mandrel; 5,759.8 Mandrel; 2,556.9 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 33.1 Notes: General &Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic10.0 10/11/2018 jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 SLOTTED LINER (L1) 4 1/2 3.96 8,329.0 15,934.7 3,972.3 12.60 L-80 IBT-m Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,448.6 3,883.0 88.26 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #7 "DD" SN: 054009-010-15 Baker PN: H301- 87-0450, SN: 054009 -010-15 3.958 10,400.8 3,957.2 86.79 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #6 "CC" SN: 054009-010-10 Baker PN: H301- 87-0450, SN: 054009 -010-10 3.958 10,651.6 3,970.8 85.49 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #5 "BB" SN: 054007-010-23 Baker PN: H301- 87-0450, SN: 054007 -010-23 3.958 10,811.3 3,991.7 81.43 SWELL PACKER 6.010 Baker 6.0" OD Swell Packer #4 "AA" SN: 054009-010-25 Baker PN: H301- 87-0450, SN: 054009 -010-25 3.958 11,176.6 4,027.9 87.66 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #3 "F" SN: 054009-010-16 Baker PN: H301- 87-0450, SN:054009- 010-16 3.958 13,645.0 4,005.2 83.12 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #2 "E" SN: 054009-010-24 Baker PN: H301- 87-0450, SN: 054009 -010-24 3.958 13,830.1 4,026.4 84.46 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #1 "D" SN: 054009-010-1 Baker PN: H301- 87-0450, SN:054009- 010-1 3.958 INTERMEDIATE; 37.5-9,493.2 FISH; 7,850.0 Sleeve - Sliding; 7,806.0 Mandrel; 7,169.3 Mandrel; 5,759.8 Mandrel; 2,556.9 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 33.1 Notes: General &Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic10.0 10/11/2018 jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L2 SLOTTED LINER (L2) 4 1/2 3.96 8,162.9 15,827.0 3,896.2 12.60 L-80 IBT-m Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,281.9 3,825.0 88.86 SWELL PACKER 5.940 Baker 6.0" OD Swell Packer # "MM" SN: 001893-001-9 Baker PN: H3014- 15-0021, SN:001893- 001-9 3.958 13,619.6 3,892.3 78.58 SWELL PACKER 6.030 Baker 6.0" OD Swell Packer # "LL" SN: 001893-001-15 Baker PN: H3014- 15-0021, SN:001893- 001-15 3.958 13,921.4 3,929.5 86.78 SWELL PACKER 5.990 Baker 6.0" OD Swell Packer # "KK" SN: 001893-001-10 Baker PN: H3014- 15-0021, SN:001893- 001-10 3.958 INTERMEDIATE; 37.5-9,493.2 FISH; 7,850.0 Sleeve - Sliding; 7,806.0 Mandrel; 7,169.3 Mandrel; 5,759.8 Mandrel; 2,556.9 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 33.1 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: Replace Wellhead 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 16014'None Casing Collapse Structural Conductor Surface Intermediate Production Slotted Liner (Main Wellbore) Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 5/1/2024 15994'7549' 4-1/2" 4026' Packer: Baker ZXP Liner Top Packer Packer: Baker ZXP Liner Top Packer SSSV: None Perforation Depth MD (ft): L-80 5407' 1859' 9493' Slotted Liner: 8445-15994' 4-1/2" Slotted Liner : 3837-4025' Perforation Depth TVD (ft): 118' 1899' 20" 10-3/4" 78' 7-5/8" 8302' MD MD 118' 1777' 4086' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY West Sak Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025638, ADL0025639 218-084 P.O. Box 100360, Anchorage, AK 99510 50-029-23610-00-00 Kuparuk River Field West Sak Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8013' MD and 3757' TVD 8271' MD and 3805' TVD N/A Sydney Long Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: sydney.long@conocophillips.com (907) 265-6312 Senior RWO/CTD Engineer KRU 1H-104 4025' 16014' 4025' 1778 psi None N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 324-079 By Kayla Junke at 3:23 pm, Feb 14, 2024 X SFD 2/15/2024 X BOP test pressure to 2500 psig Annular preventer test to 2500 psig 10-404 DSR-2/14/24VTL 02/21/2024*&:JLC 2/21/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.21 15:25:59 -09'00'02/21/24 RBDMS JSB 022324 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 13, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Sydney Long Senior Rig Workover Engineer CPAI Drilling and Wells Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over West Sak Producer 1H-104 (PTD# 218-084). This well was worked over in 2022 and received new tubing due to corrosion but utilized the existing horizontal wellhead configuration. After a thorough review of the corrosion concerns observed with the 1H West Sak producers, the horizontal wellhead is no longer the recommended configuration for these wells. It is the objective of this workover to convert to avertical wellhead configurationand replace the tubing string with select upgraded jewelry prior to the well being covered by Doyon 25 as it drills the planned 1H wells later this year. The tubing will be pulled from seals, a new wellhead will be put on the well, then a new 4.5" completion will be run. If you have any questions or require any further information, please contact me at 907-265-6312. 1H-104 West Sak Producer Pull and Replace Tubing Procedure PTD: 218-084 Page 1 of 2 PPre-Rig Work 1. CMIT to 2,500 PSI 2. T-PPPOT and T-POT tests. 3. Obtain new SIBHP 4. Set plug at 8,439’ RKB in DB Nipple. Test as barrier. a. Note, if unable to pressure test plug, RWO will proceed without deep plug 5. Dummy off upper GLMs and leave deepest GLM open for circulations 6. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Doyon 25 on 1H-104. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing down to seals. Install New Wellhead 6. RIH with DP and set G-plug and/or storm packer. Test same to confirm as barrier. 7. ND BOPs. ND horizontal wellhead tubing spool. NU new vertical tubing spool. NU BOPs. Test same. 8. Pull plugs/storm packers from wellbore. Circulate out packer gas as needed. Install new 4-½” Tubing 9. MU 4 ½” completion with seals, gauge, nipples, Chem Injection, and GLMs. 10. RIH with completion. Once on depth, sting into SBE. 11. Space out as needed. Circulate CI brine at opportune time. Land tubing and RILDS. Test packoffs. 12. Pressure test tubing to 3000 psi for 30 minutes and chart. a. Ball and rod will be utilized if no deep plug is installed 13. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 14. Confirm pressure tests, then shear out SOV with pressure differential. 15. Install BPV. Test BPV as needed. ND BOPE. NU tree. 16. Pull BPV, freeze protect well if necessary. 17. RDMO. Post-Rig Work 18. Pull all plugs from tubing string and install GLD. 19. Turn over to operations. 1H-104 West Sak Producer Pull and Replace Tubing Procedure PTD: 218-084 Page 2 of 2 GGeneral Well Information: Estimated Start Date: 5/15/2024 Current Operations: Online Well Type: Producer Wellhead Type: VetcoGray MB222A 5M BOP Configuration: Annular / Pipe Rams / Blind Rams Static BHP: 1,638 PSI at 3,500’ TVD on 7/5/2022 MPSP: 1,778 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 4-1/2” completion from seals. Change wellhead to a vertical configuration. Run new 4-1/2” completion and engage seals. Personnel: Workover Engineer: Sydney Long (265-6321 / Sydney.Long@conocophillips.com) Reservoir Surv. Engineer: Marina Krysinski Production Engineer: Will Parker 1H-104 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 119 119 20 19.12 78.7 B Welded Welded Surface 1899 1777 10.75 9.95 45.5 L80 HYD563 HYD563 Production 9493 4086 7.625 6.88 29.7 L80 HYD563 HYD563 Laterals 15994 4025 4.5 4 11.6 L80 TXP TXP Tubing 8043 3762 4.5 3.96 12.6 L80 HYD563 HYD563 PROPOSED COMPLETION 4-1/2" 12.6# L-80 Hyd 563 Tubing to surface 4-1/2" L-80 Camco KBMG gas lift mandrels @ TBD 4-1/2" 12.6# 13Cr VamTop Tubing from Lowest GLM to Seals Gauge Mandrel (TEC wire with Clamps to Surface) 13Cr Chem Injection Mandrel (1/4" Line to Surface) 13Cr 3.813" X-Nipple 13Cr 4-1/2" Seals 13Cr REMAINING COMPLETION LEFT IN HOLE ZXPN Liner Top Packer (8012' RKB) Seal Bore Extension. 4.750" ID (8032' RKB) West Sak Laterals Production Casing Conductor West Sak Liners/Laterals Surface Casing Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG:1H-104 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Installed GLD & Pulled RHC Plug 1H-104 6/30/2022 zembaej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 40.4 118.5 118.5 94.00 L-80 Welded SURFACE 10 3/4 9.95 40.3 1,899.3 1,777.4 45.50 L-80 Hydril 563 INTERMEDIATE 7 5/8 6.88 37.5 9,493.2 4,086.2 29.70 L-80 Hyd 563 SLOTTED LINER (MAIN WELLBORE) 4 1/2 3.96 8,444.9 15,993.8 4,025.8 12.60 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.1 Set Depth … 8,043.5 Set Depth … 3,762.8 String Max No… 4 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 12.60 Grade L80 Top Connection H563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 33.1 33.1 0.00 Hanger 10.875 Vetco Grey offset hanger w/ false bowl (w/ bowl 13.375" OD) Vault MB222A offset 3.958 2,556.9 2,207.0 60.71 Mandrel 4.500 Camco 4-1/2" x1" KBMG Mandrel, DMY, BK Latch, SN 21752-21 Camco KBMG 3.865 5,759.9 3,155.7 73.82 Mandrel 4.500 Camco 4-1/2" x1" KBMG Mandrel, DMY, BK Latch, SN 21752-08 Camco KBMG 3.865 7,169.3 3,554.8 73.65 Mandrel 4.500 Camco 4-1/2" x1" KBMG Mandrel, SOV, BEK Latch, SN 21752-25 Camco KBMG 3.865 7,806.0 3,712.1 76.32 Sleeve - Sliding 5.570 SLB Nexa-2 CMU with 3.812" "X" with RHC plug (Closed Position) SLB Nexa-2 CMU 3.813 7,953.7 3,745.3 78.15 Gauge Mandrel 5.685 HES 4 1/2" gauge SN 4790912911- 01-01 HES Gauge 3.920 8,014.6 3,757.4 79.03 Locator 5.360 Baker 5 1/2" Locator Baker Locator 3.900 8,016.4 3,757.7 79.06 Seal Assembly 4.740 Baker 4.75" GBH-22 Seal Assembly 192-47 w/ spacer tubes. .5' from fully located Baker 192-47 Seal Assembl y 3.870 Top (ftKB) 8,012.7 Set Depth … 8,302.0 Set Depth … 3,810.4 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP-M ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,012.7 3,757.0 79.00 PACKER 6.540 Baker ZXP Liner Top Packer 5.5" x 7.63", 5-1/2" H563 Baker ZXP LTP PN: H296-45 -0131, Control # 1062955 66-01 4.920 8,032.7 3,760.8 79.31 SBE 6.250 Baker 190-47 Seal Bore Extension, 5-1/2" Baker SBE PN: H02 -43317- A1 SI# 700886 4.750 8,052.3 3,764.4 79.50 CROSSOVER (XO) BUSHING 5.500 Reducing Crossover sub 5½" Hyd 563 X 4-1/2" TXP 3.950 8,100.7 3,773.2 79.44 NIPPLE 5.200 Camco 4-1/2" x 3.750" DB-6 Nipple, TXP-m SN# 4053-1R Camco DB 6 SN# 4053-1R 3.750 8,159.8 3,784.0 79.36 TRIPPLE CONNECT BUSHING 6.610 Baker 4.5" x 7.63"LEM #1 (Above Hook hanger) SN # 106290368-02 Baker LEM Pos 2 PN: H289-18 -0037, Control # : 1062903 68-02 3.700 8,163.0 3,784.6 79.39 TRIPPLE CONNECT BUSHING 6.610 Baker 4.5" x 7.63" LEM #1 (Below Hook Hanger @ 8162.94') Baker LEM Pos 2 PN: H289-18 -0037, Control # : 1062903 68-02 3.688 8,298.7 3,809.8 79.18 SEAL ASSY 4.500 Baker 190-47 GBH-22, 4-1/2", L-80 Straight Non-Locating Seal Assy Baker 190-47 GBH-22 3.870 Top (ftKB) 8,271.4 Set Depth … 8,490.5 Set Depth … 3,845.5 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP-m BTC ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,271.4 3,804.6 79.00 PACKER 6.550 Baker ZXP Liner Top Packer 5.5" x 7.63", 5-1/2" H563 Baker ZXP LTP PN H296 -45- 0131, CN 1064274 53 4.920 8,291.2 3,808.3 79.12 SBE 6.250 Baker 190-47 Seal Bore Extension, 5-1/2" Baker PN H02- 43317- A1, WO 4509345 733 4.750 8,310.8 3,812.0 79.26 CROSS OVER (XO) BUSHING 5.500 Reducing Crossover sub 5½" Hyd 563 X 4-1/2" TXP 3.960 1H-104, 2/13/2024 4:32:54 PM Vertical schematic (actual) SLOTTED LINER (MAIN WELLBORE); 8,444.9-15,993.7 INTERMEDIATE; 37.5-9,493.2 NIPPLE; 8,439.9 NIPPLE; 8,100.7 Seal Assembly; 8,016.4 Sleeve - Sliding; 7,806.0 Mandrel; 7,169.3 Mandrel; 5,759.8 Mandrel; 2,556.9 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 33.1 KUP PROD KB-Grd (ft) 38.89 RR Date 9/18/2018 Other Elev… 1H-104 ... TD Act Btm (ftKB) 16,014.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292361000 Wellbore Status PROD Max Angle & MD Incl (°) 97.52 MD (ftKB) 14,589.00 WELLNAME WELLBORE1H-104 Annotation LAST WO: End Date 6/27/2022 H2S (ppm) DateComment Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,325.8 3,814.8 79.34 TRIPPLE CONNECT BUSHING 6.600 Baker 4.5" x 7.63"LEM #1 (Above Hook hanger) SN # 106290791-02 Baker PN H289 -18- 0036, CN 1062907 91-02 3.700 8,329.0 3,815.4 79.36 TRIPPLE CONNECT BUSHING 6.600 Baker 4.5" x 7.63" LEM #1 (Below Hook Hanger @ 8328.95) Baker PN H289 -18- 0036, CN 1062907 91-02 3.688 8,439.9 3,835.8 79.38 NIPPLE 5.450 Camco 4-1/2" x 3.563" DB-6 Nipple, TXP-m SN# 5773-2 Camco DB 6 PN: 1028455 30, SN 5773-2 3.563 8,487.3 3,844.8 78.30 SEAL ASSY 4.500 Baker 190-47 GBH-22, 4-1/2", L-80 Straight Non-Locating Seal Assy Baker PN H453 -01- 0033, CN: 1064161 81-01 3.890 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,556.9 2,207.0 60.71 1 GAS LIFT GLV BK 1 6/30/2022 Camco KBMG 0.188 5,759.9 3,155.7 73.82 2 GAS LIFT GLV BK 1 1,465.0 6/30/2022 Camco KBMG 0.188 7,169.3 3,554.8 73.65 3 GAS LIFT OV BK 1 0.0 6/30/2022 Camco KBMG 0.375 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,464.9 3,840.4 79.03 NIPPLE 6.060 Baker 5.5" "RS" Packoff Seal Nipple 17# L-80 Hyd 563 box x box Baker PN: H294- 01-0656, Control No.: 106296385- 02 4.880 8,497.1 3,846.9 77.82 XO REDUCING 5.500 5.5" Hyd 563 15.5 # box x 4.5" 12.6# TXP- pin Crossover 3.970 10,718.1 4,096.2 91.79 SWELL PACKER 6.010 Baker 6.0" OD Swell Packer #6 (3) SN: 052826-001-21 Baker PN H301-87 -0397, SN: 052826-001 -21 3.940 11,012.3 4,093.3 88.99 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #5 (2) SN: 052826-001-32 Baker PN H301-87 -0397, SN: 052826-001 -32 3.940 11,585.5 4,076.7 92.81 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #4 (1) SN: 052826-001-5 Baker PN H301-87 -0397, SN: 052826-001 -5 3.940 11,944.0 4,047.9 94.83 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #3 (C) SN: 054009-010-18 Baker PN H301-87 -0450, SN: 054009-010 -18 3.950 13,574.7 4,008.8 91.99 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #2 (B) SN: 054009-010-20 Baker PN H301-87 -0450, SN: 054009-010 -20 3.940 13,904.4 4,013.9 82.07 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #1 (A) SN: 054009-010-14 Baker PN H301-87 -0450, SN: 054009-010 -14 3.940 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 1H-104, 2/13/2024 4:32:55 PM Vertical schematic (actual) SLOTTED LINER (MAIN WELLBORE); 8,444.9-15,993.7 INTERMEDIATE; 37.5-9,493.2 NIPPLE; 8,439.9 NIPPLE; 8,100.7 Seal Assembly; 8,016.4 Sleeve - Sliding; 7,806.0 Mandrel; 7,169.3 Mandrel; 5,759.8 Mandrel; 2,556.9 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 33.1 KUP PROD 1H-104 ... WELLNAME WELLBORE1H-104 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG:1H-104L1 jennalt Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic10.0 10/11/2018 jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 SLOTTED LINER (L1) 4 1/2 3.96 8,329.0 15,934.7 3,972.3 12.60 L-80 IBT-m Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,448.6 3,883.0 88.26 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #7 "DD" SN: 054009-010-15 Baker PN: H301- 87-0450, SN: 054009 -010-15 3.958 10,400.8 3,957.2 86.79 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #6 "CC" SN: 054009-010-10 Baker PN: H301- 87-0450, SN: 054009 -010-10 3.958 10,651.6 3,970.8 85.49 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #5 "BB" SN: 054007-010-23 Baker PN: H301- 87-0450, SN: 054007 -010-23 3.958 10,811.3 3,991.7 81.43 SWELL PACKER 6.010 Baker 6.0" OD Swell Packer #4 "AA" SN: 054009-010-25 Baker PN: H301- 87-0450, SN: 054009 -010-25 3.958 11,176.6 4,027.9 87.66 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #3 "F" SN: 054009-010-16 Baker PN: H301- 87-0450, SN:054009- 010-16 3.958 13,645.0 4,005.2 83.12 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #2 "E" SN: 054009-010-24 Baker PN: H301- 87-0450, SN: 054009 -010-24 3.958 13,830.1 4,026.4 84.46 SWELL PACKER 6.000 Baker 6.0" OD Swell Packer #1 "D" SN: 054009-010-1 Baker PN: H301- 87-0450, SN:054009- 010-1 3.958 1H-104L1, 2/13/2024 4:32:56 PM Vertical schematic (actual) L1 SLOTTED LINER (L1); 8,329.0-15,934.7 INTERMEDIATE; 37.5-9,493.2 Sleeve - Sliding; 7,806.0 Mandrel; 7,169.3 Mandrel; 5,759.8 Mandrel; 2,556.9 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 33.1 KUP PROD KB-Grd (ft) 38.89 RR Date 9/18/2018 Other Elev… 1H-104L1 ... TD Act Btm (ftKB) 15,972.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292361060 Wellbore Status PROD Max Angle & MD Incl (°) 94.87 MD (ftKB) 11,956.00 WELLNAME WELLBORE1H-104 Annotation LAST WO: End Date 6/27/2022 H2S (ppm) DateComment Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG:1H-104L2 jennalt Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic10.0 10/11/2018 jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L2 SLOTTED LINER (L2) 4 1/2 3.96 8,162.9 15,827.0 3,896.2 12.60 L-80 IBT-m Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,281.9 3,825.0 88.86 SWELL PACKER 5.940 Baker 6.0" OD Swell Packer # "MM" SN: 001893-001-9 Baker PN: H3014- 15-0021, SN:001893- 001-9 3.958 13,619.6 3,892.3 78.58 SWELL PACKER 6.030 Baker 6.0" OD Swell Packer # "LL" SN: 001893-001-15 Baker PN: H3014- 15-0021, SN:001893- 001-15 3.958 13,921.4 3,929.5 86.78 SWELL PACKER 5.990 Baker 6.0" OD Swell Packer # "KK" SN: 001893-001-10 Baker PN: H3014- 15-0021, SN:001893- 001-10 3.958 1H-104L2, 2/13/2024 4:32:57 PM Vertical schematic (actual) L2 SLOTTED LINER (L2); 8,162.9-15,827.0 INTERMEDIATE; 37.5-9,493.2 Sleeve - Sliding; 7,806.0 Mandrel; 7,169.3 Mandrel; 5,759.8 Mandrel; 2,556.9 SURFACE; 40.3-1,899.3 CONDUCTOR; 40.4-118.5 Hanger; 33.1 KUP PROD KB-Grd (ft) 38.89 RR Date 9/18/2018 Other Elev… 1H-104L2 ... TD Act Btm (ftKB) 15,872.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292361061 Wellbore Status PROD Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORE1H-104 Annotation LAST WO: End Date 6/27/2022 H2S (ppm) DateComment C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-10-18_22557_KRU_1H-104_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22557 KRU 1H-104 50-029-23610-00 Caliper Survey w/ Log Data 18-Oct-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 218-084 T38084 10/20/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.20 14:38:47 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-08-27_22557_KRU_1H-104_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22557 KRU 1H-104 50-029-23610-00 Caliper Survey w/ log Data 27-Aug-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:218-084 T37976 9/5/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.09.05 11:36:02 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-07-03_21150_KRU_1H-104_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21150 KRU 1H-104 50-029-23610-00 Caliper Survey w/ Log Data 03-Jul-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 218-084 T37806 Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.05 15:21:52 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-05-19_15927_KRU_1H-104_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15927 KRU 1H-104 50-029-23610-00 Caliper Survey w/ Log Data 19-May-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 218-084 T37671 Kayla Junke Digitally signed by Kayla Junke Date: 2023.05.25 13:31:33 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-04-09_21132_KRU_1H-09_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21132 KRU 1H-104 50-029-23610-00 Caliper Survey w/ Log Data 09-Apr-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:218-084 T37606 Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.17 15:23:25 -08'00' 5HJJ-DPHV%2*& )URP&R]E\.HOO\.HOO\&R]E\#QDERUVFRP! 6HQW6XQGD\-XQH30 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*&16.5:2&0 &F+HQVRQ-DPHV+ROFRPE6HDQ+REEV*UHJ6.QHDOH0LFKDHO/ 6XEMHFW1DERUV(6 $WWDFKPHQWV1DERUV(6[OV[ dŚĂŶŬzŽƵ <ĞůůǇŽǌďǇ ϳ^ZŝŐDĂŶĂŐĞƌ EĂďŽƌƐůĂƐŬĂƌŝůůŝŶŐ/ŶĐ͘ KĨĨŝĐĞϵϬϳͲϲϳϬͲϲϭϯϮĞůůϵϬϳͲϳϭϱͲϵϬϱϱ ŬĞůůǇ͘ĐŽǌďǇΛŶĂďŽƌƐ͘ĐŽŵ ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:7ES DATE: 6/25/22 Rig Rep.: Rig Phone: 670-6132 Operator: Op. Phone:670-6130 Rep.: E-Mail Well Name: PTD #22180840 Sundry #322-355 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1460 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" T 90 P Pit Level Indicators PP #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 2 7/8" x 5"NT H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8" Gate P Inside Reel valves 0NA HCR Valves 2 3 1/8" Gate P Kill Line Valves 2 3 1/8" & 2"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1610 P Quantity Test Result 200 psi Attained (sec)20 P No. Valves 16 P Full Pressure Attained (sec)94 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 5@1950psi P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:5.0 Hours Repair or replacement of equipment will be made within 0 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 6-23-22 6:52PM Waived By Test Start Date/Time:6/25/2022 7:00 (date) (time)Witness Test Finish Date/Time:6/25/2022 12:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Matt Herrera Nabors Tested with 41/2" test jnt. Kelly Cozby / Sean Holcomb ConocoPhillips Mark Adams / K.Barr KRU 1H-104 Test Pressure (psi): nskrwo.cm@conocophillips.com Form 10-424 (Revised 02/2022) 2022-0625_BOP_Nabors7ES_KRU_1H-104 9 9 9 9999 9 9 9 9 9 9 -5HJJ CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Ward, Dusty K To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]Re: KRU 1H-104 (PTD 218-084) 10-403 RWO Date:Thursday, June 23, 2022 10:10:47 AM Hey Victoria, Just wanted to follow up and make sure we didn’t miss anything from our side. Were you able to approve this yet? We hadn’t seen the 10-403 yet from our side, so just wanted to confirm we didn’t miss an email or anything. We’ll keep an eye out for it today and should be moving to that well later today. Thank you for your time. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, June 22, 2022 11:15 AM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Subject: [EXTERNAL]Re: KRU 1H-104 (PTD 218-084) 10-403 RWO CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. This should be approved today sometime. Sent from my iPhone On Jun 22, 2022, at 8:49 AM, Ward, Dusty K <Dusty.Ward@conocophillips.com> wrote: Victoria, I hope this find you well. I apologize again for this break-in to our schedule, but just wanted to highlight this 2nd well that failed recently on 1H-104 in the attached. We’ve actually gone faster than I thought we would on the 1H-103 well we’re on now, and could be start moving to this well (1H-104) sometime tomorrow it appears. Thanks. If you need anything else from me, please let me know. Scope is real similar to 1H-103 with a pull/replace 4.5” tubing with a downhole gauge. And thanks for expeditiously moving this through your team. Have a good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Sent: Monday, June 13, 2022 10:46 AM To: aogcc.permitting@alaska.gov Cc: Ward, Dusty K <Dusty.Ward@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: KRU 1H-104 (PTD 218-084) 10-403 RWO Hello, I have attached the 10-403 for KRU 1H-104 (PTD 218-084) RWO. Please let me know if you need any additional information. Thank you, Amy Amy A. Conklin Well Integrity Analyst ConocoPhillips Alaska 700 G Street, ATO 1307, Anchorage, AK 99501 Office: (907) 265-1484 Cell: (907) 841-2477 Amy.A.Conklin@conocophillips.com ! 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riginated: Delivered to:20-Jun-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1D-135 50-029-22816-00 n/a Kuparuk River Packer Setting Record Field- Final 9-Jun-22 0 12 1F-03A 50-029-20853-60 907799903 Kuparuk River Multi Finger Caliper Field & Processed 9-Apr-22 0 13 1H-103 50-029-23593-00 n/a Kuparuk River Leak Detect Log Field- Final 3-Jun-22 0 14 1H-103 50-029-23593-00 n/a Kuparuk River Leak Detect Log Field- Final 4-Jun-22 0 15 1H-103 50-029-23593-00 n/a Kuparuk River Multi Finger Caliper Field & Processed 3-Jun-22 0 16 1H-104 50-029-23610-00 n/a Kuparuk River Leak Detect Log Field- Final 6-Jun-22 0 17 1H-104 50-029-23610-00 n/a Kuparuk River Multi Finger Caliper Field & Processed 7-Jun-22 0 18 2M-33 50-029-22816-00 n/a Kuparuk River Packer Setting Record Field- Final 15-May-22 0 19 3R-107 50-029-23660-00 n/a Kuparuk River Packer Setting Record Field- Final 20-May-22 0 110PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date: ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 6, 2019 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7t' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Hollis French: a,9-0814 MAY 0 8 2019 AOGCV Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, ` Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10.404) Kuparuk Field Date 5/6/2019 Well Name API # PTD # Initial top of cement Vol. of cement purr ed Final lop of cement Cement top off date Corrosion inhibitor 1J & 1H Corrosion inhibitor/ sealant date ft bbls ft al 1J-180 50029233290000 2061500 20'9" 2.80 1'5" 5/4/2019 5 5/5/2019 1H-101 50029235850000 2171380 2'10" 0.70 9" 5/4/20192.2 5/5/2019 1H-102 50029235800000 2170970 2'9" 0.65 8" 5/4/2019 1.7 5/5/2019 1H-103 50029235930000 2180030 2'2.5" 0.45 9" 5/4/2019 2.2 5/5/2019 1 H-104 50029236100000 2180840 2.5" 0.40 9" 5/4/2019 2.2 5/5/2019 11-1-1086 50029236080200 2180820 3'8" 0.80 10" 5/4/2019 2.5 5/5/2019 1H-109 50029235950000 2180130 2'3" 0.40 9" 5/4/2019 2.2 5/5/2019 11-1-110 50029236010000 2180310 2'6.5" 0.65 8.5" 5/4/2019 2 5/5/2019 1 H-111 50029235810000 2171330 2' 0.35 9" 5/4/2019 2.2 5/5/2019 1H-113 50029235880000 2171680 2'1" 0.40 8" 5/4/2019 1.7 5/5/2019 1H-114 50029235840000 2171360 1'11" 0.25 7.5" 5/4/2019 1.8 5/5/2019 11-1-115 50029236050000 2180530 2'2.5" 0.35 8.5" 5/4/2019 2 1 5/5/2019 1 H-116 50029235940000 2180120 1'7" 0.25 7" 5/4/2019 1.7 5/5/2019 1H-117 50029236020000 2180320 0.35 7" 5/4/2019 1.7 5/5/2019 1H-118 50029235780000 2170840 2'4" 0.50 8.5" 5/4/2019 2 5/5/2019 1H-119 50029235910000 2171780 3' 0.80 8" 5/4/2019 1.8 5/5/2019 DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180840 Well Name/ No. KUPARUK RIV U WSAK 1H-104 Pg,j-r Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.029-23610.00-00 MD 16014 TVD 4025 Completion Date 9/18/2018 Completion Status 1-0I1 Current Status 1-0I1 UIC No REQUIRED INFORMATION / Mud Log No ✓ Samples No Directional Survey Yes V DATA INFORMATION List of Logs Obtained: GR/Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 29840 Digital Data 9426 11226 10/17/2018 Electronic Data Set, Filename: CPAI_1H- 104PB 1 _Scope_Resistivity_LW D003_RM_LAS.la s ED C 29840 Digital Data 103 1906 10/17/2018 Electronic Data Set, Filename: CPA[ _1H- 104PB 1_VISION_Resistivity_LW D001_RM_LAS.I as ED C 29840 Digital Data 1781 9514 10/17/2018 Electronic Data Set, Filename: CPAI 11-1- 104PB 1 _VI SION_Resistivity_LW D002_RM_LAS.I as ED C 29840 Digital Data 58 11226 10/17/2018 Electronic Data Set, Filename: CPAI_1H- 104PB 1_Scope_Resistivity_RM_LAS.las ED C 29840 Digital Data 10/17/2018 Electronic File: CPAI_1 1-1- 104PB7_VISION_Resistivity_RM_DLIS_LW D001 Alis ED C 29840 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104PB 1_VI SION_Resistivity_RM_DLIS_L W D001 .html ED C 29840 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104PB 1 _VI SION_Resistivity_RM_DLIS_LW D002 Allis ED C 29840 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104PB7_VISION_Resistivity_RM_DLIS_LW D002 .html ED C 29840 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104PB 1 _Scope_Resistivity_R M_DL IS_L W D003. this AOGCC Page I of 5 Friday, January 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180840 Well Name/No. KUPARUK RIV U WSAK 1H-104 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23610.00-00 MD 16014 TVD 4025 Completion Date 9/18/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 29840 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104PB 1 _Scope_Resistivity_RM_DLIS_L W D003. html ED C 29840 Digital Data 10/17/2018 Electronic File: CPAI 1H- 104PB 1 _Scope_Resistivity_DLIS_RM.dlis ED C 29840 Digital Data 10/17/2018 Electronic File: CPAI 1 H- 104PB 1_Scope_Resistivity_D LI S_RM. html ED C 29840 Digital Data 10/17/2018 Electronic File: CPAI 1H- 104PB 1 _Scope_Resistivity_2MD_RM. Pdf ED C 29840 Digital Data 10/17/2018 Electronic File: CPAI 1 H- _Scope_Resistivity_2TVD_RM.Pdf ED ED C 29840 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104PB1_Soope_Resistivity_5MD_RM.Pdf ED C 29840 Digital Data 10/17/2018 Electronic File: CPAI 1 1H- Scope_Resistivity_5T VD_RM.Pdf ED ED C 29840 Digital Data 10/17/2018 Electronic File: CPAI_IH-104PB1 Final Surveys.csv ED C 29840 Digital Data 10/17/2018 Electronic File: Gyrodata Survey - 1H-104 - Post SLB SAG.pdf ED C 29840 Digital Data 10/17/2018 Electronic File: 1H-104PB1 NAD27 EOW Compass Surveys [Canvas].txt ED C 29840 Digital Data 10/17/2018 Electronic File: 1H-104PB1 NAD27 EOW Compass Surveys [Macro].txt ED C 29840 Digital Data 10/17/2018 Electronic File: 11-1-1 D4PB1 NAD27 EOW Compass Surveys [Petrel].txt ED C 29840 Digital Data 10/17/2018 Electronic File: 1H-104PB1 NAD27 EOW Compass Surveys [Surveys].txt ED C 29840 Digital Data 10/17/2018 Electronic File: 1H-104PB1 NAD27 EOW Compass Surveys.pdf ED C 29840 Digital Data 10/17/2018 Electronic File: 1H-104PB1 NAD83 EOW Compass Surveys [Canvas].td ED C 29840 Digital Data 10/17/2018 Electronic File: 1H-104PB1 NAD83 EOW Compass Surveys [Macro].txt ED C 29840 Digital Data 10/17/2018 Electronic File: 1H-104PB1 NAD83 EOW Compass Surveys [Petrel].Ud ED C 29840 Digital Data 10/17/2018 Electronic File: 1H-104PB1 NAD83 EOW Compass Surveys [Surveys].txt AOGCC Page 2 of 5 Friday, January 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180840 Well Name/No. KUPARUK RIV U WSAK IH -104 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23610-00-00 MD 16014 TVD 4025 Completion Date 9/18/2018 Completion Status 1 -OIL Current Status 1-011- UIC No ED C 29840 Digital Data 10/17/2018 Electronic File: 1H-104PBI NAD83 EOW Compass Surveys.pdf Log C 29840 Log Header Scans 0 0 2180840 KUPARUK RIV U WSAK 1H-104 PB1 LOG HEADERS ED C 29843 Digital Data 9427 11226 10/17/2018 Electronic Data Set, Filename: CPAI 1H- 104_Scope_Resistivity_LW D003_RM_LAS.las ED C 29843 Digital Data 10750 16014 10/17/2018 Electronic Data Set, Filename: CPAI 1H- 104_Scope_Resistivity_L W D004_RM_LAS.las ED C 29843 Digital Data 103 1906 10/17/2018 Electronic Data Set, Filename: CPAI 11-1- 104_VISION_Resistivity_LW D001_RM_LAS.las ED C 29843 Digital Data 1781 9514 10/17/2018 Electronic Data Set, Filename: CPAI_1H- 104_VISION_Resistivity_LWD002_RM_LAS.Ias ED C 29843 Digital Data 103 16014 10/17/2018 Electronic Data Set, Filename: CPAI-11-1- ED ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI 1H- 104_VISION_Resistivity_RM_DLIS_LWDo01.dlis ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI 11-1- H- 1 I 104_VISION_Resistivity_RM_DLIS_LWD001.htm ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI 11-1- 104_VISION_Resistivity_RM_DLIS_LW D002.diis ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI 1H- 104_ VISION_Resistivity_RM_DLIS LWD002.htm ED ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI 1H- 104_Scope_Resistivity_RM_DLIS_L W 0003.diis ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI 1H- 104_Scope_Resistivity_RM_DLIS_LW D003.html li ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI 1H- 104_Scope_Resistivity_RM_DLIS_LWD004.this ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI 1H- _104_ScopeResistivity_RM_DLIS_LW D004.htm1 ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104_Scope _ Resistivity_DLIS_RM.dlis ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI 1H- 104_Scope_Resistivity_DLIS_RM.htm I AOGCC Page 3 of 5 Friday, January 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 1/18/2019 Permit to Drill 2180840 Well NamelNo. KUPARUK RIV U WSAK 1H-104 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23610-00-00 MD 16014 TVD 4025 Completion Date 9/18/2018 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI_1 H- 104_Scope_Resistivity_2MD_RM.pdf ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI 1H- 104_Scope_Resistivity_2TVD_above_90_deg_R M.pdf ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI 1H- 104_ Scope_Resistivity_2TVD_RM.pdf ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI_1 H- 104_Scope_Resistivity_51VID_RM.pdf ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI_1H- 104_Scope_Resistivity_5TVD_above_90deg_RM .pdf ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI_1 H- 104_Scope_Resistivity_5TVD_RM. pdf ED C 29843 Digital Data 10/17/2018 Electronic File: Gyrodata Survey - 1 H-104 - Post - SLB SAG.pdf ED C 29843 Digital Data 10/17/2018 Electronic File: 11-1-104 NAD27 EOW Compass Surveys [Canvas].txt ED C 29843 Digital Data 10/17/2018 Electronic File: 1H-104 NAD27 EOW Compass Surveys [Macro].txt ED C 29843 Digital Data 10/17/2018 Electronic File: 1H-104 NAD27 EOW Compass Surveys [Petrel].txt ED C 29843 Digital Data 10/17/2018 Electronic File: 1H-104 NA027 EOW Compass Surveys [Surveys].txt ED C 29843 Digital Data 10/17/2018 Electronic File: 1H-104 NAD27 EOW Compass Surveys.pdf ED C 29843 Digital Data 10/17/2018 Electronic File: 1H-104 NAD83 EOW Compass Surveys [Canvas].txt ED C 29843 Digital Data 10/17/2018 Electronic File: 11-1-104 NAD83 EOW Compass Surveys [Macro].t# ED C 29843 Digital Data 10/17/2018 Electronic File: 1H-104 NAD83 EOW Compass Surveys [Petrel].txt ED C 29843 Digital Data 10/17/2018 Electronic File: 1H-104 NAD83 EOW Compass Surveys [Surveys].txt ED C 29843 Digital Data 10/17/2018 Electronic File: 1H-104 NAD83 EOW Compass Surveys.pdf ED C 29843 Digital Data 10/17/2018 Electronic File: CPAI_1 H-1 04—Final Surveys.csv AOGCC Page 4 of 5 Friday, January 18, 2019 DATA SUBMITTAL COMPLIANCE REPORT 111 812 01 9 Permit to Drill 2180840 Well Name/No. KUPARUK RIV U WSAK 1H-104 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23610.00-00 MD 16014 TVD 4025 Completion Date 9/18/2018 Completion Status 1-0I1 Current Status 1 -OIL UIC No Log C 29843 Log Header Scans 0 0 2180840 KUPARUK RIV U WSAK 11-1-104 LOG HEADERS Well Cores/Samples Information: Name INFORMATION RECEIVED, Completion Report lY 1 Production Test Information q NA Geologic Markers/Tops0 COMPLIANCE HISTORY Completion Date: 9/18/2018 Release Date: 8/1/2018 Description Comments: Compliance Reviewed B' Interval Start Stop Directional / Inclination Data 'y Mechanical Integrity Test Information Y / NA Daily Operations Summary D Date Comments Sample Set Sent Received Number Comments Mud Logs, Image Files, Digital Data Y / 1A Composite Logs, Image, Data Files V Cuttings Samples y/16 Core Chips Y Core Photographs Y / Laboratory Analyses Y /; A AOGCC Page 5 of Friday, January 18, 2019 STATE OF ALASKA ALASKA Oil ANn rAS CnNCFRVATInN cnnnnnlceinni - ------- - - - ----......._ .. 1 a. Well Status: COMPLETIIOSPLUG❑N OR RECOMPLETIONended ❑ REPORT AND,L oil ❑ ❑ Other ❑ Abandoned ❑ 20AAC 25.105 20MC 25.110 Development 0 Exploratory ❑ GINJ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test E] 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 9/18/2018 14. Permit to Drill Number/ Sundry: 218-084 ° 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: .8/6/2018 15. API Number: 50-029-23610-00-00 4a. Location of Well (Governmental Section): Surface: 5201' FNL, 772' FEL, Sec 28, T12N, R10E, UM Top of Productive Interval: 1779' FNL, 4138' FEL, Sec 35, T12N, RIDE, UM Total Depth: 2100' FNL, 3916' FEL, Sec 26, T12N, R10E, UM 8. Date TO Reached: -8/21/2018 16. Well Name and Number: KRU 1H-104/1H-104PBI 9. Ref Elevations: KB:92.71 GL:54.1 BF: 17. Field / Pool(s): Kuparuk River FieldlWest Sak Oil Pool 10. Plug Back Depth MD/TVD: 11227/4057 18. Property Designation: ADL25639, ADL 25638 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 549569 y- 5980782 Zone- 4 TPI: x- 556779 y- 5978975 Zone- 4 Total Depth: x- 556957 y- 5983935 Zone- 4 11. Total Depth MD/TVD: 16014/4025 19. DNR Approval Number: 80-261, 931695000 12. SSSV Depth MD/TVD: NIA 20. Thickness of Permafrost MD/TVD: 1738/1646 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: NIA (ft MSL) 21. Re-drill/Lateral Top Window MDfrVD: N/A 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 23. CASING, LINER AND CEMENTING RECORD CASING AMOUNT WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD FT TOP BOTTOM TOP BOTTOM PULLED 20 94 L-80 40 118 40 118 42 Existing cement to surface 10314 45.5 L-80 40 1899 40 1777 13112 885 sx 11.0ppg Class G 12 Onnii Clags G 75/8298.0 29.7 L-80 37 9493 37 4086 97/8 1401 sx 15.8ppg Class G 41/2 12.6 L-80 8445 15994 3837 4026 63/4 Slotted Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @ 9704-15994 MD and 4090-4026 TVD .... 8/24/2018 ;Cr�II- MUS 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4 112 8051 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: 9/29/2018 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Nate of Test: 10/6/2018 Hours Tested: 14hrs, 7min. Production for Test Period Oil -Bbl: 2181 Gas -MCF: 56919 Water -Bbl: Choke Size: - Gas -Oil Ratio: 261 Tubing 340psi-12=: Casinq Calculated 24 -Hour Rate Oil -Bbl: 7 Gas -MCF: 96 Water -Bbl: 2 Oil Gravity -API (torr): 1 407 Revised 5/2017/j q �ONTI U ON PAGE 2 _/ (rTL le Z ( f� RBDMS M(T Cir � bmit ORIGINIAL only/-. 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, Fromrro), 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 Surface Surface Permafrost - Base 1738 1646 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 9493 4085 information, including reports, per 20 AAC 25.071. Formation @ TPI -West Salk A3 UGNU; C 5657 3128 WEST SAK D 8165 3794 WEST SAK C 8472 3852 WEST SAK B 8582 3878 WEST SAK A4 8711 3919 WEST SAK A3 8853 3970 WEST SAK A2 9290 4065 1H-104PB1 TD 11227 4057 TD 16014 4025 Formation at total depth WEST SAK A3 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, results.paleontoloaical repo[j. production or well test AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.1L,. Authorized Name: G.L. Alvord Contact Name: Scott Brunswick Authorized Title: Alaska Drilling Manager Contact Email: -9coft.A.Brunswickocbp.com Authorized // Contact Phone: 263-4249 (r7 J2 6 Signature: . L., Date: 1 e a / 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 results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only msula¢d Conductor Cuing, 20",94x, K35 x 34".0.312" WT 2 N-134' MD 10.3/4".4554. 480, Hyd5631 1899' MD / 1]]T ND -3 �5 2 Slacked Baker Hook Hanger an Level Junction Syssems Wellhead /Tubing Head/Tree, 13-3re" x 4-'/.^. 5,000 ,ii ZXP Packets � IH -I 1 IL2: 8012'MDJ IH -104 LI: 82]I'MD 375" DB Nipple P.M. 8101 MD 4-0". 116 x. L-80IBT-M the; Lift Mandrel, 4-12" x I" w/ SOV 2500' MD Gm Lift Mmidrtl. 4 -IR" x I" w/dummy valve 5]32' MD 1H-104 Producer Schematic Final aa -completed Gu Lift Mandrel, 412" x 1' w/dummy valve 1164' MD 4.W' SSD wiN 3 812" DB NiMic profile 1T)9' MD Pmmumnl Dmm Hok Gauge XA — 7%7' MD Turing Scal Asxmbly !� idiiw MD Lateral Eau, Module i Tubing SealAmmbly 3.562" DP Nipple Profilc 8439' MED IZXP poker_ 8444' MD a 7-5/8", 22700, 480, H>ffi63, Calk an 9493' MD/ 4091' TVD Loh Machine, @ 816]' MD 13795' TVD 43/4N Ocited IciD/3864'TVD Lower Lobe Window @ 8334' MD / 3816' TVD 6.3/4'D/BseM 2Skpcd Liner and Blank pipe 126x"It TXP/IBTM 15972'MDI Slol4d Llncrar BIaN:Plea 126#TXP/SLHTL80 113/4` ALA, send at KUP PROD 1H-104 Moc Well Attribut Mex Anglq )TConoeoPhilhpsD.In orn WellEoreAPuuW wellWres m: MOIL "IBtmmnAlaska, InCWEST SAK SDO]92`SNfll PROD ]59 1d 5fl9110 1fi 0108 114-10C 10'16'20183'.94'.4] PM Last Tag VxByxlemaEc(.n Mlnota[ion LAST TAG: En00ale OepN lrlKB) Last Moo By jennalt _.................._.._........................ ....__._.............................. TUBING HANGER n.e Last Rev Reason .......................... ... .. ............ Annse,E1M Ooh Last Mn4 By REV REASON: New Multilal, Installed Gas Lin Design 8 Pulled RHC912&2018 jennaX DUSmlCasing Strings Casinp pe: nplmn oO(in) lO lint Top ln6el BN Broui RN., Set oeplll(ND'... wuun(I Gme Top Threat 78UNF�E; 0 a1195 CONDUCTOR 20 1912 404 118.5 118.5 9400 L-80 Welled Casinp Desingron OD(in) ID(in) TopimB) BN DepN1 MS) SetOeon1TV.1-age". N... Grade Top TM1reatl SURFACE 10 ON 995 4031,8991,20].4 45.50 LA0 Hydril 563 Casinpdesorlptbn ODXnI ID(in) Top rytltel SM CepN ryd(01 SN Depthr(NDI.. WNlen 11 Grate Top Throng al.esc.3 INTERMEDIATE 7518 8.88 31.5 9,4932 4,0862 2970 L,80 Hyd 563 Living Oercriplion Ggni ID lin) Top IRK.) iH Deper MKS) SN DapN INOt.. YN4n (L.. GrenR Top ThrneaO Goes Un: 2520.9 SLOTTED LINER(MAIN WELLBORE) 14 12 3.96 8444.9 15,9938 4,025.8 12.60 U80 SLHT Liner Details Nominal lD GAS LIFL; S.]%8 Top l8,4 TapIN Top l790 Ibm on Cam Ilni 8,464.9 3840) 3,840.4 79.03 NIPPLE Baker ackoff Seat Nipple]# L 4.880 Gook LIP]: 7,18).s Hyd 563 box x box 73 3841.0 7893 HANGER Baker x -Lock Liner hanger P#L-8 4.800 SLIDING SLEEVE: T,ew.I Hyd 563 Pin x On 84775 3.8427 7862 SBEOaer 4. eat ore xmnsion, 5 10E 4.750 Hyd 563 box x pin 8,49]1 3,846.9 7782 W S5"Bid 563 15.5 # box x 5' 12 6#TMP-pin 3970 REDUCING Crossover LDCPTOR; B.@13 i ,718.1 4,0962 91.79 L er . " D well acker O N: 52 1- 3940 PACKE.IaMv sEALASSY:e... PACKER 21 BBE: S.1 11, 1 3 4,0933 88.99 LL Baker . "OD Swell Packer#5() IN 1- 3 N CROSSOVER G(0) BUSHING. a Sai PACKER 32 wCSI.7 1RIPPLE CONNECTT BUSHING, 9459.. 11,585.5 4,0766 92 .81 W LL PACKER Baker ER well Packer #4 1 N:051- 5 3.940 TRIPPLECONNECTBUaNIHE. 9,H0.0 11,944.0 4.0479 9483 W LL Baker "OD well Packer#( ) SN: 0 15- 3,950 13SUOTEDLNERO.D. PACKER 18 a1S341Swo 135747 4.0088 9199 W LL EIBM= Swell Parker #2 (B) N: 1 3,970 PACxER; ErTi3 .....I, PACKER 20 CROSS OVER (M) BUSHING, 139044 4,0139 82.07 W LL Baker 60' OD Swell Packer#1 (A)SN'. 054009-010- 3.940 4310. TRIPPIE CONNECT BUSHING: PACKER 14 am. TRIPPLE CONNECTBUGHUNNGO Tubing Strings Tubing Oeecnptlan ilrinp Ma... TUBING- 4112 D (In) 3.9fi 11 Top INNIS 326 Sen DeWR 11S. 8050.8 DepM (ND) I- 3,764.1 (BradGnetle 12.60 L40 Top Conn.... IBT-m LI... LINER IL1k e.3xaIESS4.7 PRODUCTION Completion Details Top IND) Topl Nominal TopdKB) IRKS) ('ncl I Ifem Des Co. ID (in) 7803 1 37114 ]6.30 bUDINLi 4-112' Sliding Sleeve, IBT-m, 3.812 CMU, RHC Plug wl DS Lock 3,812 SLEEVE 7.971.6 3,7490 7843 GAUGE 11T Solid SENIOR Mandrel, NDPG,single SEUge,R 0l 50 3.898 gauge,TXP-m 8021.3 3,7586 79.13 LOCATOR Baker 19247 locator"at assembly OD 5. "Larger ODabove 3.870 located INTERMEDNTFIT.as,1902 8,0230 3,759.0 79.16 SEALASSY Baker 1047 locator seal assembly wlmule shoe -below located 3.870 Mandrel inserts n jF[ra1�j .on N reMKIEU Top(nKBI IRK.) Make Model OO(M) V.M LarchTgoo po(In) T(psnn $ew Type Type (In) (p54 Pon Dale Com 1 2,5239 2.1906 Cam. KBMG 1 GAS LIFT GLV BK 0.186 1,455.0 912712018 2 5,736.8 3.149.3 Cam. KBMG 1 GAS LIFT GLV BK 0.188 1,467.0 9ID2018 3 7,1635 3,554.3 Cam. KBMG 1 GASLIFT OV BK 0.313 0.0 92712018 Notes: General & Safety Ertl Dane I An.ri 1011112018 1.111'. View Schemalic.Ala.k.SChemadc109 SLOTTED LINER (SAN WELLBORE): AM4 15.A8.7 KUP PROD lw- Well Attribut ConocoPF►illiPs PlelINme — Alaska.lnc. " WEST 6AK 1 H -104L1 IN -1041', harica 89:S0'.4a PM Last Tag Vawlvlsn&(ecbd) Annodlbn LAST TAG: End Date Cepid(we) LnL Mao By lennall ........... ...._.__.. ................._. Last Rev Reason TUBING INNOER; ala .................................. .... ....... An.n Ena Dad LnLmod BY .............................................._........... ... .. ............ REV REASON Film Mulbut, Installed Gas Lift Design 8 Pulled RHC 9SMg018 lannad lua ml Casing Strings cesln9 Deunption oO "al I-ng r-P(BRa) Bamepin NtKle Set Deph"O"). wuLon (I_.Grade nln Top Td LI SLOTTED LINER ILI) d12 3.96 83290 15,934) 3,916.9 12.60 L-80 IBT-m Liner Details coxoucrOR.a<1ms komdMl. Tupmae) Tdp WD)(dHe) ToPlxlr) IYm Des Com pnl 8,329.0 3,815.4 79.36 HANGER Baker"B-3" Flanged book hanger, .5"XTEYInsie 5.620 casing BDRFACE: se Bl.1 8.3484 3,8187 8135 HANGER a er'B-3 Fae,scbookhal.1,4.SX7. "'B W 834834- MD 3990 GASUPT;$5mg 8,4486 3,8276 88.26 WELL PACKER a er Swel Packer#7 "OW BN: 054 010.15 3958 184008 3.901 a 8679 TWOUL Baker OD Swell Packer "CC' 8N: 54 3958 PACKER 010.10 GAs pr, s,Tasa 10,6516 ,915.4 85.49 TWEL a r wet acker rt5 "8B" N:0 7- 3.956 PACKER 01023 10,8113 3,93. 81.43 WELL aker well Packer N4 "AA" SN: 054 3958 GAS UPT; TAaLs PACKER 01 02 5 11,1766 3,972.5 87 WELL Baker 6 W OD Sevell Packer d3 "F" SM 054009- 3.958 SUDINGSLEEvE?.9001 PACKER 010-16 13,6450 3,949.8 8 12 WELL Baker 6 W OD Sewell Packerp 'E" SN: 054009- 3.958 PACKER 010-24 13,830.1 3.971.0 48 WELL Baker 6 W OD SUCH Packers "0" SN: 054009- 3.958 PACKER 010-1 LOCATOR: 8.mtz Tubing Strings rubm9 DexNpdon $'ring ma_. mgnl TOP RKER Set Death BL.&el made MD) I.. WL gbY6 Gnd. Top Connenllon PACKER:461v .Ea-ASGY;S.m29 LI LEMIZXPLINER 4112 3.96 8271.4 8,490.5 3,086 1260 L-80 TXP-m BTC SBE; B=.7 TOP PACKER CROSSOVER (XOR BUSHING: 9.649 Completion IBgOn DBtalls Top AVD) TOpeal Nominal TOp IN(B) I.KBI I') IMM Des Com ID (in) NIPPLE; Alm? 8,2714 IPACKER Baker ZXP liner Top Packer 5.5"x763',5-1/P'H563 4.920 TWPPLE CONNECT BUSHING: 8,291.2 SEE Baker 19047 Seal Bore Extension, 5la 4750 al. TRIPPLECONNECT BUSHING; 8,310.8 3,8120 7926 URO ER Reducing Crossover sub 51/,'Hyd 563 X4-117 TXP 3.%0 e.tmo (XO) BUSHING IS SLOTTED LINER(Us 61m41SB CTO 8,325.8 3,814.8 79.34 Baker4.5" x 7. "LEM M Above Hook anger k 1 290791 3.700 CONNECT -02 BUSHING likeesR: a.n1a Stiff. 1.2 i 8,329.0 3,8154 79.36 Baker 45-. 763"LEM N1 (Below HODk Hanger@83211 ) 3,688 CROSS OVERlxo) BUSHING: CONNECT a,3ma BUSHING TRIPPLE CONNECT BUSHING: 8,4399 3,82.3 87.92 NIPPLE amc64-12"x3563"DBE Nipple, TXP.m SNp 523-2 3.563 9,4a2 INTERMEDNTE N S9 . 8,487.3 3,828.5 89 W SEAL A SY a er 19047 GBH- , 4- I ', L- Iraigbt on- ocaling Seal 3890 TRIPPLE CONNECT BUSHING: e.sm.o Assy Motes: General d Safety End care I .'Wlpn 1011112018 NOTE View Schematic Al Alaska Bcbemaac100 HIPPIE; 8.0.49 SEMASSY; 84072 LI SLOTTED UNER BN; KUP PROD 1H-1O4L2 —m_c4; IxdQWESTSAK Well Attribut Max Angle TD CaioeoPhIIII NName WeII reAPVOW WeIIMre Sbtus MO(M1 Ant B[m China Alaska. 1110. 500292361061 PROD n6.28 12.329 UU 15,6370 1H.1wLz.lmaale aw:ae vM Last Tag vnraslanl+ma4c 1ac0e6 Annoblbn LAST TAG: Entl Oah 0.oninvo B) j lmLast MlOO By ...............__............. _.....__...... Last Rev Reason rvarvc WWGERI us Annohtlon EM Dab LaN Mge By ............ ---------'-"' ------ --------- REV REASON'. New MUI81a1, Installed Gas Lift Design & Pulled RHC 9282018 jenn.11 SCSI Casing Strings ............................................................... .............. Gasmg Descenalon OO lip ft)(m) TO MB.) Bel CepKyrtitel R1 Digood) WBLen g...Orade TOPTh , SLOTTED LINER(12) 0112 396 6.162.9 15,827.0 3,868.6 12.60 L410 MT -m Liner Details Nominan0 Topockt) mp IWO)take) rePbd(•1 Ihm Dea Com (in) 81162.9 3,184.6 79.39 MANGER 99ker' ' ' Flanged hook hanger, ' X 7.6Y Inside 5.6M CONDUCTOR) ki am, 8,182.3 3,7879 81.15 HANGER Baker' -Flanged hook burger,.5" X 7. - B W 3.990 8180.65MD 8,281.9 3,]9]4 88.86 WELL a er 0' OD Swell Packer# 'MM' 71,170-078-1 3.958 PACKER 001-9 suRFAca:aal,eEea 13,819.6 3,881 78.58 SWELL BIAGI Swell Pacxerp "LL" SN'. 00893 3.958 PACKER 001-15 13,921.4 3],902.0 8670 WELL Baker. 00 Swell Packerp' 5-N-701893- 3958 OASUFTgaas PACKER 001-10 Tubing Strings Tubing Descrp" svbP Ma... ID M) TOPI2KBI sa Dagn tn_$ eL DelNn (TVD11... wlflattl Braae roP eonnmtbn 1-2 LEM/ZXPLINER 4112 3.96 8.012.> 8.302.0 3.79]6 12.60 L-80 TXP-M TOP PACKER GAS LIFT, Seal! Completion Details Top nVD) ougg. Nominal Top(MBI Bear I.I Item Gas Com to (in) 8,012.7 PACKER Baker ZXP Liner Top Packer 5.5'x763",5 -1)2'H563 CAM QUELP7:],16]s 8,01 SBE Baker 19047 Seal Some Extension, SIa' 4.750 8.0523 GROSSO Reduan9 Crossover sub 5'5'Hyd 563 X 4-12'TXP 3950 (XO) BUSHING BLIDINO sLEEVE; T.BWe 8,100.7 NIPPLE Cannot, 4-12'%3]50"DSA Nipple, TXP-m SN#4053-1R 3,750 8,1598 3,784.0 7936RI PLE Baker4. "x7. 'LEM#1 Above Hook hanger IT 1062903M 3.700 CONNECT -02 BUSHING 8,163.0 3,784.6 7939 TRIPPLE Bllahal5"x)63'LEM#1 (Below Hook Hanger@8162.90) 3.688 CONNECT BUSHING 8,298.7 3,797.6 90.15 EAL AS Y Salo r 19041 BH- - ", L Straight on oca ingreal-3.070 LOCATOR: e.03v3 PACKER. BM27 ABsy Notes: General & Safety sEUAupr. e0aa E B. :::::End Dah AnnohLion CROSSOVER PPI 16111/2016 NOTE'.View $chemalic wl Alaska SChema1ic10.0 S.R NIPREB111J7 TRIPPLE CONNECT BUSHING: Ser INTERMEDNTE:3].58.a4.R TRIPPLE CONNECT BUSHING. State 6EALAs6Y.GM7 -2 SLGIIED LINER BU: 0162.&1S. a Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Shat Depth start Time End Time Our (hr) Phase Op Code Activity Cade Time P -T -X Operation (flKB) End Depth (eKB) 8/5/2018 8/5/2018 11.00 MIRU MOVE MOB P Move Rig F11 H-1 08B - T/ 1 H-1 04 0.0 0.0 09:00 20:00 Rig release F/1 H-1088 at 09:00 Rig accepted on 1 H-104 at 20:00 8/5/2018 8/5/2018 2.00 MIRU MOVE RURD P Make up surface riser to Diverter 0.0 0.0 20:00 22:00 annular, Obtain RKB Measurements, Take on remaining fluid to pits, Dress shakers. 8/5/2018 8/5/2018 0.50 MIRU MOVE BOPE P Perform surface diverter test, Koomey 0.0 0.0 22:00 22:30 drawdown, Test of 1-12S, & Gas alarms done Sim -Ops. Tested Gain loss alarms for pits, Flow alrms and trip tank alarm. Witness to test waived by AOGCC Rep Bob Noble. 8/512018 8/5/2018 1.00 MIRU MOVE SFTY P Held Pre -Spud Meeting with all 0.0 0.0 22:30 23:30 personnel &Table top diverter drill. 8/5/2018 816/2018 0.50 MIRU MOVE SHAH P Pick up bit, Motor, crossover and 1 0.0 0.0 23:30 00:00 stand HWDP. Prior to filling surface stack with spud mud. 8/6/2018 8/6/2018 2.00 MIRU MOVE BHAH P Make Up BHA and tag at 95' MD, Fill 0.0 118.0 00:00 02:00 lines and hole, Check for leaks. Pressure test mudline to 3,500 psi. Clean out conductor to 11 8'MD (RKB) 8/6/2018 8/6/2018 1.75 SURFAC DRILL DDRL P Drill 13-1/2" Surface interval F/ 118' 118.0 224.0 02:00 03:45 MD - T/ 224' MD 224' TVD. 450 gpm, 480 psi, 28% flow out,40 rpm, 2 k. torque,bit wt. 7-8k. Off bottom 400 psi. Up 57k. down 57k. Rot 57k. 1 k torque off bottom, Max gas = 0, AST = 0. Art =1.25, Bit hrs. 1.25, Jar hrs. 25.78. 8/6/2018 8/6/2018 2.25 SURFAC DRILL BHAH P Rack back 2 stands HWDP, Make up 224.0 224.0 03:45 06:00 remaining BHA. 8/6/2018 8/6/2018 6.00 SURFAC DRILL DDRL P Drill 13-1/2" Surface interval F/ 224' 224.0 606.0 06:00 12:00 MD - T/ 606' MD 605' TVD. 450 gpm, 845 psi, 31% flow out,60 rpm, 4 k. torque,bit wt. 20k. Off bottom 675 psi. Up 74k. down 79k. Rot 79k. 21k torque off bottom, Max gas = 0, AST = 2.06. Art =1.83, Bit hrs. 3.89, Jar hrs. 29.12. 8/6/2018 8/6/2018 6.00 SURFAC DRILL DDRL P Drill 13-1/2" Surface interval F/ 606' 606.0 1,148.0 12:00 1800 MD - T/ 1,148' MD 1,126' TVD. 550 gpm, 1,430 psi, 32% flow out,60 rpm, 5k. torque,bit wt. 30k. Off bottom 1,200 psi. Up 89k. down 89k. Rot 89k. 2k torque off bottom, Max gas = 0, AST = 1.21. Art =2.47, Bit hrs. 7.52, Jar hrs. 32.80. 8/6/2018 8/7/2018 6.00 SURFAC DRILL DDRL P Drill 13-1/2" Surface interval F/ 1,148' 1,148.0 1,815.0 18:00 00:00 MD - T/ 1,815' MD 1,709' TVD. 550 gpm, 1,520 psi, 36% flow out,60 rpm, 6k. torque,bit wt. 30k. Off bottom 1,286 psi. Up 99k. down 94k. Rot 95k. 2k torque off bottom, Max gas = 7,500 Hydratess at 1,375' MD+/ - AST = 1.75. Art =2.47, Bit hrs. 11.79, Jar hrs. 37.02. Page 1136 Report Printed: 9/24/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Depth Sten Time Entl Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (f KB) 8/712018 8/7/2018 0.50 SURFAC DRILL DDRL P Drill 13-1/2" Surface interval F/ 1,815' 1,815.0 1,906.0 00:00 00:30 MD - T/ 1,906' MD 1,783' TVD. 550 gpm, 1,520 psi, 36% Flow out,60 rpm, 6k. lorque,bit wt. 30k. Off bottom 1,286 psi. Up 99k. down 94k. Rot 95k. 2k torque off bottom, Max gas = 7,500 Hydrates at 1,375' MD+1- AST =.44. Art =.07, Bit hrs. 12.3, Jar hrs. 37.53. 8/7/2018 8/7/2018 0.25 SURFAC CASING OWFF P Monitor well, static. 1,906.0 1,906.0 00:30 00:45 8/7/2018 8/7/2018 3.50 SURFAC CASING BKRM P BROOH f/ 1906'-863' MD, 550 gpm, 1,906.0 863.0 00:45 04:15 1350-1150 psi, 60 rpm, FO 34%, Tq 2- 4K. BROOH 1st stand pumping a BU. BROOH last 2 stands pumping a BU. 8/7/2018 8/7/2018 0.25 SURFAC CASING OWFF P Monitor well, static. 863.0 863.0 04:15 04:30 8/7/2018 8/7/2018 3.00 SURFAC CASING SHAH P Lay down BHA 1 f/ 863'-O' MO as per 863.0 0.0 04:30 07:30 1 1 SLB DD. 8/7/2018 8/7/2018 0.50 SURFAC CASING BHAH P Clear & clean dg Floor. 0.0 0.0 07:30 08:00 8/7/2018 8/7/2018 1.75 SURFAC CASING RURD P Pick up & dg up GBR casing 0.0 0.0 08:00 09:45 equipment; CRT, link extensions, slips & elevators. SIMOPS download & remove BHAH shed, load shoe track & verify pipe count. 8/7/2018 8/7/2018 1.00 SURFAC CASING PUTS P Makeup shoe track to 161' MD, 0.0 161.0 09:45 10:45 Bakerl-ok first 3 connections & torque to 19.4K, install 2 bow spring centralizer 10' Nom each end on first 2 joints. Fill & check floats, good. 8/7/2018 8/7/2018 5.00 SURFAC CASING PUTS P Continue running 10-3/4", 45.5 #, L- 161.0 1,855.0 10:45 15:45 80, Dopeless Hydril 563 casing f/ 161'- 1855' MD, PU 115K, SO 92K, Tq Connections to 19.4K, install bow spring centralizers on each collar. Ran a total of 46 bow spring centralizers & 4 stop collars. 8/7/2018 8/7/2018 0.50 SURFAC CASING HOBO P Make up hanger & landing joint f/ 1,855.0 1,899.3 15:45 16:15 1855'-1899' MD, washing down at 1 bpm, 120 psi, FO 4%, SO 92K. 8/7/2018 8/7/2018 1.25 SURFAC CEMENT CIRC P Circulate & Condition mud for 1,899.3 1,899.3 16:15 17:30 cementing staging up the pump to 7 bpm, 160 psi, FO 20%, PU 119K, SO 108K. 8/7/2018 817/2018 0.50 SURFAC CEMENT RURD P Blow down top drive & dg up cement 1,899.3 1,899.3 17:30 18:00 lines to CRT. 8/7/2018 8/7/2018 1.50 SURFAC CEMENT CIRC P Circulate & condition mud for 1,899.3 1,899.3 18:00 19:30 cementing staging up the pump to 7 bpm, 289 psi, FO 20%, PU 119K, SO 108K. SIMOPS PJSM for cementing. Page 2/36 Report Printed: 9/24/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Terse our (hr) Phase Op Code Activfly Code Time P -T -X Operation (ftKB) End Depth(ftKB) 8/7/2018 8!7/2018 4.00 SURFAC CEMENT CMNT P Pump 5 bbis of CW100 & PT lines to 1,899.3 0.0 19:30 23:30 4000 psi, good. Pump 35 bbis of CW100 at 4.8 bpm, 120 psi. Pump 80 bbis of 10.5 ppg MPII at 4 bpm, 115 psi. Drop bottom plug. Pump 300.9 bbls of 11.0 ppg Lead cement at 6 bpm, 175 psi. Observed bottom plug bump w/ 179 bbls away. Observed MPII at surface at 265 bbis away. Pump 67 bbis of 12.0 ppg Tail cement at 6 bpm, 270 psi. Drop top plug. Pump 10 bbis of fresh H2O at 5 bpm, 150 psi. Swap to dg & pump 165.1 bbis of 9.5 ppg spud mud to bump plug. Observe good 11.0 ppg cement back w/ 75 bbl mud pumped. Landed on hanger w/ 80 bbis of mud pumped. Pressure up to 784 psi & hold for 5 minutes. Check floats, good. CIP 23:22 hrs. Total of 109 bbis of 11.0 ppg lead cement to surface. 8/7/2018 8/8/2018 0.50 SURFAC CEMENT PRTS P Pressure test 10-314" casing. Pump 0.0 0.0 23:30 00:00 2.9 bbis, pressuring up at 5 spm to 3250 psi. Shut in & observed pressure for 30 minutes ISP 3250 & FSP 3195 psi bled back 2.7 bbls. - 8/8/2018 8/8/2018 3.00 SURFAC CEMENT RURD P Rig down cementing & casing running 0.0 0.5 00:00 03:00 equipment. Drain cement from stack & flush w/ black water. Clean out cementing valves. Clean out cellar box. 8/812018 8/8/2018 3.00 SURFAC CEMENT NUND P Remove flow riser, disconnect diverter 0.0 0.0 03:00 06:00 line, remove surface annular, diverter lee & starting head. Prep casing hanger for well head. 8/8/2018 8/8/2018 3.00 SURFAC WHDBOP NUND P Pick and set wellhead as per GE Rep. 0.0 0.0 06:00 09:00 Confirm alignment w/ Lounsbury. Nipple up wellhead annulus valves. 8/8/2018 8/8/2018 0.25 SURFAC WHDBOP PRTS P Test seal between casing hanger & 0.0 0.0 09:00 09:15 wellhead to 2000 psi for 10 minutes, witnessed by CPAI Rep. 8/8/2018 8/8/2018 2.75 SURFAC WHDBOP NUND P Nipple up DSA & spacer spool. Pick & 0.0 0.0 09:15 12:00 set BOP stack. Torque all flanged connections. Install choke & kill lines. 8/8/2018 8/8/2018 3.75 SURFAC WHDBOP SVRG P Make up potato masher & pup joint. 0.0 0.0 12:00 15:45 Change out annular element. 8/8/2018 8/8/2018 1.25 SURFAC WHDBOP RURD P Install test plug, rig up test equipment 0.0 0.0 15:45 17:00 & flood lines. Page 3136 ReportPrinted: 9124/2018 Operations Summary (with Timelog Depths) 111-104 I& Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StertTime End Time our (hr) Phase op Code Ac" rode Time P -T -X Operation (ftKB) End Depth mKB) 8/8/2018 8/8/2018 4.50 SURFAC WHDBOP BOPE P Test BOPE w/ 4", 4-1/2", & 7-5/8" test 0.0 0.0 17:00 21:30 joints to 250/3500 psi for minutes each charted. Test choke valves 1-14, upper & lower IBOP, 4" & 4-1/2" dart valves, 4" & 4-1/2" FOSV, lower VBR's w/ 4" & 4-1/2" TJ, Blind rams, upper 7- 5/8" rams, annular w/ 4" & 7-5/8" TJ, manual kill & choke valves, HCR kill & choke valves, 2 kill in line Demco valves. Test manual & super choke 250/2000 psi & show bleed down. Accumulator draw down initial system pressure 2900 psi, after functioning 1850 psi, 200 psi recovery in 9 seconds, full in 48 seconds. Nitrogen bottles 6 @ 2000 psi. Tested gas detection system, flow & pit level indicators. Test witnessed waived by AOGCC Rep Brian Bixby. 8/8/2018 8/8/2018 0.50 SURFAC WHDBOP RURD P Remove test plug & install wear 0.0 0.0 21:30 22:00 bushing. Blow down & rig down test equipment. 8/8/2018 6/8/2018 1.00 SURFAC CEMENT BHAH P Make up BHA 3, 9-7/8" assembly as 0.0 378.0 22:00 23:00 per SLB DD to 378' MD. 818/2018 8/9/2018 1.00 SURFAC CEMENT TRIP P TIH f/ 378'-1706' MD, PU 90K, SO 378.0 1,706.0 23:00 00:00 79K. 8/9/2018 819/2018 0.25 SURFAC CEMENT CIRC P Fill pipe & SHT tools, 520 gpm, 800 1,706.0 1,706.0 00:00 00:15 psi. 8/9/2018 8/9/2018 0.25 SURFAC CEMENT PRTS P Line up & test OA valve to 3000 psi for 1,706.0 1,706.0 00:15 00:30 5 minutes, good. Blow down lines. 8/9/2018 8/9/2018 0.50 SURFAC CEMENT TRIP P TIH f/ 1706'-1813' MD, tagging top of 1,706.0 1,813.0 00:30 01:00 plugs on the float collar. 819/2018 8/9/2018 4.00 SURFAC CEMENT DRLG P Drill out shoe track & rat hole it 1813'- 1,813.0 1,906.0 01:00 05:00 1906' MD, 450 gpm, 715 psi, 60 rpm, Tq 3-51K, WOB 2-10K, PU 90K, SO 86K, ROT 86K. 8/9/2018 6/9/2018 0.25 SURFAC CEMENT DDRL P DDrill 9-7/8" intermediate section f/ 1,906.0 1,926.0 05:00 05:15 1906'-1926' MD, 1799' TVD, 524 gpm, 926 psi, FO 35%,80 rpm, Tq 5K, WOB 4K, ECD 10.13, OFF BTM 910 psi, PU 91 K, SO BOK, ROT 87K, Tq 2K, Max gas 0, ADT .17, Bit .17, Jars 97.77, Total footage 20'. 8/9/2018 8/9/2018 1.25 SURFAC CEMENT CIRC P Pull inside shoe& circulate for FIT at 1,926.0 1,926.0 05:15 06:30 650 gpm, 1337 psi, 50 rpm, Tq 2-41K, MW 9.6 ppg 8/9/2018 8/9/2018 0.50 SURFAC CEMENT FIT P Rig up & perform FIT at 1899' MD, 1,926.0 1,926.0 06:30 07:00 1777' TVD to an EMW of 12.0 ppg, w/ 9.6 ppg spud mud. Pump .5 bbl to 230 psi. Shut in & record pressure for 10 minutes ISIP 220 psi, FSIP 180 psi. Bled back .4 bbl. Rig & blow down test equipment. 8/9/2018 8/9/2018 5.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 1,926.0 2,498.0 07:00 12:00 1926'-2498' MD, 2179' TVD, 650 gpm, 960 psi, FO 33%,160 rpm, Tq 3.5K, WOB 13K, ECD 9.89, OFF BTM 950 psi, PU 94K, SO 84K, ROT 88K, Tq 2K, Max gas 103, ADT 3.12, Bit 3.12, Jars 100.72, Total footage 572'. SCR @ 1968' MD, 1833' TVD, MW 9.0 ppg, 08:05 hm #1 @ 30 = 100 psi, @ 40 = 120 psi #2@30=90 psi, @40= 110psi Spill Drill CRT 2:10, 11:00 hrs Page 4136 Report Printed: 9124/2018 Operations Summary (with Timelog Depths) 111-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth stint Tim End Time Dur (hr) Phase Op Code Activit/ Code Tim P -T -X Operation (fti(B) End Depth (111<8) 8/9/2018 8/9/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 2,498.0 3,324.0 12:00 18:00 2498'-3324' MD, 2467' TVD, 650 gpm, 1040 psi, FO 32%,150 rpm, Tq 7K, WOB 15K, ECD 9.87, OFF BTM 1030 psi, PU 105K, SO 73K, ROT 87K, Tq 4K, Max gas 126, ADT 4. 11, Bit 7.23, Jars 104.83, Total footage 826'. 8/9/2018 8110/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" inlemtediate section f/ 3,324.0 4,311.0 18:00 00:00 3324-4311' MD, 2742' TVD, 650 gpm, 1170 psi, FO 32%, 170 rpm, Tq 8K, WOB 20K, ECD 10.0, OFF BTM 1162 psi, PU 109K, SO 78K, ROT 92K, Tq SK, Max gas 35, ADT 4.03, Bit 11.26, Jars 108.86, Total footage 987'. SCR @ 3511' MD, 2516' TVD, MW 9.0+ ppg, 19:05 hrs #1 @ 30 = 140 psi, @ 40 = 170 psi #2 @ 30 = 130 psi, @ 40 = 160 psi 8/10/2018 8/10/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 4,311.0 5,107.0 00:00 06:00 4311'-5107' MD, 2974' TVD, 650 gpm, 1376 psi, FO 32%, 140 rpm, Tq 11 K, WOB 20K, ECD 10.22, OFF BTM 1350 psi, PU 127K, SO 70K, ROT 94K, Tq 7K, Max gas 33, ADT 3.98, Bit 15.24, Jars 112.84, Total footage 796'. 8/1012018 8/10/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 5,107.0 5,806.0 06:00 12:00 5107'-5806' MD, 3170' TVD, 650 gpm, 1600 psi, FO 32%,140 rpm, Tq 11K, WOB 20K, ECD 10. 18, OFF BTM 1580 psi, PU 128K, SO 73K, ROT 96K, Tq 9K, Max gas 33, ADT 3.76, Bit 19.0, Jars 116.6, Total footage 699'. SCR @ 5601' MD, 3113' TVD, MW 9.2 ppg, 10:45 hrs #1 @ 30 = 200 psi, @ 40 = 220 psi #2 @ 30 = 200 psi, @ 40 = 220 psi 8/10/2018 8/10/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 51806.0 6,458.0 12:00 18:00 5806'-6458' MD, 3357' TVD, 650 gpm, 1532 psi, FO 32%,140 rpm, Tq 10K, WOB 15K, ECD 10.06, OFF BTM 1530 psi, PU 130K, SO 77K, ROT 103K, Tq 8K, Max gas 151, ADT 4.16, Bit 23.16, Jars 120.76, Total footage 652'. SCR @ 6553' MD, 3383' TVD, MW 9.1 ppg, 19:15 hrs #1 @ 30 = 240 psi, @ 40 = 280 psi #2 @ 30 = 220 psi, @ 40 = 260 psi 8/10/2018 8/11/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 6,456.0 7,028.0 18:00 00:00 6458'-7028' MD, 3518' TVD, 650 gpm, 1581 psi, FO 32%,140 rpm, Tq 10K, WOB 15K, ECD 10.27, OFF BTM 1550 psi, PU 147K, SO 81 K, ROT 107K, Tq 8K, Max gas 61, ADT 4.21, Bit 27.37, Jars 124.97, Total footage 570'. 8/11/2018 8/11/2018 6.00 INTRMI DRILL DDRL P DDrill 9-718" intermediate section f/ 7,028.0 7,556.0 0000 0600 7028'-7556' MD, 3656' TVD, 650 gpm, 1698 psi, FO 32%, 150 rpm, Tq 11 K. WOB 15-22K, ECD 10.27, OFF BTM 1690 psi, PU 148K, SO 80K, ROT 104K, Tq 9K, Max gas 34, ADT 3.89, Bit 31.27, Jars 128.86, Total footage 530'. Page 5136 Report Printed: 9/24/2018 Operations Summary (with Timelog Depths) 11-1-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Dept, Stan Tune End Time Dur (M Phase op Code Aclivxy Code mma P -T -X operation (WB) End Depth (W13) 8/11/2018 8/11/2018 6.00 INTRM7 DRILL DDRL P DDrill 9-7/8" intermediate section f/ 7,556.0 8,028.0 06:00 12:00 7556'-8028' MD, 3769' TVD, 650 gpm, 1770 psi, FO 32%,160 rpm, Tq 12K, WOB 20-23K, ECD 10.42, OFF BTM 1732 psi, PU 149K, SO 78K, ROT 108K, Tq 6K, Max gas 106, ADT 4.05, Bit 35.31, Jars 132.91, Total footage 530'. Spill Drill CRT 2 min @ 08:00 hrs SCR @ 7598' MD, 3672' TVD, MW 9.1 ppg, 07:00 hrs #1 @ 30 = 240 psi, @ 40 = 280 psi #2 @ 30 = 240 psi, @ 40 = 280 psi 8/11/2018 8/11/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 8,028.0 8,360.0 12:00 18:00 8028'-8360' MD, 3828' TVD, 650 gpm, 1764 psi, FO 33%,150-120 rpm, Tq 12K, WOB 3-22K, ECD 10.37, OFF BTM 1772 psi, PU 150K, SO 70K, ROT 107K, Tq 9K, Max gas 210, ADT 3.58, Bit 38.89, Jars 136.49, Total footage 332'. 8/11/2018 8/12/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermetliate section f/ 8,360.0 8,605.0 18:00 00:00 8360'-8605' MD, 3885' TVD, 650 gpm, 1836 psi, FO 33%,150-120 rpm, Tq 13K, WOB 3-22K, ECD 10.4, OFF BTM 1800 psi, PU 153K, SO 72K, ROT 112K, Tq 11 K, Max gas 39, ADT 2.92, Bit 41.81, Jars 139.41, Total footage 245'. SCR @ 8549' MD, 3865' TVD, MW 9.0 ppg, 21:30 hrs #1 @ 30 = 280 psi, @ 40 = 320 psi #2 @ 30 = 280 psi, @ 40 = 320 psi 8/12/2018 8/12/2018 6.00 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 8,605.0 9,090.0 0000 06:00 8605'-9090' MD, 4031' TVD, 650 gpm, 2000 psi, FO 33%,140-120 rpm, Tq 13K, WOB 8-25K, ECD 10.68, OFF BTM 1862 psi, PU 162K, SO 75K, ROT 113K, Tq 11 K, Max gas 29, ADT 3.69, Bit 45.5, Jars 143.10, Total footage 485'. 8/1212018 8/12/2018 5.50 INTRMI DRILL DDRL P DDrill 9-7/8" intermediate section f/ 9,090.0 9,514.0 06:00 11:30 9090'-9514' MD, 4100' TVD, 650 gpm, 1942 psi, FO 33%,150 rpm, Tq 13K, WOB 8-25K, ECD 10.65, OFF BTM 1944 psi, PU 154K, SO 75K, ROT 108K, Tq 1OK, Max gas 226, ADT 2.88, Bit 48.38, Jars 145.98, Total footage 424'. Kick w/ Drilling Drill CRT 1:44 @ 08:00 hrs. 8/12/2018 8/12/2018 1.25 INTRMI CASING CIRC P Circulate CBU at 650 gpm, 1944 psi, 9,514.0 9,414.0 11:30 12:45 FO 33%, 100 rpm, Tq 10K. Obtain final survey & SCR. SCR @ 9512' MD, 4099' TVD, MW 9.2 ppg, 12:30 hrs #1 @ 30 = 340 psi, @ 40 = 380 psi #2 @ 30 = 330 psi, @ 40 = 380 psi 8/12/2018 8/12/2018 0.50 INTRM7 CASING OWFF P Monitor well, static. 9,414.0 9,414.0 12:45 13:15 8/12/2018 8/12/2018 4.75 INTRMI CASING BKRM P Backream out of hole f/ 9414'-7792' 9,414.0 7,792.0 13:15 18:00 MD, 700 gpm, 2195 psi, FO 35%,120 rpm, Tq 1OK, ECD 10.85, Max Gas 530 psi, PU w/ reaming 100K. Page 6136 Report Printed: 912412018 Operations Summary (with Timetog Depths) 1H-104 I& Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Scan Depth Sten Time End Tim Our (hr) Phase Op Cade AaOvky Code Time P-T-X Opener n (111<13) End Depth (flKB) 8/12/2018 8/13/2018 6.00 INTRMI CASING BKRM P Backream out of hole f/ 7792'-4970' 7,792.0 4,970.0 18:00 00:00 MD, 700 gpm, 1800 psi, FO 35%, 120 rpm, Tq 9K, ECD 10.82, Max Gas 84 psi, PU w/ reaming 90K. 8/13/2018 8/13/2018 6.75 INTRMI CASING BKRM P Backream out of hole laying down DP 4,970.0 1,890.0 00:00 06:45 f/ 4970'-1890' MD, 700-600 9pm, 1127 psi, FO 35%,120-80 rpm, Tq 4K, ECD 10.85, PU wl reaming 81 K. 8/13/2018 8/13/2018 1.25 TNTRMI TiRG P Circulate hole dean @ 750 gpm, ICP 1,890.0 1,890.0 06:45 08:00 1431 psi, FCP 1384 psi, FO 34%,70 rpm, Tq 3K, ECD 9.91, PU 88K, SO 83K, ROT 86K. 8/13/2018 8/13/2018 0.50 INTRMI P Monitor well, static. 1,890.0 1,890.0 08:00 08:308/13/2018 8113/2018 0.25 INTRMI CIRC P Pump dry job & blow down TD. 1,890.0 1,890.0 08:30 08:458/13/2018 8/13/2018 125 INTRMI rCASINGOWFF TRIP P TOH f/ 1890'-378' MD. 1,890.0 378.0 08:45 10:008/13/2018 8/13/2018 200 INTRMI BHAH P Lay down BHA 3 as per SLB DD. 3780 0.0 10:00 12:00 Bit Grade 4,5,BTA,X,I,CTTD 8/13/2018 8/13/2018 1.00 INTRMI SHAH P Clear BHA & clean dg floor. 0.0 0.0 12:00 13:00 8/13/2018 8/13/2018 1.00 INTRMI CASING W W WH P Make up stack wash tool & flush stack 0.0 0.0 13:00 14:00 @ 850 gpm, 150 psi. Lay down tool & make up bushing tool. Remove wear bushing & lay down tools. 8/13/2018 8/13/2018 1.00 INTRMI CASING KURD P Rig up GBR casing handling 0.0 0.0 14:00 15:00 equipment. 8/13/2018 8/13/2018 1.00 INTRMI CASING PUTB P PJSM, make up 7-5/8", 29.7 #, L-80, 0.0 174.0 15:00 16:00 Hydril 563 dopeless casing shoe track to 174' MD, Bakerl-ok connections to pin end of #5, Tq to 14K, floats checked good. 8/13/2018 8/1312018 3.25 INTRMI CASING PUTB P Continue RIH wl7-5/8", 29.7 #, L-80, 174.0 1,899.0 16:00 19:15 Hydril 563 dopeless casing shoe 174- 1899' MD, connections Tq to 14K, fill pipe on the fly, top off every 10 for displacement, install centralizers installed free floating. 8/13/2018 8/13/2018 0.75 INTRMI CASING CIRC P Circulate rasing volume at the shoe 1,899.0 1,899.0 19:15 20:00 reciprocating pipe, 3.5 bpm, 100 psi, PU 93K, SO 90K. 8/13/2018 8/13/2018 2.50 INTRMI CASING PUTB P Continue RIH w/ 7-5/8", 29.7 #, L-80, 1,899.0 3,650.0 20:00 22:30 Hydril 563 dopeless casing shoe 1899 -3650' MD, connections Tq to 14K, fill pipe on the fly, lop off every 10 for displacement, install centralizers installed free floating. 8/13/2018 8/13/2018 1.00 INTRMI CASING CIRC P Circulate casing volume, reciprocating 3,650.0 3,650.0 22:30 23:30 pipe, staging pump up to 4.5 bpm, 185 psi, PU 118K, SO 95K. 8/13/2018 8/1412018 0.50 INTRMI CASING PUTB P Continue RIH w/ 7-518", 29.7 #, L-80, 3,650.0 4,028.0 23:30 00:00 Hydril 563 dopeless casing shoe 3650'-4028' MD, connections Tq to 14K, fill pipe on the fly, top off every 10 for displacement, install centralizers installed free floating. 8/14/2018 8/14/2018 3.50 INTRMI CASING PUTB P Continue to RIH with 7 5/8" 29.7#, L- 4,028.0 6,116.0 00:00 03:30 80 563 Dopless casing as per detail from 4,028' MD - 6,115' MD Fill on fly every 10 and TO connections to 14K FT/LB. Page 7136 Report Printed: 912412018 Operations Summary (with Timelog Depths) 11-1-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth start Time End Time Dur Ihn Phase Op Cod. Acbviy Code Time P -T -X Operation (111(13) End Depth (flKB) 8/14/2018 8/14/2018 1.25 INTRM1 CASING CIRC P Circulate casing volume while rec from 6,116.0 6,116.0 03:30 04:45 6,116' MD - 6,085' MD. stage pumpe to 7 BPM @ 364 PSI UP WT = 152K, DWN WT = 93K. total stks pumped = 2,800. 8/14/2018 8/14/2018 6.00 INTRMI CASING PUTB P Continue to RIH with 7 518" casing as 6,116.0 9.461.0 04:45 10:45 per detail from 6,115' MD - 9,461' MD. Fill pipe every ten. TO all connections to 14K. Work past obstruction at 9,320' MD with 4 BPM @ 483 PSI DPP. UP WT=200K. DWN WT= 77K. 8/14/2018 8/14/2018 0.25 INTRMI CASING HOBO P MU hanger and landing joint. Wash 9,461.0 9,503.0 10:45 11:00 down @ 2 BPM 424 PSI DPP.12% F10. DWN WT = 65K. 8/14/2018 8/14/2018 3.00 INTRMI CEMENT CIRC P Recip pipe from 9,483' MD - 9,503' 9,503.0 9,503.0 11:00 14:00 MD while staging up pumps to 6 BPM @ 369 PSI DPP. FCP = 454 PSI DPP. 20%F10 UP WT=200K DWN WT= 77K. pumped 9,961 STKS. . 8/14/2018 8114/2018 4.00 INTRMI CEMENT CMNT P PJSM and RU cement hose PT lines 9,503.0 9,493.2 14:00 18:00 to 4,000 PSI. (PASSED). Reciprocate pipe from 9,503' MD - 9,488' MD. UP WT=211K. DWNWT=IOIK. PUmp 41.3 BBLS MP If. @ 3 BPM 312 PSI, 12% F/O. Drop BTM Plug pump 250 BELS of 15.8# class G cement stage up pumps to 6 BPM with ICP 400 SI. FCP 270 PSI. 22% F/O. Drop top plug and chase with 10 BBLS H2O. followed with 9.2 PPG treated LSND @ 7 BPM icp 161 PSI, Obsereve DWN WT to 50K — 10' high. Attempt to free pipe with no success. UP WT = 228K, DWN WT = 98k. continue to pump 7 BPM with FCP 1,265 PSI. teduce rate to 3 BPM @ 4,025 slits. ICP 1,175 PSI. FCP 1,320 PSI. Bump plug with 422 STKS. CIP @ 1730 firs. Increase pressure to 1,853 PSI and hold for 5 min. Bleed off and check floats. Holding. 8/1412018 8/15/2018 6.00 INTRMI CEMENT WOC T WOC. Prep stack for nipple down. 9,493.2 9,493.2 18:00 00:00 BD and remove cement hose. Clean up cementing egiupment and valves. PU subs and prep for upcomming BHA chnage over. Load and tally 4" DP. 8/15/2018 8/1512018 5.00 INTRMI CEMENT WOC T WOC. Prepare stack for ND. RD 9,493.2 9,493.2 00:00 05:00 Volant / install 150T elevators, flean out cement valves. Load and tally 4" DP. Sim ops clean. 8/15/2018 8/1512018 1.00 INTRMI CEMENT NUND T Drain stack / Break flange to hoist / 9,493.2 9,493.2 05:00 06:00 1 release air from boots. 8/15/2018 8/15/2018 5.00 INTRMI CEMENT RURD T Hoist stack and penetrate 2' above 9,493.2 9,493.2 06:00 11:00 flange for drainage. Clean and prep for emergency slip install. PU to 200K on indicator and install slips as per GE rep. Install Wachs cutler and cut casing as per GE rep. 8115/2018 8/15/2018 1.00 INTRMI CEMENT CUTP T LD landing joint and cut 7 518" casing, 9,493.2 9,493.2 11:00 12:00 1 elevators and casing hand slips. 8/15/2018 8/15/2018 1.00 INTRMI CEMENT WWSP P MU 4 1/2" landing joint with X/0, and 9,493.2 0.0 12:00 13:00 packoff running tool. Set 10 3/4' X 7 5/8" Packoff as per GE rep. Page 8136 ReportPrinted: 912412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log scan Dept, Start Time End Time Dur (M Phase Op Corte Acwfty Code Tiro P-T-X Operation (ftKB) End Depth (11K8) 8/1512018 8/15/2018 1.00 INTRMI CEMENT NUND P NU BOP stack and change out saver 0.0 0.0 13:00 14:00 sub to 4" XT39 dimops. 8/15/2018 811512018 0.50 INTRM1 CEMENT PRTS P Witness packoff test to 3,832 PSI for 0.0 0.0 14:00 14:30 10 min /(PASSED). Tm 8/15/2018 8/15/2018 0.50 INTRM1 CEMENT RURD P Install wear bushing of 9" plus run 0.0 0.0 14:30 15:00 LDS X2 8/1512018 8/15/2018 1.75 INTRMI CEMENT SHAH P PJSM for PU 6 3/4" BHA#3 as per 0.0 336.0 15:00 16:45 SLB rep.to 336' MD UP WT = 51 K DWN WT = 57K. Sim-ops with LRS for FP of 10 3/4" X 7 5/8" arm with 100 BBLS fresh / 80 BBLS diesel. Pressure break over at 900 PSI. Average rate of 3 BPM 7-800 PSI. 8/15/2018 8/16/2018 7.25 INTRM1 CEMENT TRIP P Trip in hole with 4" DP from 336' MD 336.0 7,788.0 16:45 00:00 to 7,788' MD. UP WT = 145K DWN WT = 62K. Monitor disp via TT. 811612018 8/16/2018 2.00 INTRMI CEMENT TRIP P Continue to RIH with 6 T/4 "BHAon 4" 7,788.0 9,300.0 00:00 02:00 DP from 7,778' MD - 9,300' MD. UP WT=162K, DWN WT=60K Monitor disp via TT. 8/16/2018 8116/2018 0.75 INTRM1 CEMENT PRTS P Rig up to pressure test 7 5/8" casing. 9,300.0 9,300.0 02:00 02:45 Pump 6 BBLS to achieve 3,680 PSI hold and chart for 30 min. Lost 5 PSI iin 30 min. (PASSED). bleed off total 6.2 BBLS. 8/16/2018 8/16/2018 3.00 INTRM1 CEMENT DRLG P Ream down and drill out shoe track 9,300.0 9,514.0 02:45 05:45 assym. 220 GPM @ 1,170 PSI. 50 RPM 9K TQ. UP WT = 155K, DWN WT = 53K. 1O RT. top of plug found at 9,397.5' MD. 8/16/2018 8/16/2018 0.25 INTRM1 CEMENT DDRL P Drill 6 314" hole from 9,514' MD - 9,514.0 9,534.0 05:45 06:00 9,534' MD 4,086' TVD. 220 GPM 1,660 PSI, 18% Flo, 80 RPM 11K TO, 8K WOB, OB 1,600 PSI. UP WT = 155K, DWN WT = 53K. ROT 102K, 9K TQ, Max gas units 0. ADT .16, Bit hm .16, Jar HRS 43 8/1612018 8/16/2018 1.00 INTRM1 CEMENT CIRC P Rotate and circulate from 9,453' MD - 9,534.0 9,534.0 06:00 07:00 9,450' MD. 240 GPM @ 1,655 PSI. 16% F/O, 40 RPM 11 K TQ, UP QT = 170K, DWN WT= 52K, ROT 102K, pumped 2,872 STKS. 8/16/2018 8/1612018 1.25 INTRM1 CEMENT FIT P STD back strict 97, RU for FIT / @ 9,534.0 9,534.0 07:00 08:15 4,091' TVD. 13.1 EMW achieved at 16 STKS pumped 800 PSI with 9.3 PPG test mud 8/16/2018 8/16/2018 0.25 PROD1 DRILL RURD P RD test equipment. 9,534.0 9,534.0 08:15 08:30 8/16/2018 8/16/2018 0.50 PROD1 DRILL SVRG P Grease top drive / PM / service saver 9,534.0 9,534.0 08:30 09:00 and air slips. 8/16/2018 8116/2018 1.25 PROD1 DRILL DISP P Swap hole over to 9.2 PPG Flo-Pro, 9,534.0 9,534.0 09:00 10:15 pump 20 BBL high vis sweep 250 GPM @ 1,940 PSI. 17% F/O. 40 RPM 10K TQ. ECD 10.76. 1,683 FCP. UP WT= 134K DWN WT= 85K. Page 9136 Report Printed: 912412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time Dur (ho Phase Op Code Act vity Code Time P -% Operation (flKB) End Depth (flKB) 8/16/2018 8/16/2018 7.75 PROD1 DRILL DDRL P Drill 6 3/4" hole from 9,534' MD 4,086' 9,534.0 10,112.0 10:15 18:00 TVD - 10,112' MD 4,097' TVD. 260 GPM @ 1,811 PSI, 19% F/0, 130 RPM 7K TO, 3K WOB, OB 1,808 PSI, UP WT = 137K, DWN WT = 75K. ROT 103K, 5K TO, Max gas units 86. ADT 5.37, Bit firs 6.8, Jar HRS 48.37 SPR's 9,532' MD 4,087' TVD MW = 9.2 PPG HR 10:15 MP-1) 20 SPM-420 PSI 30 SPM-580 PSI MP-2) 20 SPM-420 PSI 30 SPM-580 PSI 8/16/2018 8/17/2018 6.00 PROD1 DRILL DDRL P Drill6 3/4" hole from 10,112' MD 10,112.0 10,605.0 1800 00:00 4,097' TVD - 10,605' MD 4,095 TVD. 260 GPM @ 1,815 PSI, 19% F/0, 130 RPM 8K TO, 2-5K WOB, OB 1,810 PSI. UP WT=139K, DWN WT=71 K. ROT 101 K, 6K TQ, Max gas units 63. ADT 4. 10, Bit hrs 9.63, Jar HRS 52,47 SPR's 10,589" MD 4,095' TVD MW = 9.2 PPG HR 20:30 MP-1) 20 SPM-510 PSI 30 SPM-710 PSI MP-2) 20 SPM-550 PSI 30 SPM-790 PSI 8/17/2018 8/17/2018 6.00 PROD1 DRILL DDRL P Drill 6 3/4" hole from 10,605' MD 10,605.0 11,226.0 0000 06:00 4,095 TVD - 11,226' MD 4,052' TVD. 260 GPM @ 2,175 PSI, 19% F/O, 130 RPM 10K TO, 2-7K WOB, ECD - 11.96 OB 2,150 PSI. UP WT = 139K, DWN WT = 66K. ROT 99K, 8K TO, Max gas units 8. ADT 4.21, Bit firs 13.84, Jar HRS 56.68 8/17/2018 8/17/2018 1.50 PRODi DRILL BKRM T BKRM from 11,226' MD - 10,879' MD. 11,226.0 10,879.0 0600 07:30 250 GPM @ 2,027 PSI DPP. 18% F/0, 80 RPM, 61K TO. UP WT = 139K, DWN WT = 66K, ROT = 99 8/17/2018 8/17/2018 0.50 PROD1 DRILL PMPO T Pump OOH from 10879' MD - 10780' 10,879.0 10,780.0 07:30 08:00 MD at 250 GPM 1,925 PSI DPP, 8/17/2018 8/17/2018 4.00 PROD1 DRILL K-0—ST T Open hole side track. Work string 10,780.0 10,860.0 08:00 12:00 from 10,830' MD - 10,860 1,910 PSI 18% F/0, 150 RPM, 8K TO, UP WT w/pump = 99K. DWN = 95K. 8/17/2018 8/17/2018 2.00 PROD1 DRILL KOST T Open Hole side track as per DD. 10,860.0 10,860.0 12:00 14:00 Working string from 10,830' MD - 10,860' MD. 250 GPM @ 1,910 PSI DPP. 18% F/0, 150 RPM @ 8K TO, UP / DNW WT with pumps on 99 W95K. 8/17/2018 8/18/2018 10.00 PROD1---T0— RODiDRILL KOST T Open Hole side track as per DD. 10,860.0 10,874.0 1400 00:00 Working string from 10,860' MD - 10,874' MD. 250 GPM @ 1,829 PSI DPP. 19% F/O, 150 RPM @ 9K TO UP / DNW WT with pumps on 99K/95K. 8/18/2018 8/18/2018 6.00 PROD1 DRILL KOST T Continue to perform open hole 10,874.0 10,969.0 00:00 06:00 sidetrack time driling form 10,874' MD - 10,969' MD 250 GPM @ 1,875 PSI, 18% F/O, 150 RPM, 8K TO, UP WT = 129K, DWN WT=78K. ROT =100K, Max gas= 14 Page 10136 ReportPrinted: 9/24/2018 Operations Summary (with Timelog Depths) e 11-1-104 . ..• Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sran Depm ErWTlme Dv(hr) Phew Op code Activity Cade Time P -T -X Operation Mks) End Dept(KKB) 8/18/2018 3.00 PROD1 DRILL DDRL T Drill 6 3/4" hole fod 10,969' MD - 10,969.0 11,227.0 09:00 11,227' MD 4,104' TVD. @ 248 GPM, 2,051 PSI, 18% F/O, 125 RPM, 9.5K TO. 3.5K WOB, ECD = 11.07, OB = r20T188e 2,048 PSI, UP WT = 129K, OWN WT = 78K, ROT = t00K, 9K TO, Max gas = 340, ADT 6.44, Bit hrs 31. 1, Jar hrs 73.94. 8118/2018 2.00 PROD1 DRILL OWFF T Observe well for flow. Observe rise in 11,227.0 11,277.0 11:00 fluid at rotary table. SI well and monitor pressure. ISIDPP = 25 PSI, ISICP = 20 PSI Pbserve Iressure rise to 200 PSI SIDPP, 180 PSI SICP. Increase of 4BBLS to pits. ---1 —1,2-770 8/18/2018 8/18/2018 2.50 PROD1 DRILL KLWL T Circulate well around using drillers 11,277.0 11:00 13:30 method @ 3BPM, 1,080 PSI DPP Casing pressure peaked at 650 PSI during circulation with gas to surface. Pumped a total of 4,569 STKS. Rotated pipe for one min to ensure free. Talk with production folks and have them shut in 1H -News injection support. Talk with KRU operations about postponing bridge closure until well stabilized. Order out more KCL from MI. 8/18/2018 8/18/2018 4.00 PROD1 DRILL OWFF T Shut down pumps and SI casing to 11,277.0 11,227.0 13:30 17:30 monitor pressures and WT UP pits to new KW F based off new calcs. Maintain 200 PSI on Casing pressure. WT UP pits to 9.7 PPG with new calculations proving a 10.2 PPG needed. Went with 9.7 PPG for first circulation so crews could keep up with 30 SEC SX at 9.7. 8/18/2018 8/18/2018 2.75 PROD1 DRILL KLWL T Pump 9.7 PPG mud utilizing kill sheet 11,227.0 11,277.0 17:30 20:15 pump schedule. ICP = 1,016 PSI, FCP = 1,036 PSI. Maintain 200 PSI Casing pressure. Total stks pumped = 5,515. 8/18/2018 8/18/2018 0.75 PROD1 DRILL OWFF T Sl and monitor pressure while 11,277.0 11,277.0 20:15 21:00 weighing up to 10.2 PPG KWF in surface pits. SIDPP = 380 PSI, SICP = 240 PSI. Rotate for 1 min with 9K TO to break over and 5-8K TO stable. 8/18/2018 8/19/2018 3.00 PROD1 DRILL KLWL T Pump 10.2 PPG MW utilizing kill sheet 11,277.0 11,277.0 21:00 00:00 (drillers method), pump schedule. ICP = 970 PSI. CP = 919 PSI. Pump 5,605 STKS. MW in = 10.2 MW out = 10.1+, Rotate pipe at 10 RPM broke over at 8K TO. 8/19/2018 8/19/2018 0.50 PROD1 DRILL KLWL T 6,623 STKS pumped. MW in/out 10.2 11,277.0 11,277.0 00:00 00:30 PPG. Rotate pipe 10 RPM with 13K to break over - 8K TO 8/19/2018 8/19/2018 0.75 TRODI KLWL T Monitor pressure via choke and 11,277.0 11,277.0 00:30 01:15 confirm zero pressure. Open arm and monitor hole. 8/19/2018 8/19/2018 2.25 PROD1 DRILL CIRC T Circulate up 2X BU at 250 GPM, 80 11,277.0 11,277.0 01:15 03:30 RPM / ECD = 12.24 PPG, UP WT = 11 27K DWN WT= 85K. rot 102K. Page 11136 Report Printed; 912412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time Dur (hr) Phase Op Code Achvity Code Time P -T -X Operation (ftKB) End Depth(fKB) 8119/2018 8/19/2018 0.50 PROD1 DRILL OWFF T Monitor well for flow/blow down 11,277.0 11,277.0 03:30 04:00 choke / kill lines. Grease wash pipe. SPR's 11,255' MD 4,104' TVD, MW = 10.2 Time 0415 hrs MP 1) 20 SPM 570 PSI 30 SPM 780 PSI MP 2) 20 SPM 540 PSI 30 SPM 720 PSI 8/19/2018 8/19/2018 2.00 PROD1 DRILL DDRL P Drill 6 3/4" hole from 11,277' MD - 11,277.0 11,445.0 04:00 06:00 11,445 MD @ 250 GPM 2,090 PDI 19% F/0, 130 RPM 10K TO, 5K WOB, ECD's 12.1 PPG. OB 2,056 PSI UP WT = 137 DWN WT = 68K, ROt - 99K, 9K TO, Max gas 43 units 8119/2018 8/19/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 11,445' MD - 11,445.0 11,965.0 0600 12:00 11,965' MD 4,043' TVD 250 GPM @ 2,161 PSI DPP, 20% F/O, 150 RPM 1 OK TQ, ECD's = 12.34, OFF BTTM = 2,150 PSI, UP WT= 150K, DWN WT = 52K, ROT 102K, 10K TO Max gas = 227 units, ADT 5.07, Bit hrs 36.17, Jar hrs 79.07 8/19/2018 8/19/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 1,965' MD 11,965.0 12,605.0 1200 18:00 4,043' TVD - 12,605' MD 4,018 TVD 260 GPM @ 2,179 PSI DPP, 21 % F/0, 140 RPM 10K TQ, 1K WOB ECD's = 12.3, OFF BTTM = 2,150 PSI, UP WT = 146K, DWN WT = K, ROT 102K, 10K TO, Max gas = 2817 units, ADT 4.05, Bit hrs 40.22, Jar hrs 83.12 8/19/2018 8/20/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 12,605' MD 12,605.0 13,064.0 18:00 00:00 4,018 TVD - 13,064' MD 4,012' TVD 260 GPM @ 2,292 PSI DPP, 20% F/O, 140 RPM 10K TQ, 5K WOB ECD's = 12.37, OFF BTTM = 2,281 PSI, UP WT = 160K, DWN WT = K, ROT 104K, 1 OK TO, Max gas = 7780 units, ADT 3.37, Bit hrs 43.80, Jar hrs 86.7 SPR's 12,684" MD 4,015' TVD MW = 10.2 PPG HR 1841 MP -1) 20 SPM -530 PSI 30 SPM -730 PSI MP -2) 20 SPM -490 PSI 30 SPM -690 PSI 8/20/2018 8/20/2018 6.00 PROD? DRILL DDRL P DDRL 6 3/4" hole from 13,064' MD 13,064.0 13,812.0 0000 0600 4,012' TVD - 13,812 MD 3,994' TVD 260 GPM @ 2,478 PSI DPP, 20% F/0, 140 RPM 107K TQ, 5.51K WOB ECD's = 12.71, OFF BTTM = 2,495 PSI, UP WT = 172K, DWN WT = K, ROT 106K, 1 OK TO, Max gas= 235 units, ADT 3.85, Bit hrs 47.65, Jar hrs 90.55 Page 12136 Report Printed: 9/24/2018 e - Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Depth Stan Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (BKB) Ertl Depth (ftKB) 8/20/2018 8/20/2018 6.00 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 13,812 MD 13,812.0 14,454.0 06:00 12:00 3,994' TVD - 14,454' MD 4,084 TVD 260 GPM @ 2,840 PSI DPP, 19% F/O, 140 RPM 1 O TQ, 5K WOB ECD's = 12.92, OFF BTTM = 2,816 PSI, UP WT = 183K, OWN WT = K, ROT 118K, 10.51K TQ, Max gas = 235 units, ADT 3.65, Bit hrs 51.3, Jar hrs 94.2 SPR's 13,900" MD 4,084' TVD MW = 10.1+ PPG HR 0615 MP -1) 20 SPM -700 PSI 30 SPM -890 PSI MP -2) 20 SPM -710 PSI 30 SPM -900 PSI 8/20/2018 8/20/2018 6.00 PROD1 DRILL DDRL P DDRL 63/4" hole from 14,454' MD 14,454.0 14,940.0 12:00 18:00 4,084 TVD - 14,940 MD 4,040' TVD 260 GPM @ 2,690 PSI DPP, 20% F/O, 150 RPM 1 O TQ, 3K WOB ECD's = 12.75, OFF BTTM = 2,670 PSI, UP WT = 185K, DWN WT = K, ROT 122K, 1 OK TQ, Max gas = 235 units, ADT 3.9, Bit hrs 55.2, Jar hrs 98.1 8/20/2018 8/21/2018 6.00 PROD1 DRILL DDRL P DDRL63/4" hole from 14,940 MD 14,940.0 15,191.0 1800 00:00 4,040' TVD - 15,191' MD 4,031' TVD 260 GPM @ 2,794 PSI DPP, 20% F/O, 140 RPM 10.51K TQ, 2.7K WOB ECD's = 12.84, OFF BTTM = 2,791 PSI, UP WT = 189K, DWN WT = K, ROT 122K, 10.7K TQ, Max gas = 235 units, ADT 3.3, Bit hrs 58.5, Jar hrs 101.4 SPR's 14,917" MD 4,037' TVD MW = 10.2 PPG HR 1909 MP -1) 20 SPM -620 PSI 30 SPM -690 PSI MP -2) 20 SPM -640 PSI 30 SPM -680 PSI 8/21/2018 8/21/2018 6.00 PROD1 DRILL DDRL P DDRL 63/4" hole from 15,191'MD 15,191.0 15,648.0 00:00 06:00 4,031' TVD - 15,648' MD 4,029' TVD 250 GPM @ 2,605 PSI DPP, 19% F/O, 140 RPM 10.61K TQ, 2K WOB ECD's = 12.83, OFF BTTM = 2,578 PSI, UP WT= 195K, DWN WT= K, ROT 126K, 1 OK TO, Max gas = 78 units, ADT 4.44, Bit hrs 62.94, Jar hrs 105.84 8/21/2018 8/21/2018 4.75 PROD1 DRILL DDRL P DDRL 6 3/4" hole from 15,648' MD 15,648.0 16,014.0 06:00 10:45 4,029' TVD - 16,014" MD 4,022' TVD 250-230 GPM @ 2,525 PSI DPP, 19% F/O, 140 RPM 1 O TQ, 2-7K WOB ECD's = 12.87, OFF BTTM = 2,520 PSI, UP WT = 180K, DWN WT = K, ROT 127K, 1 OK TO, Max gas = 95 units, ADT 3.9, Bit hrs 66.84, Jar hrs 109.74 8/21/2018 8/21/2018 3.25 PROD1 CASING CIRC P Circulate and condition mud. Rotate 16,014.0 15,922.0 10:45 14:00 and reciprocate from 16,014' MD to 15,922' MD. 230 gpm, 2589 psi, 17% FO, 140 rpm, 81K tq, ECD=12.95 UP WT=175K, DWN WT = K, ROT 126K. Page 13136 Report Printed: 9/24/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth start Time End Time Dur(m) Phase Op Code AoOVity Cotle Time P -T -X Cranston (MB) End Depth(ftKB) 8/21/2018 8/21/2018 1.00 PROD1 CASING OWFF P Monitor well. Slight flow at.29 bph 15,922.0 15,922.0 14:00 15:00 diminishing to .14 bph. 8/21/2018 8/21/2018 3.00 PROD1 CASING BKRM P BROOH from 15,922' MD to 14,821' 15,922.0 14,821.0 15:00 1800 MD. 240 gpm, 2738 psi, 18% FO, 140 rpm, 8K tq, ECD=12.87. 6/21/2018 8/22/2018 6.00 PROD1 CASING BKRM P Continue to BROOH from 14,921' MD 14,821.0 12,774.0 18:00 00:00 to 12,774' MD. 240 gpm, 2274 psi, 16% FO, 140 rpm, 7.5K tq, ECD=12.57. OA=100 psi. 8/22/2018 8/22/2018 6.00 PROD1 CASING BKRM P Continue to BROOH from 12,774' MD 12,774.0 10,763.0 0000 0600 to 10,763' MD. 240 gpm, 2095 psi, 18% FO, 140 rpm, 7K tq, ECD=12.21. 8/22/2018 8/22/2018 3.00 PROD1 CASING BKRM P Continue to BROOH from 10,763' MD 10,763.0 9,445.0 0600 09:00 to 9,445'10D. 240 gpm, 2002 psi, 18% FO, 140 rpm, 7K tq, ECD=11.89. 8/22/2018 8/22/2018 3.00 PROD1 CASING CIRC P Circulate and condition mud. Rotate 9,445.0 9,445.0 09:00 12:00 and reciprocate from 9,445' MD to 9,357' MD, 220 gpm, 1738 psi, 15% FO, 80 rpm, 5K tq, ECD=11.80, UP WT= 120K 5/0 WT=88K ROT WT=97K. OA=95 psi 30 bbls loss previous 12 hrs. 8/22/2018 8/22/2018 2.75 PROD1 CASING CIRC P Circulate and condition mud. Perform 9,445.0 9,445.0 12:00 14:45 80% mud dilution. Rotate and reciprocate from 9,445' MD to 9,357' MD, 200 gpm, 1320 psi, 15% FO, 80 rpm, 4K tq, UP WT=120K SIO WT=88K ROT WT=97K. 8/22/2018 8/22/2018 0.75 PROD1 CASING OWFF P Monitor well. Slight flow at 1.19 bph 9,445.0 9,450.0 14:45 15:30 1 diminishing to .28 bph. 8/22/2018 8/22/2018 0.50 PROD1 CASING PMPO P Pump OOH from 9,450' MD to 9,262' 9,450.0 9,262.0 15:30 16:00 MD at 85 to 65 gpm with 415 psi. 7% FO 8/22/2018 8/22/2018 0.75 PROD1 CASING OWFF P Monitor well. Slight flow at .27 bph 9,262.0 9,262.0 16:00 16:45 diminishing to .13 bph. 8/22/2018 8/22/2018 1.00 PROD1 CASING MPSP P Make up and set Baker TST-3 9,262.0 0.0 16:45 17:45 retrievable packer. COE at 97.10' MD. UP WT=125K SO WT=80K 8/22/2018 8/22/2018 0.75 PROD1 CASING WWWH P Make up stack washing tool. Flush 0.0 0.0 17:45 18:30 BOPS with 900 gpm, 167 psi, 42% FO and 30 rpm. 8/22/2018 8/22/2018 0.50 PROD1 CASING MPSP P Test storm packer to 700 psi/10 mins 0.0 0.0 18:30 19:00 as per Baker Rep. 8/22/2018 8/22/2018 1.50 PROD CASING BOPE P Set test plug and change out upper 0.0 0.0 1900 20:30 pipe rams to 3 1/2" z 6" VBR's. 8/22/2018 8/22/2018 1.50 PROD1 WHDBOP RURD P Rig up to test BOPE. Purge air from 0.0 0.0 2030 22:00 system and perform shell test. Page 14/36 Report Printed: 9/24/2018 -, Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X operation (ftKB) EM Depth (NCB) 8/22/2018 8/232018 2.00 PROD1 WHDBOP BOPE P Perform bi-weekly BOPE test. 0.0 0.0 22:00 00:00 250/3500 psi- 5 min each. Following tests done with 4 1/2" test joint. Test #1-Annular,CV's 1, 12,13,14, 4" kill Demco, 4" dart valve. Test #2 -Upper 3 1/2" x 6" VBR, CV's 9, 11, mezzanine kill line valve, 4" FOSV. Test #3 -CV's 8,10, kill HCR. Test #4- CV's 6,7, manual kill line valve. OA=O psi. 8/23/2018 8/23/2018 3.00 PROW WHDBOP BOPE P Continue bi-weekly BOPE lest. Test 0.0 0.0 00:00 03:00 #5- Super choke and manual choke at 250/2000 psi. Test #6- CV's 2,5. Test #7- Lower 3 1/2" x 6" VBR. Test #8 - Blind rams, CV's 3,4,6. Following tests done with 4" test joint. Test #9 - Annular, upper IBOP, choke line HCR. Test #10- Upper 3 1/2" x 6" VBR, lower IBOP. Test #11- Lower 3 1/2" x 6" VBR. Accumulator draw down initial system pressure 2900 psi, after functioning 1800 psi, 200 psi recovery in 10 seconds, full in 48 seconds. Nitrogen bottles 6 @ 2025 psi. Tested gas detection system, flow & pit level indicators. Test witness waived by AOGCC Rep Lou Laubenstein. 8/23/2018 8/23/2018 0.75 PRODi WHDBOP RURD P Rig down test equipment. Set 9" IDr9,262.0 .0 0.0 03:00 03:45 j wear ring. 8/23/2018 8/23/2018 1.00 PROW CASING MPSP P Make up packer retrieval tool. Engage.0 9,262.0 03:45 04:45 packer and monitor for pressure up DP. Close annular preventer and release packer. Monitor for pressure through choke. 0 pressure, 0 flow. POOH and lay down storm packer. 8/23/2018 8/23/2618 3.25 PROD1 CASING CIRC P CBU x2. Rotate and reciprocate from 9,262.0 04:45 08:00 9,260' MD to 9,167' MD. 200 gpm, 1296 psi, 18% FO, 80 rpm, 5K tq, UP=125K, SO=80K, Rot=100K. 8/23/2018 8/23/2018 0.25 PROD1 CASING OWFF P Monitor well. Slight diminishing flow. 9,262.0 9,262.0 08:00 08:15 8/23/2018 8/23/2018 3.75 PRODt CASING PMPO P Pump OOH from 9262' MD to 6,590' 9,262.0 6,590.0 08:15 12:00 MD. 200 gpm, 1250 psi, 18% FO, UP=117K OA=45 psi 8/23/2018 8/23/2018 5.00 PROD? CASING PMPO P Continue to Pump OOH from 6,590' 6,590.0 3,088.0 12:00 17:00 MD to 3,088' MD. 200 gpm, 786 psi, 18% FO, UP=83K. 8/23/2018 8/23/2018 0.25 PROD1 CASING CIRC P CBU. 200 gpm, 786 psi, 18% FO. 3,088.0 3,088.0 17:00 17:15 8/23/2018 8232018 1.25 PROD1 CASING OWFF P Monitor well. Well flowing at 2 bph 3,088.0 3,088.0 17:15 18:30 1 diminishing to .178 bph. 8/23/2018 8/23/2018 0.75 PROD1 CASING PMPO P Continue to Pump OOH from 3,088' 3,088.0 2,684.0 18:30 19:15 MD to 2,684' MD. 150 gpm, 530 psi, 13% FO, UP=80K. 8/23/2018 8/23/2018 4.00 PRODi CASING PMPO P Continue to Pump OOH from 2,684' 2,684.0 336.0 19:15 23:15 MD to 336' MD. 84 gpm, 252 psi, 10% FO, UP=79K. 8232018 8/24/2018 0.75 PROD1 CASING OWFF P Blow down TD. Monitor well. Slight 336.0 336.0 23:15 00:00 flow at .66 bph diminishing to .27 bph. 8/24/2018 8/24/2018 0.25 PROD1 CASING owl P Continue to monitor well. Slight flow 336.0 336.0 0000 00:15 at .27 bph diminishing to .21 bph. Page 15136 Report Printed: 9/2412 01 8 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Oepm siert Time End Time our (i Phase Op Code Activity Code Time P-T-X Operation (fti End Depth (M<13) 8/24/2018 8/24/2018 1.25 PROD1 CASING BHAH P Stand back and lay down BHA as per 336.0 0.0 00:15 01:30 SLB DO. 8/24/2018 8/24/2018 0.50 PROD1 CASING BHAH P Clean and clear rig floor. 0.0 0.0 01:30 02:00 8/24/2018 8/24/2018 1.00 COMPZ1 CASING RURD P Rig up to run 4 1/2" slotted liner. Verify 0.0 0.0 0200 03:00 joint count in pipe shed. 8/24/2018 8/24/2018 9.00 COMPZI CASING PUTS P Pick up and RIH with L-80 12.6# 0.0 5,290.0 03:00 12:00 IBT/SLHT slotted liner as per detail to 5290' MD. PU=84K SOi 8/24/2018 8/24/2018 4.25 COMPZI CASING PUTB P Continue to pick up and RIH with L-80 5,290.0 7,491.0 12:00 16:15 12.6# IBT/SLHT slotted liner as per detail from 5290' MD to 7491' MD. PU=96K SO=72K 8/24/2018 8/24/2018 1.25 COMPZI CASING OTHR P Pick up Baker liner hanger/packer 7,491.0 7,562.0 16:15 17:30 assembly. Mix and pour pal mix. Verify pin settings. 8/24/2018 8/24/2018 0.25 COMPZI CASING CIRC P Pick up one stand of DP. Break 7,562.0 7,562.0 17:30 17:45 circulation staging pump up to 3 bpm, 186 psi, it% FO. PU=99K S0=75K 8/24/2018 8/24/2018 1.25 COMPZI CASING RUNL P RIH with 4 1/2" slotted liner on 4" DP 7,562.0 9,461.0 17:45 19:00 from 7562' MD to 9461' MD. Drop 2" drift on each stand. 8/24/2018 8/24/2018 0.25 COMPZI CASING CIRC P Break circulation. Stage pump up to 4 9,461.0 9,461.0 19:00 19:15 bpm, 347 psi, 12% FO, PU=114K 5O=79K 8/24/2018 8/25/2018 4.75 COMPZI CASING RUNL P Continue to RIH with 4 1/2" slotted 9,461.0 15,378.0 19:15 00:00 liner on 4" DP from 9461' MD to 15378' MD. Drop 2" drift on each stand. Work through tight hole at 10765' MD. PU=173K SO=79K OA=O psi. 6/25/2018 8/25/2018 0.75 COMPZI CASING RUNL P Continue to RIH with 41/2" slotted 15,378.0 16,019.0 00:00 00:45 liner on 4" DP from 15378' MD to 16019' MD. Drop 2" drift on each stand. PU=179K SO=85K. Tag TD at 89' in on stand #90 (16910' MD) 8/25/2018 8/25/2018 0.50 COMPZI CASING CIRC P Circulate DP volume of 80 bbls, 4 16,019.0 15,994.0 00:45 01:15 bpm, 875 psi, 14% FO. Space out to liner set depth. Observe PU increase to 225K without breakover and SO to block weight without breakover 8/25/2018 8/25/2018 1.25 COMPZI CASING PACK P Drop 1.625" setting ball and pump 15,994.0 8,445.0 01:15 02:30 down at 3 bpm, 600 psi.Reduce rate to 1.5 bpm, 420 psi at 55 bbls. Ball on seat at 618 strokes. Pressure up to 1700 psi to set hanger. Slack off to block weight. Increase pressure to 2500 psi and hold for 5 min. Increase pressure to 4100 psi and hold for 3 min to set and release packer. TOL at 8445' MD. PU=147K SO=104K after release. 8/25/2018 8/25/2018 0.50 COMPZ1 CASING PRTS P Test ZXP liner top packer to 3500 8,445.0 8,445.0 02:30 03:00 psi/10 mins on chart. Good test. 8/25/2018 8/25/2018 0.75 COMPZ1 WELLPR CRIH P P/U 12' out of RS packoff nipple and 8,445.0 8.445.0 03:00 03:45 spot 20 bbls of 10.4 ppg Cl brine to above Lt Whipstock @ 8335' MD, Pump @3 bpm= 690 psi w/ 14% FO, displace out of drill pipe with 760 strokes. Page 16136 Report Printed: 912412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our (hr) Phase Op Code ActlViry Coes Tune P -T -x Operation (flKB) End OepN(flKB) 8/25/2018 8/25/2018 0.50 COMPZI WELLPR OWFF P Monitor well. Dropped in riser 9". 8,445.0 8,445.0 03:45 04:15 8125/2018 8/25/2018 0.50 COMPZI WELLPR TRIP P POOH to 8330' MD. 8,445.0 8,330.0 04:15 04:45 8/25/2018 8/25/2018 2.00 COMPZI WELLPR SLPC P Slip and cut 77' drilling line. 8,330.0 8,330.0 04:45 06:45 6/25/2018 8/25/2018 0.75 COMPZI WELLPR TRIP P POOH from 8330' MD to 8053' MD. 8,330.0 8,053.0 06:45 07:30 1 1 PU=140K. 8/25/2018 8/25/2018 2.50 COMPZI WELLPR PMPO P Pump OOH due to swabbing from 8,053.0 6,030.0 07:30 10:00 8053' MD to 6030' MD. 1.5 bpm, 200 psi. PU=100K 8/25/2018 8/25/2018 3.25 COMPZi WELLPR TRIP P POOH from 6030' MD to 57' MD. 6,030.0 57.0 10:00 13:15 8/2512018 8125/2018 0.50 COMPZ1 WELLPR BHAH P Lay down running tools as per Baker 57.0 0.0 13:15 13:45 Rep. 8125/2018 8/2512018 0.50 PROD2 WHPST BHAH P Mobilize whipstock tools to rig Boor 0.0 0.0 13:45 14:15 and prep for BHA PU. 8/25/2018 8/26/2018 2.00 PROD2 WHPST BHAH P Make up whipstock BHA as per Baker 0.0 110.0 14:15 16:15 Rep. 8/25/2018 8/25/2018 2.25 PROD2 WHPST BHAH P Change out x -o, float sub, 1 jt HWDP 110.0 267.0 16:15 18:30 and MWD x -o due to observed deflection in BHA. MWD pin x pin x -o was source of deflection. Continue to make up BHA to 267' MD. 8/2512018 8/25/2018 1.00 PROD2 WHPST TRIP P RN with whipstock BHA from 267' MD 267.0 1,682.0 18:30 19:30 to 1682' MD. PU=72K SO=72K 8/25/2018 8/25/2018 0.25 PROD2 WHPST DHEQ P Shallow pulse test MWD. 250 gpm, 1,682.0 1,682.0 19:30 19:45 1030 psi, 19% FO. 8125/2018 8/26/2018 4.25 PROD2 WHPST TRIP P Continue to RIH with whipstock BHA 1,682.0 8,257.0 19:45 00:00 from 1682' MD to 8257" MD. Fill pipe every 20 stands. PU=147K SO=109K 8/26/2018 8/26/2018 0.75 PROD2 WHPST WPST P Orient tool face to 19"LOHS, pumping 8,257.0 8,334.8 00:00 00:45 @ 250 gpm, 1890 psi, PU 137K, SO 102K. Wash in hole maintaining 19° LOHS. Tag liner top @ 8445' MD, set 1 Ok down, PU 1 Ok over, set down 25k over, & observe pin shear. 8/26/2018 8/26/2018 5.25 PROD2 WHPST MILL P Mill 63/4" window from 8334.75' MD 8,334.8 8,347.1 00:45 06:00 to 8347.11' MD. 257 gpm, 1650 psi, 19% FO, 80 rpm, 3-71K tq. 1 K WOB. Pump hi -vis super sweep at 8341' MD. SCR @ 8326' MD, 3822' TVD, MW 10.4 ppg, 03:30 hrs #1 @ 20 = 540 psi, @ 30 = 660 psi #2 @ 20 = 560 psi, @ 30 = 700 psi 8126/2018 8126/2018 2.50 PROD2 WHPST MILL P Continue to mill 6 3/4" window and 8' 8,347.1 8,373.0 06:00 08:30 guage hole from 8347' MD to 8373' MD. 257 gpm, 1650 to 2500 psi, 19% FO, 80 rpm, 3-5K tq, 5-1 OK WOB. Pressure increase came after pumping super sweep. TOL at 8441.91' MD TOW at 8334.75' MD BOW at 8348.34' MD. OA=250 psi @ 0700 hrs. 8/26/2018 8/26/2018 1.75 PROD2 WHPST REAM P Pump hi -vis super sweep. Work mills 8,373.0 8,330.0 08:30 10:15 through window. Ream up & down @ same drilling rates x3. Work mills through window w/ no pumps or rotary x2. 1.5K drag up and down. Pump on PU= 133k, SO = 104k. Pump off PU=147K 50=111K Page 17136 ReportPrinted: 9124/2018 Operations Summary (with Timelog Depths) 11-1-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan oexn Sten Time End Time our (hr) Pease op c xis Activity CWe Time P -T -X Operation (ftKB) End oepin dtKB) 8/26/2018 8/26/2018 0.25 PROD2 WHPST TRIP P POOH on elevators from 8330' MD to 8,330.0 8,144.0 10:15 10:30 8144' MD. PU=146K SO=110K 8/26/2018 8/26/2018 1.00 PROD2 WHPST FIT P Rig up and perform FIT to 585 8,144.0 8,144.0 10:30 11:30 psill3.3 EMW. Pumped .7 bbis. Bled back .4 bbis. Blow down and rig down test equipment. 8/26/2018 8/2612018 0.50 PROD2 WHPST TRIP P POOH on elevators from 8144' MD to 8,144.0 7,688.0 11:30 12:00 1 1 7688' MD. PU=140K SO=105K. 8/26/2018 8/26/2018 0.50 PROD2 WHPST CIRC P Pump 20 bbl 11.5 ppg dry job. Blow 7,688.0 7,688.0 12:00 12:30 down TD. 8/2612018 8/26/2018 3.00 PROD2 WHPST TRIP P POOH on elevators forth 7688' MD to 7,688.0 157.0 12:30 15:30 157' MD. 8/26/2018 8/26/2018 1.00 PROD2 WHPST BHAH P Lay down milling BHA as per Baker 157.0 0.0 15:30 16:30 Rep. 8/26/2018 8/26/2018 0.50 PROD2 WHPST BHAH P Clean and Gear rig floor. Drain ROPE. 0.0 0.0 16:30 17:00 Pull wearring. 812612018 8/26/2018 1.00 PROD2 WHPST WWWH P Make up stack washing tool. Flush 0.0 0.0 17:00 18:00 ROPE at 853 gpm, Lay down tool. Set 9" ID wearring. OA= 0 psi. 8/26/2018 8/26/2018 0.50 PROD2 WHPST SVRG P Service top drive and blocks 0.0 0.0 18:00 18:30 8/26/2018 8/26/2018 1.00 PROD2 WHPST BHAH P MU up motor/clean out assembly per 0.0 631.0 18:30 19:30 SLB to 631' MD. 8/26/2018 8/2612018 0.50 PROD2 WHPST TRIP P RIH w/ clean out BHA on 4" DP from 631.0 1,765.0 19:30 20:00 derrick from 631' MD to 1765' MD. PU=69K, SO=69K. Monitor displacement via trip tank. 8/26/2018 8/2612018 0.25 PROD2 WHPST DHEQ P Shallow hole test MWD. 250 gpm, 1,765.0 1,765.0 20:00 20:15 1 1 1315 psi, 19% FO. 8/26/2018 8/26/2018 2.75 PROD2 WHPST TRIP P Continue to RIH w/ clean out BHA on 1,765.0 8,135.0 20:15 23:00 4" DP from derrick from 1765' MD to 8135' MD. PU=122K, SO=84K. Monitor displacement via trip tank. Fill pipe every 20 stands. 8/26/2018 8/26/2018 0.25 PROD2 WHPST TRIP P Orient motor to 22"LOHS. Trip down 8,135.0 8,372.0 23:00 23:15 though window from 8334.75' MD to 8348.34' MD, no issues. Tag bottom @ 8372' MD and set down 5K. 8/26/2018 8/27/2018 0.75 PROD2 DRILL DDRL P Drill 6 314" hole from 8373' MD to 8,372.0 8,460.0 23:15 00:00 8460' MD 3827' TVD. 250 GPM @ 1970 PSI, 19% F/0, 40 RPM 5K TO, 11KWOB, OB1820PSI. UPWT= 124K, DWN WT = 85K. ROT 95K, 8K TO, Max gas units 0. ADT .45, ASR .09 Bit hrs .45, Jar HRS 110.13 SCR @ 8367' MD, 3822' TVD, MW 10.4 ppg, 23:15 hrs #1 @ 20 = 630 psi, @ 30 = 820 psi #2 @ 20 = 620 psi, @ 30 = 820 psi Losses for tour -11.6 bits Page 18136 ReportPrinted: 9/24/2018 Operations Summary (with Timelog Depths) IH-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log shut Depth StaM1Time End Time Dur (m) Phase Op Code Actively Code Time P-T-X Operation (NKB) End Depth (ftKB) 8/27/2018 8/27/2018 0.25 PROD2 DRILL DDRL P Drill 6 3/4" hole from 8460' MD 3827' 8,460.0 8,476.0 00:00 00:15 TVD to 8476' MD 3839' TVD. 250 GPM @ 1990 PSI, 19% F/0, 40 RPM 5K TO, 6K WOB, OB 1830 PSI. UP WT=125K, OWN WT=86K. ROT 95K, 4.5K TQ, Max gas units 0. ADT .11, AST 0 Bit hrs .56, Jar HRS 110.24 6/27/2018 8/27/2018 1.00 PROD2 DRILL CIRC P CBU while rotating and reciprocating 8,476.0 8,476.0 00:15 01:15 from 8476' MD to 8416' MD. 250 gpm, 1920 psi, 19% FO, 40 rpm, 4.51K lq, MW 10.4 ppg. Orient to 10" LOHS. 8/27/2018 812712018 0.25 PROD2 DRILL TRIP P POOH from 8476' MD to 8321' MD. 8,476.0 8,321.0 01:15 01:30 No drag observed pulling though window. 8/2712018 8/27/2018 0.50 PROD2 DRILL OWFF P Monitor well. Static. 8,321.0 8,321.0 01:30 02:00 8/27/2018 8/27/2018 3.25 PROD2 DRILL TRIP P POOH from 8321' MD to 631' MD. 8,321.0 631.0 02:00 05:15 1 1 1 Monitor displacement via trip tank. 8/27/2018 8127/2018 1.50 PROD2 DRILL BHAH P Monitor well at BHA. Static. Lay down 631.0 0.0 05:15 06:45 and stand back clean out BHA #6 as per DD. Monitor displacement via trip tank. 8127/2018 8/27/2018 0.75 PROD2 DRILL BHAH P Clean and clear rig floor. Drain BOPE. 0.0 0.6- 06:45 07:30 Pull wearying. Make up stack washer. 8/27/2018 8/27/2018 0.75 PROD2 DRILL WWWH P Function all rams and annular 0.0 0.0 07:30 08:15 preventer. Flush BOPE with 854 gpm x2. Install 9" ID wearring. Blow down TD. 8/27/2018 8/27/2018 0.50 PROD2 DRILL SVRG P Service and inspect lop drive and 0.0 0.0 08:15 08:45 blocks. 8/27/2018 8/27/2018 1.25 PROD2 DRILL BHAH P Make up RSS BHA #7 as per DO to 0.0 336.0 08:45 10:00 336' MD. Monitor displacement via trip tank. 8/27/2018 812712018 0.50 PROD2 DRILL TRIP P RIH with 4" DP from 336' MD to 1750' 336.0 1,750.0 10:00 10:30 MD. Monitor displacement via trip tank. 8/27/2018 8/27/2018 0.50 PROD2 DRILL DHEQ P Shallow hole test MWD. Stage pump 1,750.0 1,750.0 10:30 11:00 1 1 1 up to 241 gpm, 1100 psi, 17% FO. 8/27/2018 8/27/2018 2.75 PROD2 DRILL TRIP P RIH with 4" DP from 1750' MD l0 1,750.0 8,405.0 11:00 13:45 8405' MD. Fill pipe every 25 stands. IPU=122K Monitor displacement via trip tank. SO=82K 8/27/2018 8/27/2018 1.00 PROD2 DRILL DLOG P Wash down to bottom. MAD pass from 8,405.0 8,476.0 13:45 14:45 8405' MD to 8476' MD. 240 gpm, 1712 psi, 19% FO. Send downlink. Displace to new 10.2 ppg FloPro mud. 8/27/2018 8/27/2018 3.25 PROD2 DRILL DDRL P Drill 6 3/4" hole from 8476' MD 3839' 8,476.0 8,800.0 14:45 18:00 TVD to 8800' MD 3826' TVD. 250 GPM @ 1835 PSI, 19% F/O, 150 RPM 7K TO, 3K WOB, OB 1830 PSI. UP WT= 116K, DWN WT = 81 K. ROT 93K, 41K TO, Max gas units 20. ADT 2.63, Bit him 2.63, Jar HRS 112.87 SCR @ 8596' MD, 3826' TVD, MW 10.2+ ppg, 15:50 hrs #1 @ 20 = 490 psi, @ 30 = 680 psi #2 @ 20 = 480 psi, @ 30 = 680 psi Page 19/36 Report Printed: 9124/2018 Operations Summary (with Timelog Depths) 11-1-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -x Operation mKS) End Depth (ftKS) 8/27/2018 8/28/2018 6.00 PROD2 DRILL DDRL P Drill 63/4" hole from 8800' MD 3826' 8,800.0 9,720.0 18:00 00.00 TVD to 9720' MD3878' TVD. 250 GPM @ 1940 PSI, 19% F/O, 140 RPM 8K TQ, 5K WOB, ECD=12.19 OB 1940 PSI. UP WT= 123K, OWN WT = 81 K. ROT 96K, 4K TQ, Max gas units 1400. ADT 4.19, Bit hrs 6.82, Jar HRS 117.06 SCR @ 8880' MD, 3841' TVD, MW 10.3 ppg, 18:30 hrs #1 @ 30 = 510 psi, @ 40 = 690 psi #2 @ 30 = 480 psi, @ 40 = 680 psi OA=305 psi 8/28/2018 8/28/2018 6.00 PROD2 DRILL DDRL P Drill 6 3/4" hole from 9720' MD 3878' 9,720.0 10,408.0 00:00 06:00 TVD to 10408' MD3893' TVD. 250 GPM @ 2065 PSI, 19% NO, 140 RPM 8.5K TQ, 81K WOB, ECD=12.56 OB 2050 PSI. UP WT = 128K, DWN WT = 73K. ROT 95K, 8K TQ, Max gas units . ADT 3.92, Bit his 10.74, Jar HRS 120.98 8/28/2018 8/28/2016 6.00 PROD2 DRILL DDRL P Drill 6 3/4" hole from 10408' MD3893' 10,408.0 11,004.0 06:00 12:00 TVD to 11004' MD 3959' TVD. 250 GPM @ 2220 PSI, 19% F/O, 140 RPM 8.71K TQ, 10.51K WOB, ECD=12.33 OB 2215 PSI. UP WT = 129K, OWN WT=81 K. ROT 99K, 7.2K TQ, Max gas units 139. ADT 4.55, Bit hrs 15.29, Jar HRS 125.53 SCR @ 10495' MD, 3902' TVD, MW 10.3+ ppg, 06:38 hrs #1 @ 30 = 500 psi, @ 40 = 720 psi #2 @ 30 = 480 psi, @ 40 = 700 psi OA=310 psi 8/28/2018 8/28/2018 6.00 PROD2 DRILL DDRL P Drill 6 3/4" hole from 11004' MD 3959' 11,004.0 11,339.0 12:00 18:00 TVD to 11339' MD 3972' TVD. 260 GPM @ 2380 PSI, 19% F/O, 160 RPM, 8.5K TQ, 5K WOB, ECD=12.23, OB 2370 PSI. UP WT = 132K, OWN W7=81 K. ROT 98K, 6K TO, Max gas units 195. ADT 4.16, Bit hrs 19.45, Jar HRS 129.69 8/28/2018 8/29/2018 6.00 PROD2 DRILL DDRL P Drill 6 3/4" hole from 11339' MD 3972' 11,339.0 11,979.0 18:00 00:00 TVD to 11979' MD 3930' TVD. 260 GPM @ 2430 PSI, 19% F/O, 150 RPM, 7.71K TQ, 4K WOB, ECD=12.5, OB 2420 PSI. UP WT= 132K, OWN WT = 67K. ROT 97K, 8K TQ, Max gas units 180. ADT 4.19, Bit hrs 23.64, Jar HRS 133.88 SCR @ 11350' MD, 3967' TVD, MW 10.2+ ppg, 18:13 his #1 @ 30 = 500 psi, @ 40 = 730 psi #2 @ 30 = 490 psi, @ 40 = 720 psi OA=165 psi Page 20136 ReportPrinted: 9/2412018 Operations Summary (with Timelog Depths) 11-1-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftm End Depth(ftKB) 8/29/2018 8/29/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 3/4" Ll hole f/ 11,979.0 12,445.0 00:00 0600 11979'- 12445' MD, 3901' TVD, 260 gpm, 2350 psi, FO 19%,150 rpm, Tq 8.4K, WOB 5K, ECD 12.59, OB 2345 psi, PU 133K, SO 66K. ROT 96K, 8K To, Max gas 190, ADT 4.03, Bit 27.67, Jars 137.91 8/29/2018 8/29/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole f/ 12,445.0 12,946.0 06:00 12:00 12446'- 12946' MD, 3895' TVD, 260 gpm, 2400 psi, FO 19%, 150 rpm, Tq 8.5K, WOB 3K, ECD 12.46, off btm 2400 psi, PU 137K, SO 67K, ROT 96K, Tq 8.5K, Max gas 251, ADT 4.28, Bit 31.95, Jars 142.19 SCR @ 12491' MD, 3899' TVD, MW 10.3 ppg, 06:36 hrs #1 @ 30 = 530 psi, @ 40 = 730 psi #2 @ 30 = 530 psi, @ 40 = 730 psi OA 280 psi 8/29/2018 8/29/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 3/4" 1-1 hole f/ 12,946.0 13,444.0 12:00 18:00 12946'- 13444' MD, 3913' TVD, 260 gpm, 2515 psi, FO 20%,150 rpm, Tq 8.7K, WOB 4.2K, ECD 12.74, off Dim 2490 psi, PU 141 K. SO 60K, ROT 94K, Tq 8.5K, Max gas 230, ADT 4.27, Bit 36.22, Jars 146.46 8/29/2018 8/29/2018 4.50 PROD2 DRILL DDRL P Directional drill 63/4"L1 hole f/ 13,444.0 13,900.0 18:00 22:30 13444'- 13900' MD, 3962' TVD, 260 gpm, 2767 psi, FO 16%, 150 rpm, Tq 8.3K, WOB 5K, ECD 12.54, off btm 2660 psi, PU 146K, SO 60K, ROT 96K, Tq 8K, Max gas 20, ADT 3.4, Bit 39.62, Jars 149.86 Observed losses of initial rate of 30 bph at 13715' MD. 8/29/2018 8/29/2018 1.00 PROD2 DRILL OWFF T Monitor well with 5 rpm & Tq 8K, 13,900.0 13,900.0 22:30 23:30 perform well bore breathing lest laking returns to the trip tank. Observe flow decrease from initial flow of 1 bpm to 0.2 bpm over 43 minutes. Total volume back 25 bbls. 8/29/2018 8/30/2018 0.50 PROD2 DRILL DDRL P Directional drill 63/4"L1 hole f/ 13,900.0 13,944.0 23:30 00:00 13900'- 13944' MD, 3965' TVD, 260 gpm, 2515 psi, FO 16%,150 rpm, Tq 8.3K, WOB 2K, ECD 12.36, off btm 2510 psi, PU 146K, SO 60K, ROT 96K, Tq 8K, Max gas 23, ADT .34, Bit 39.96, Jars 150.2 Observed loss rate increase to 90 bph. 8/30/2018 8/30/2018 6.00 PROD2 DRILL DDRL P Directional drill 63/4"Lt hole f/ 13,944.0 14,379.0 00:00 06:00 13944' - 14379' MD, 3950' TVD, 250 gpm, 2430 psi, FO 17%,150 rpm, Tq 9K, WOB 3K, ECD 12.41, off btm 2428 psi, PU 150K, SO 65K, ROT 109K, Tq 9K, Max gas 40, ADT 4.62, Bit 44.58, Jars 154.82 Observed loss rate — 100 bph. Page 21/36 Report Printed: 9/2412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-x Operation Stan Depth (flKB) End Depth(ftKB) 8/30/2018 8/30/2018 2.00 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole f/ 14,379.0 14,546.0 06:00 0800 14379'- 14546' MD, 3940' TVD, 250 gpm, 2575 psi, FO 17%,120 rpm, Tq 8.5K, WOB 1.5K, ECD 12.42, off btm 2570 psi, PU 150K, SO 65K, ROT 116K, Tq 9K, Max gas 30, ADT 1.72, Bit 46.3, Jars 156.54 Observed loss rate — 100-80 bph. SCR @ 14452' MD, 3945' TVD, MW 10.2+ ppg, 06:45 his #1 @ 20 = 530 psi, @ 30 = 730 psi #2 @ 20 = 530 psi, @ 30 = 730 psi OA 230 psi 8/30/2018 8/30/2018 0.75 PROD2 DRILL CIRC T Pump 40 bbls LCM pill at 250 gpm, 14,546.0 14,546.0 08:00 08:45 2640 psi, FO 16%,120 rpm, Tq 7.5K. Reduce pump rate to 170 gpm, 1425 psi as pill was pumped across the suspected loss zone. 8/30/2018 8/30/2018 3.25 PROD2 DRILL DDRL P Directional drill 6 3/4" 11 hole f/ 14,546.0 14,679.0 08:45 1200 14546'- 14679' MD, 3932' TVD, 240 gpm, 2420 psi, FO 17%,120 rpm, Tq 8K, WOB 3K, ECD 12.4, off btm 2400 psi, PU 152K, SO N/A, ROT 116K, Tq 9K, Max gas 61, ADT 2.65, Bit 48.95, Jars 159.19 Observed loss rate — 80-60 bph. 8/30/2018 8/30/2018 6.00 PROD2 DRILL DDRL P Directional drill 6 3/4" L1 hole f/ 14,679.0 14,925.0 12:00 1800 14679'- 14925' MD, 3929' TVD, 240 gpm, 2460 psi, FO 16%,120 rpm, Tq 8.8K, WOB 6K, ECD 12.48, off btm 2455 psi, PU 163K, SO N/A, ROT 109K, Tq 9K, Max gas 67, ADT 4.74, Bit 53.69, Jars 163.93 Observed loss rate — 40 bph. 8/30/2018 8/31/2018 6.00 PROD2 DRILL DDRL P Directional drill 3/4" L1 hole f/ 14,925.0 15,371.0 18:00 0000 14925- 15371' MD, 3928' TVD, 245 gpm, 2607 psi, FO 18%,120 rpm, Tq 8.5K, WOB 4K, ECD 12.54, off btm 2600 psi, PU 165K, SO N/A, ROT 106K, Tq 7.7K, Max gas 35, ADT 4.94, Bit 58.63, Jars 168.87 Observed loss rate — 40 bph. SCR @ 15004' MD, 3928' TVD, MW 10.1+ ppg, 19:10 hrs #1 @ 20 = 820 psi, @ 30 = 1040 psi #2 @ 20 = 860 psi, @ 30 = 1080 psi OA 195 psi 8/31/2018 8/31/2018 6.00 PROD2 DRILL DDRL P Directional drill 3/4" L1 hole f/ 15,371.0 15,737.0 00:00 06:00 15371'- 15737' MD, 3910' TVD, 245 gpm, 2740 psi, FO 17%,120 rpm, Tq 8.6K, WOB 4K, ECD 12.61, off btm 2735 psi, PU 169K, SO N/A, ROT 124K, Tq 8K, Max gas 35, ADT 5.09, Bit 63.72, Jars 173.96 Observed loss rate — 25 bph. Page 22136 Report Printed: 9/24/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Tune End Time Our (hr) phase Op Core Activity Core Time P -T -X Operation (WB) End Dept, (NCB) 8/31/2018 8/31/2018 5.50 PROD2 DRILL DDRL P Directional drill 6 3/4" Lt hole f/ 15,737.0 15,972.0 06:00 11:30 15737' - 15972' MD, 3900' TVD, 250 gpm, 2910 psi, FO 18%, 120 rpm, Tq 8.51K, WOB 5K, ECD 12.65, off btm 2900 psi, PU 169K, SO N/A, ROT 124K, Tq 8.51K, Max gas 375, ADT 4.18, Bit 67.90, Jars 178.14 Observed loss rate - 20 bph. SCR @ 15737' MD, 3810' TVD, MW 10.0+ ppg, 06:00 hm #1 @ 20 = 880 psi, @ 30 = 1100 psi #2 @120 = 800 psi, @ 30 = 1060 psi OA 75 psi 8/31/2018 8/31/2018 2.00 PROD2 CASING CIRC P Obtain final survey & CBU at 250 15,972.0 15,972.0 11:30 13:30 gpm, 2930 psi, FO 17,120 rpm, Tq 8K, ECD 12.61, PU 165K, SO N/A, ROT 123K. SCR @ 15972' MD, 3900' TVD, MW 10.0+ ppg, 13:30 hrs #1 @ 20 = 890 psi, @ 30 = 1120 psi #2 @120 = 900 psi, @ 30 = 1120 psi 8/31/2018 8131/2018 2.00 PROD2 CASING OWFF P Monitor well, observing flow decrease 15,972.0 15,972.0 13:30 15:30 from 135 bph to 1.2 bph. PU 175K, SO 68K. 8/31/2018 9/1/2018 8.50 PROD2 CASING BKRM P BROOH f/ 15972'-12872' MD, 240 15,972.0 12,872.0 15:30 00:00 gpm, 1990 psi, FO 13%, ECD 11.72, 120 rpm, Tq 7K, PU 134K, SO 65K. 9/1/2018 9/1/2018 6.00 PROD2 CASING BKRM P BROOH f/ 12872'-10700' MD, 241 12,872.0 10,700.0 00:00 0600 gpm, 1950 psi, FO 13%, ECD 11.8, 120 rpm, Tq 6.51K, PU 134K, SO 70K. 9/1/2018 9/1/2018 5.00 PROD2 CASING BKRM P BROOH f/ 10700'-8694' MD, 241 gpm, 10,700.0 8,694.0 06:00 1100 1836 psi, FO 16%, ECD 11.63, 120 rpm, Tq 4.5K, PU 114K, SO 81 K. 9/1/2018 9/1/2018 1.00 PROD2 CASING PMPO P Pump out of the hole pulling the BHA 8,694.0 8,314.0 11:00 1200 lhru the window f/ 8694'-8314' MD, 1 bpm, 330 psi, FO 4%. 9/1/2018 9/1/2018 2.25 PROD2 CASING CIRC P Circulate casing clean & raise MW to 8,314.0 8,314.0 12:00 14:15 10.4 ppg, 241 gpm, 1886 psi, FO 17%, ECD 11.89, 100-120 rpm, Tq 4K. 91112018 9/1/2018 2.00 PROD2 CASING OWFF P Monitor well, observe wellbore 8,314.0 8,314.0 14:15 16:15 breathing to static hole conditions. Measure flow back to trip tank & record reducing rate. 9/1/2018 9/1/2018 1.75 PROD2 CASING PMPO P Pump out of the hole f/ 8314'-6320' 8,314.0 6,320.0 16:15 18:00 MD, 50 gpm, 260 psi, FO 12%, PU 103K, SO 84K. 9/1/2018 9/1/2018 2.75 PROD2 CASING TRIP P TOH f/ 6320'-336' MD. 6,320.0 336.0 18:00 20:45 9/1/2018 911/2018 0.25 PROD2 CASING OWFF P Monitor well, observe fluid level drop 336.0 336.0 20:45 21:00 4" in the riser. 9/1/2018 9/112018 1.00 PROD2 CASING BHAH P Lay down BHA 7, clear & clean rig 336.0 0.0 21:00 22:00 floor. 9/112018 9/1/2018 1.50 COMPZ2 FISH BHAH P Pick up BHA 8, 7-5/8" Whipstock 0.0 248.0 22:00 23:30 retrieval assembly to 248.43'. Offset 110.62 9/1/2018 9/2/2018 0.50 COMPZ2 FISH TRIP P TIH w/ BHA8 f/ 248'-1292' MD, PU 248.0 1,292.0 23:30 00:00 1 I 62', SO 55K. 9/2/2018 9/2/2018 2.75 COMPZ2 FISH TRIP P TIH w/ BHA8 f/ 1292'-8287' MD, PU 1,292.0 8,287.0 00:00 02:45 1 113K, SO 79K. 9/2/2018 9/2/2018 1.00 COMPZ2 FISH CIRC P CBU at 230 gpm, 1600 psi, PU 108K, 8,287.0 8,287.0 02:45 03:45 I SO 80K. Page 23136 Report Printed: 9/2412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Depth start Tme End Time Dur (hr) Phase Op Code Actively Code Tme P -T -X Operation (IIKB) End Depth (ftKB) 9/2/2018 9/2/2018 0.25 COMPZ2 FISH FISH P Wash in hole & orient tool face to 160 8,287.0 8,325.0 03:45 04:00 R & wash out whipstock slot 210 gpm, 1300 psi. Pick up above slide & orient to 20 L. Slack off & engage hook to slot at 8340' MD, w/ 5K. Pull to 170K & observe anchor release. Pull whipstock assembly past window to 8325' MD, PU 110K. 9/2/2018 9/2/2018 1.50 COMPZ2 FISH CIRC P CBU two times at 280 gpm, 1651 psi. 8,325.0 8,325.0 04:00 05:30 9/2/2018 9/2/2018 1.00 COMPZ2 FISH OWFF P Monitor well, with breathing. Observe 8,325.0 8,325.0 05:30 0630 return Bow reduce to .15 BPH. 9/2/2018 9/2/2018 3.75 COMPZ2 FISH PMPO P Pump out of hole due to swabbing f/ 8,325.0 5,386.0 06:30 1015 8325'-5386' MD, 58 gpm, 160 psi, FO 2%, PU 95K. 9/2/2018 9/2/2018 2.75 COMPZ2 FISH TRIP P TOH with whipstock assembly f/ 5,386.0 353.0 10:15 13:00 5386'-353' MD, PU 53K. 9/2/2018 92/2018 0.25 COMPZ2 FISH OWFF P Monitor well, static 353.0 353.0 13:00 13:15 9/2/2018 9/22018 2.50 COMPZ2 FISH BHAH P Rack back HWDP & lay down 353.0 0.0 13:15 15:45 whipstock assembly as per BOT Rep. Clear & clean rig Boor. 922018 9/2/2018 1.00 COMPZ2 CASING RURD P Mobilize & rig up 4-1/2" handling 0.0 0.0 15:45 16:45 equipment, verify pipe count. 9/2/2018 92/2018 0.25 COMPZ2 CASING SFTY P PJSM with all personnel involved in 0.0 0.0 16:45 17:00 running 4-1/2" lower completion. 9/2/2018 9/3/2018 7.00 COMPZ2 CASING PUTB P Make up 4-1/2", 12.6#, L-80, TXP / 0.0 4,784.0 17:00 00:00 IBTM as per detail to 4784' MD, PU 79K, SO 69K. Bakerl-ok first 2 connections, TXP torque to 71K f albs. IBTM connections made up to the mark. Each joint centralized w/ 6-1/8" Volant Hyrdroform. 9/3/2018 9/312018 3.50 COMPZ2 CASING PUTB P Make up 4-1/2", 12.6#, L-80, TXP / 4,784.0 7,580.0 00:00 03:30 IBTM as per detail f/ 4784'-7580' MD, PU 95K, SO 75K. TXP torque to 71K fUlbs. IBTM connections made up to the mark. Each joint centralized w/ 6- 1/8" Volant Hyrdroform. Last 2 joints not centralized. 9/3/2018 9/3/2018 1.50 COMPZ2 CASING OTHR P Make up hook hanger assembly as 7,580.0 7,613.0 03:30 05:00 per BOT Rep. Make up & install slim pulse assembly as per SLB MWD. Verify offset 156.26. 9/3/2018 9/3/2018 0.50 COMPZ2 CASING CIRC P Circulate staging up to 2 bpm, 320 psi, 7,613.0 7,613.0 05:00 05:30 FO 10%, blow down TD. SIMOPS Change out handling equipment to TIH w/ 4" DP. 9/3/2018 9/3/2018 2.25 COMPZ2 CASING RUNL P TIH w/ 4-1/2" lower completion on 4" 7,613.0 10,450.0 05:30 07:45 DP, drifting stands from derrick f/ 7613'-10450' MD, PU 112K, SO 76K. At the window PU 98K, SO 74K. 9/3/2018 9/3/2018 3.00 COMPZ2 CASING DHEQ T Test slim pulse tool at various rates 10,450.0 10,450.0 07:45 1045 staging up to 180 gpm, 954 psi, FO 17%. Increase in pressure f/ 950 to 1300 psi at 2430 strokes pumped. Unable to pump over 80 gpm without exceeding 1300 psi max. No detection. Confer w/ town & decide to TOH & change out slim pulse. 9/3/2018 9/3/2018 0.50 COMPZ2 CASING OWFF T Monitor well, static. 10,450.0 10,450.0 10:45 11:15 9/3/2018 9/3/2018 i 1.75 COMPZ2 i CASING TRIP T TOH f/ 10450'-7577' MD, PU 98K, SO 10,450.0 7,577.0 11:15 13:00 I 74K. Page 24/36 Report Printed: 9124/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Star) Tints ne EM Ti Dur (hr) Phase Op Catl8 Activity Cotle Time P -RX Op QUDeeration Ertl Depth (WB) 9/3/2018 9/3/2018 3.50 COMPZ2 CASING BHAH T Break out hook hanger assembly & 7,577.0 7,613.0 13:00 16:30 inspect. Change out slim pulse MWD. Test tools at 2 bpm, 290 psi, FO 11 %. 9/3/2018 9/3/2018 0.50 COMPZ2 CASING TRIP T TIH f/ 7613'-8278' MD, PU 100K, SO 7,613.0 8,278.0 16:30 17:00 74K, 9/3/2018 9/3/2018 0.50 COMPZ2 CASING SRW T Shallow hole test slim pulse tools 2 8,278.0 8,278.0 17:00 17:30 bpm, 312 psi, FO 11 %, good. 9/3/2018 9/3/2018 1.00 COMPZ2 CASING RUNL T TIH w/ 4-1/2" lower completion on 4" 8,278.0 8,450.0 17:30 18:30 DP, 8278'-8460' MD, nogo out at 8460' MD. Pick up & rotate 90" right & attempt to enter window. Repeat process 3 times to enter L1. 9/3/2018 9/3/2018 1.00 COMPZ2 CASING RUNL T TIH w/ 4-1/2" lower completion on 4" 8,450.0 10,450.0 18:30 19:30 DP, f/ 8450'-10450' MD. 9/3/2018 9/4/2018 4.50 COMPZ2 CASING RUNL P TIH w/ 4-1/2" lower completion on 4" 10,450.0 15,882.0 19:30 00:00 DP, drifting stands from derrick f/ 10450'-15882' MD, PU 165K, SO 76K. 9/4/2018 914/2018 1.75 COMPZ2 CASING HOSO P Orient tool face to 160'R at 120 gpm, 15,882.0 15,943.0 00:00 01:45 1030 psi & wash down to 15935' MD setting down w/ 7K, string turned to 173'R (appear to be on the hook). Pick up & re -orient string to 20°L and drift lhru to 15943' MD. Pick back up above & discuss orientation. Orient string to 170°R & go down to 15935' MD & set 20K SOW. Observe TF roll to 170°L, on the hook. 9/4/2018 9/4/2018 1.00 COMPZ2 CASING HOSO P Release running tool f/ Hook hanger, 15,943.0 8,323.0 01:45 02:45 drop 29/32th ball and pump down 118gpm, 1000 psi. Reduce pump rate 64 gpm, 580 psi. Ball on seat @ 724 strokes. Pressure up to 3500 psi & pick up 4' and confirm release w/ P/U wt. of 135K. Pressure up to 4500 psi to blow ball seat. Flanged hook hanger BOW (418348' MD, hook hanger inside casing @ 8328' MD. 9/4/2018 9/4/2018 1.00 COMPZ2 WELLPR OWFF P Monitor well; observe reduction in Flow 8,323.0 8,323.0 02:45 03:45 rate return to confirm wellbore breathing. 9/4/2018 9/4/2018 0.25 COMPZ2 WELLPR TRIP P TOH f/ 8323'-8171' MD, PU 130K, SO 8,323.0 8,171.0 03:45 04:00 74K. 914/2018 9/4/2018 1.00 COMPZ2 WELLPR SLPC P Cut & slip 88' of drill line. 8,171.0 8,171.0 04:00 05:00 914/2018 9/4/2018 7.00 COMPZ2 WELLPR TRIP P TOH f/ 8171'-40' MD, serviced super 8,171.0 40.0 05:00 12:00 sliders f/ 4897' on the way out of the hole. 9/4/2018 9/4/2018 0.75 COMPZ2 WELLPR BHAH P Lay down SLB slim pulse MWD & 40.0 0.0 12:00 12:45 BOT running tool. 9/412018 9/4/2018 0.50 COMPZ2 WELLPR BHAH P Clear & clean rig floor. 0.0 0.0 12:45 13:15 9/4/2018 9/4/2018 0.50 COMPZ2 RWRID RURD P Rig up GBR torque tum & handling 0.0 0.0 13:15 13:45 equipment. 9/4/2018 9/4/2018 2.75 COMPZ2 RWRID RCST P Make up 4.5", 12.6#, L-80, TXP, 0.0 232.0 13:45 16:30 LEM/ZXP assembly, torque turned, as per detail to 232' MD. Scribe & orient MWD, tool face offset 26.18. 9/4/2018 9/4/2018 0.25 COMPZ2 RWRID DHEQ P Make up a stand of DP & test slim 232.0 320.0 16:30 16:45 pulse tools 2 bpm, 242 psi, FO 11 acquired detection. 9/4/2018 9/4/2018 1.00 COMPZ2 RWRID RCST P TIH w/ LEM assembly on DP f1320'- 320.0 1,657.0 16:45 17:45 I 1657' MD, PU 65K, SO 66K. Page 25136 ReportPrinted: 9/24/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Tuna End Time Dur (hr) Phase Op Code Aotwfty Code Time P-T-X Operedon $tart Depm (AKS) End Depth (Wir) 9/4/2018 9/4/2018 0.25 COMPZ2 RWRID DHEO P Shallow test MWD at 2 bpm, 310 psi, 1,657.0 1,657.0 17:45 18:00 FO 11%, good. 9/4/2018 9/4/2018 3.75 COMPZ2 RWRID RCST P TIH w/ LEM assembly on DP f/ 1657'- 1,657.0 8,223.0 18:00 21:45 8223' MD, PU 137K, SO 100K. 9/4/2018 9/4/2018 1.75 COMPZ2 RW RID PACK P Wash down from 8223'- 8490' MD & 8,223.0 8,271.0 21:45 23:30 orient LEM to 82`L w/ 91 gpm, 745 psi, FO 10%. PU 137K, SO 100K. Engage seal assembly & latch LEM in Hook Hanger on depth @ 8490.50' MD. Observe LEM rotate to 34` L. Set down 20K. PU 147K to verify LEM is engaged. Drop 1.625" OD ball. Set down 30K & pump @ 127-84 gpm, 1000-665 psi, FO 13-11%. Ball on seat @ 600 stks. Observe hydraulic pusher tool stroke & set ZXP packer @ 2,400 psi, neutralized @ 3,700 psi & 4200 psi holding for a couple minutes. Bleed off pressure & PU 3' per Baker, PU 137K. 9/4/2018 9/5/2018 0.50 COMPZ2 RWRID PRTS P Line up & test ZXP liner top packer to 8,271.0 8,271.0 23:30 00:00 3500 psi for 10 minutes, CPAI Rep witness. Bleed off & blow down kill line. 9/5/2018 915/2018 0.75 COMPZ2 RWRID CRIH P PU above ZXP to 8239' MD & spot 20 8,271.0 8,239.0 00:00 00:45 bbls of corrosion inhibited pill at 126 gpm, 550 psi, 9/5/2018 9/5/2018 0.75 COMPZ2 RWRID OWFF P Monitor well, track return flow to verify 8,239.0 8,239.0 00:45 01:30 reduction in rate (wellbore breathing). 9/512018 9/5/2018 3.50 COMPZ2 RWRID TRIP P TOH w/ LEM/ZXP running tools f/ 8,239.0 0.0 01:30 05:00 1 1 8239'-0' MD 9/5/2018 9/512018 0.50 COMPZ2 RWRID BHAH P Lay down running tool & slim pulse 0.0 0.0 05:00 05:30 MWD. 9/5/2018 9/5/2018 1.25 COMPZ2 RWRID SVRG P Change out 4" XT39 saver sub on top 0.0 0.0 05:30 06:45 drive, threads worn. 9/5/2018 9/5/2018 0.75 COMPZ2 WHDBOP RURD P Rig up test equipment & flood lines. 0.0 0.0 06:45 07:30 Pull wear bushing & install test plug. 915/2018 9/5/2018 0.50 COMPZ2 WHDBOP SVRG P Service & inspect top drive, blocks & 0.0 0.0 07:30 08:00 the crown. 9/5/2018 91512018 4.25 COMPZ2 WHDBOP BOPE P Test witnessed by AOGCC Rep Guy 0.0 0.0 08:00 12:15 Cook. Test w/ 4" & 4.5" test joints. Perform bi-weekly BOPE test. 250/3500 psi- 5 min each. Following tests done with 4 1/2" lest joint. Test #1-Annular,CV's 1,12,13,14, 4" kill Demco, 4" dart valve. Test #2-Upper 3 1/2" x 6" VBR, CV's 9,11, mezzanine kill line valve, 4" FOSV. Test #3-CV's 8, 10. kill HCR, Upper IBOP. Test #4- CV's 6,7, lower IBOP, manual kill line valve. Test #5- Super choke and manual choke at 250/2000 psi. Test #6 - CV's 2,5. Test #7- Lower 3 1/2" x 6" VBR. Test #8- Blind rams, CV's 3,4. Following tests done with 4" test joint. Test #9-Annular, choke line HCR. Test #10- Upper 3 1/2" x 6" VBR & manual choke. Test #11- Lower 3 1/2" x 6" VBR. Accumulator draw down initial system pressure 3000 psi, after functioning 1750 psi, 200 psi recovery in 6 seconds, full in 50 seconds. Nitrogen bottles 6 @ 2158 psi. Tested gas detection system, flow & pit level indicators. 12S alarm in pits FP. Page 26136 Report Printed: 9/2412018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Star) Time EM Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/5/2018 9/5/2018 0.75 COMPZ2 WHDBOP RURD P Rig down & blow down all lines & test 0.0 0.0 12:15 13:00 equipment. Pull test plug & install 9" ID wear bushing. 915/2018 9/5/2018 0.50 PROD3 WHPST SHAH P Mobilize whipstock BHA 9 to rig floor. 0.0 0.0 13:00 13:30 9/5/2018 9/5/2018 2.50 PROD3 WHPST BHAH P Make up mill assembly w/ MWD & 0.0 262.0 13:30 16:00 rack back in the derrick. Make up whipstock assembly to 262' MD as per BOT Rep, SO 49K. 915/2018 9/5/2018 1.25 PROD3 WHPST TRIP P TIH w/ whipstock BHA 9 for L2 f/ 262'- 262.0 2,160.0 16:00 17:15 1 2160' MD, SO 75K. 9/5/2018 9/5/2018 0.50 PROD3 WHPST DHEQ P Pulse test MWD at 220 gpm, 675 psi, 2,160.0 2,160.0 17:15 17:45 FO 16%, good. Blow down TD. 9/5/2018 915/2018 3.75 PROD3 WHPST TRIP P TIH w/ whipstock BHA 9 for L2 f/ 2,160.0 8,160.0 17:45 21:30 2160'-8160' MD, PU 142K, SO 75K. 915/2018 9/5/2018 0.75 PROD3 WHPST WPST P Establish parameters & orient tool 8,160.0 8,167.0 21:30 22:15 face to 20°L at 231 gpm, 1580 psi, FO 16%, PU 142K, SO 103K. Wash down f/ 8160'-8272' MD, tagging w/ 4K. Observe screws shear at 95K SO to set anchor. Set down to 90K. Pick up to 150K confirm anchor set. Slack off to 74K & observe bolt shear. Pick up & confirm release 144K. TOW 8167' MD. 9/5/2018 9/6/2018 1.75 PROD3 WHPST MILL P Mill window from 8167' MD (TOW)- 8,167.0 8,169.0 22:15 00:00 8169' MD w/ 250 gpm, 1830 psi, FO 18%, 100 rpm, 4-8k Tq, WOB 241K. PU 143K, SO 111 K, ROT 117K. SCR @ 8167' MD, 3793' TVD, MW 10.4, 22:00 hrs #1 @30=660@40= 870 psi #2@ 30=660@40= 880 psi 9/6/2018 9/6/2018 8.50 PROD3 WHPST MILL P Mill window from 8169' MD - 8205' 8,169.0 8,205.0 00:00 08:30 MD w/ 250 gpm, 1960 psi, FO 18%, 100 rpm, 4.5k Tq, WOB 6-8K. PU 143K, SO 111K, ROT 117K. 9/6/2018 9/6/2018 2.75 PROD3 WHPST REAM P Dress window 8204'-8165' MD, 250 8,205.0 8,165.0 08:30 11:15 gpm, 1960 psi, FO 18%, 100 rpm, Tq 2-61K, PU 146K, SO 108K wlout pumps. Work tight spot 8178'-8180' MD till clean. 9/612018 916/2018 1.50 PROD3 WHPST CIRC P CBU f/ 8165'-8048' MD, 296 gpm, 8,165.0 8,048.0 11:15 12:45 2270 psi, FO 20%, PU 143K, SO 106K. 9/6/2018 9/6/2018 0.75 PRODS WHPST FIT P Perform FIT to an EMW of 13.4 ppg, 8,048.0 8,048.0 12:45 13:30 TOW 8167' MD, BOW 8188' MD, hole depth 8205' MD, 3792' TVD, MW 10.4+. Pressure up to 575 psi with .7 bible pumped. Shut in & record pressure for 10 minutes. Iniflal shut in pressure 530 psi, final pressure 450 psi. Bled back .6 bbls. Rig down & blow down test equipment. 9/6/2018 9/6/2018 3.50 PROD3 WHPST TRIP P TOH f/ 8048'-157' MD, PU 49K, SO 8,048.0 157.0 13:30 17:00 52K. 9/6/2018 9/6/2018 0.25 PROD3 WHPST OWFF P Monitor well, static. 157.0 157.0 17:00 17:15 9/6/2018 9/6/2018 0.75 PROD3 WHPST BHAH P Lay down window mill BHA as per 157.0 0.0 17:15 18:00 BOT Rep. Recover 60 Ibs of swarf from magnets in the BHA. Window mill bit 3/8" under, lower watermelon mill 1/4" under, & upper watermelon mill was in gauge. Page 27136 Report Printed: 912412018 Operations Summary (with Timelog Depths) 114-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth StartTime End Time our(hr) Phase or, Code Activity Cade Time P -T -X Operation (KKS) End Depth(flKB) 9/6/2018 9/6/2018 0.50 PROD3 WHPST BHAH P Clear & clean dg floor. 0.0 0.0 18:00 18:30 9/6/2018 9/6/2018 1.00 PRODS WHPST WWWH P Pull wear bushing. Make up stack 0.0 0.0 18:30 19:30 wash tool, flush at 854 gpm, 3X. Function VBR's & annular. Lay down stack tool & install 9" ID wear bushing RILDS X2. 9/6/2018 9/6/2018 0.50 PRODS WHPST SVRG P Inspect & service top drive & blocks. 0.0 0.0 19:30 20:00 9/6/2018 9/6/2018 1.50 PRODS WHPST BHAH P Pick up 6-3/4", kick off, motor 0.0 631.0 20:00 21:30 assembly, BHA 10, to 631' MD, PU 58K, SO 62K. 9/6/2018 9/6/2018 0.75 PROD3 WHPST TRIP P TIH f/ 631'-2040' MD, PU 77K, SO 631.0 2,040.0 21:30 22:15 77K. 9/6/2018 9/6/2018 0.50 PROD3 WHPST DHEQ P Shallow hole test MWD, 240 gpm, 2,040.0 2,040.0 22:15 22:45 1257 psi, good. 9/6/2016 9/7/2018 1.25 PROD3 WHPST TRIP P TIH f/ 2040'-5850' MD, PU 130K, SO 2,040.0 5,850.0 22:45 00:00 83K. 9/7/2018 9/7/2018 1.50 PROD3 WHPST TRIP P TIH f/ 5850'-8067' MD, PU 119K, SO 5,850.0 8,067.0 00:00 01:30 82K. 9/7/2018 9/7/2018 0.50 PRODS WHPST CIRC P Orient tool face to 20" L at 57 gpm, 8,067.0 8,205.0 01:30 02:00 1850 psi, FO 18%. Pumps off & drift through window f/ 8067'-8205' MD. 9/7/2018 9/7/2018 5.25 PROD3 DRILL DDRL P Directional drill 3/4" L2 hole f/ 8205' 8,205.0 8,312.0 02:00 07:15 - 8312' MD, 3807' TVD, 240 gpm, 1940 psi, FO 19%, 50 rpm, Tq 6K, WOB 14-8K, ECD -, off btm 1870 psi, PU 119K, SO 82K, ROT 97K, Tq 4K, Max gas 16, ADT 3.41, AST 1.4, Bit 3.41, Jars 181.56 9/7/2018 9/7/2018 0.50 PROD3 DRILL CIRC P Obtain SCR's. Orient tool face to 20" L 8,312.0 8,039.0 07:15 07:45 at 55 gpm, 1815 psi, FO 17%, PU 121 K, SO 79K. Pumps off & drift through window f/ 8312'-8039' MD SCR @ 8311' MD, 3807' TVD, MW 10.4 ppg, 07:00 hrs #1 @ 20 = 670 psi, @ 30 = 900 psi #2 @ 20 = 670 psi, @ 30 = 860 psi 9/7/2018 9/7/2018 0.50 PRODS DRILL CIRC P CBU at 240 gpm, 1850 psi, 40 rpm, Tq 8,039.0 8,039.0 07:45 08:15 1 1 5K, PU 121 K, SO 79K. 9/7/2018 9/7/2018 0.25 PRODS DRILL OWFF P Monitor well, static. 8,039.0 8,039.0 08:15 08:30 9/7/2018 9!7/2018 4.00 PRODS DRILL TRIP P TOH with kick off BHA 10 If 8039'- 8,039.0 631.0 08:30 12:30 631' MD, 9/7/2018 9/7/2018 1.25 PRODS DRILL BHAH P Lay down BHA 10 as per SLB. 631.0 0.0 12:30 13:45 9/7/2018 9/7/2018 0.75 PRODS DRILL BHAH P Clear & clean rig floor. 0.0 0.0 13:45 14:30 9/7/2018 9/7/2018 1.00 PROD3 DRILL BHAH P Make up 6-3/4" RSS BHA per SLB DO 0.0 339.0 14:30 15:30 to 339' MD, PU 52K, SO 58K 9/7/2018 9/7/2018 0.75 PROD3 DRILL TRIP P TIH f/ 339'-1751' MD. 339.0 1,751.0 15:30 16:15 j 9/7/2018 9/7/2018 0.25 PRODS DRILL DHEQ P Shallow hole test MWD 230 gpm, 1,751.0 1,751.0 16:15 16:30 1087 psi, FO 16%. 9/7/2018 9/7/2018 3.50 PRODS DRILL TRIP P TIH f/ 1751'-8211' MD, fill pipe every 1,751.0 8,211.0 16:30 20:00 20 stands. SCR @ 8208' MD, 3794' TVD, MW 10.2 ppg, 19:50 hrs #1 @ 20 = 640 psi, @ 30 = 840 psi #2 @ 20 = 640 psi, @ 30 = 840 psi 9/7/2018 917/2018 0.50 PRODS DRILL SRW P Survey/Log f/ 8211'-8310' MD, 240 8,211.0 8,310.0 20:00 20:30 I I gpm, 1824 psi, FO 18%, 60 rpm, Tq 4K, PU 118K, SO 86K, ROT 96K. Page 28136 Report Printed: 9/24/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Corte Time P -T -X Operation Start Depth (ftKB) End Dept (ftKB) 9/7/2018 9/7/2018 1.25 PROD3 DRILL DISP P Displace well to new 10.2 ppg 8,310.0 8,312.0 20:30 21:45 FLOPRO NT mud at 250 gpm, 1838 psi, FO 18%, 60 rpm, Tq 4K. 9/7/2018 9/8/2018 2.25 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 8312' 8,312.0 8,410.0 21:45 0000 - 8410' MD, 3804' TVD, 250 gpm, 1830 psi, FO 19%, 120 rpm, Tq 7K, WOB 2-8K, ECD 11.48, off btm 1833 psi, PU 121 K, SO 82K, ROT 99K, Tq 7K, Max gas 120, ADT 1.21, Bit 1.21, Jars 1.21 9/8/2018 9/8/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 8410' 8,410.0 8,840.0 00:00 06:00 - 8840' MD, 3816' TVD, 250 gpm, 1880 psi, FO 19%,150 rpm, Tq 8K, WOB 2K, ECD 11.6, off Mat 1870 psi, PU 120K, SO 82K, ROT 99K, Tq 7K, Max gas 120, ADT 3.711, Bit 4.92, Jars 4.92 9/8/2018 9/8/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 8840' 8,840.0 8,989.0 06:00 12:00 - 8989' MD, 3825' TVD, 270 gpm, 2116 psi, FO 19%, 100 rpm, Tq 9K, WOB 2-9K, ECD 11.45, off btm 2079 psi, PU 120K, SO 82K, ROT 99K, Tq 7K, Max gas 301, ADT 3.99, Bit 8.91, Jars 8.91 SCR @ 8882' MD, 3820' TVD, MW 10.2 ppg, 07:45 hrs #1 @ 20 = 420 psi, @ 30 = 620 psi #2 @ 20 = 420 psi, @ 30 = 620 psi 9/8/2018 9/8/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 8989' 8,989.0 9,330.0 12:00 18:00 - 9330' MD, 3841' TVD, 270 gpm, 2172 psi, FO 19%, 100 rpm, Tq 9K, WOB 1-10K, ECD 11.57, off btm 2166 psi, PU 132K, SO 76K, ROT 102K, Tq 8K, Max gas 63, ADT 4.57, Bit 13.48, Jars 13.48 9/8/2018 9/9/2018 6.00 PROD3 DRILL DDRL P Directional drill 3/4" L2 hole f/ 9330' 9,330.0 9,895.0 18:00 00:00 - 9895' MD, 3851' TVD, 270 gpm, 2170 psi, FO 19%, 140 rpm, Tq 9K, WOB 1-10K, ECD 11.97, off btm 2160 psi, PU 133K, SO 71K, ROT 102K, Tq 8K, Max gas 33, ADT 4.07, Bit 17.55, Jars 17.55 SCR @ 9737' MD, 3849' TVD, MW 10.1 ppg, 22:30 hrs #1 @ 20 = 480 psi, @ 30 = 700 psi #2 @ 20 = 500 psi, @ 30 = 710 psi 9/9/2018 9/9/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole N 9895' 9,895.0 10,360.0 00:00 06:00 - 10360' MD, 3868' TVD, 270 gpm, 2250 psi, FO 19%, 100 rpm, Tq 9K, WOB 2-8K, ECD 11 97, off Dim 2200 psi, PU 132K, SO 68K, ROT 96K, Tq 8K, Max gas 22, ADT 4.91, Bit 22.46, Jars 22.46 9/9/2018 9/9/2018 6.00 PROD3 DRILL DDRL P Directional drill 3/4" L2 hole f/ 10,360.0 10,591.0 06:00 1200 10360'- 10591' MD, 3890' TVD, 270 gpm, 2290 psi, FO 19%,140 rpm, Tq 9K, WOB 2-81K, ECD 12.04, off btm 2285 psi, PU 134K, SO 76K, ROT 97K, Tq 8K, Max gas 107, ADT 4.58, Bit 27.04, Jars 27.04 SCR @ 10400' MD, 3870' TVD, MW 10.2 ppg, 08:00 his #1 @ 20 = 510 psi, @ 30 = 700 psi #2 @ 20 = 520 psi, @ 30 = 710 psi Page 29/36 ReportPrinted: 9/24/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth(%Ka) 9/9/2018 9/9/2018 6.00 PROD3 DRILL DDRL P Directional drill 3/4" L2 hole f/ 10,591.0 10,951.0 12:00 1800 10591'- 10951' MD, 3921' TVD, 270 gpm, 2380 psi, FO 19%, 140 rpm, Tq 9K, WOB 2-8K, ECD 12.08, off btm 2300 psi, PU 135K, SO 73K, ROT 100K, Tq 8K, Max gas 77, ADT 4.94, Bit 31.98, Jars 31.98 9/9/2018 9/10/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 10,951.0 11,211.0 1800 0000 10951'- 11211' MD, 3914' TVD, 270 gpm, 2350 psi, FO 19%, 140-100 rpm, Tq 9K, WOB 2-8K, ECD 12.05, off btm 2320 psi, PU 137K, SO 76K, ROT 96K, Tq 8K, Max gas 66, ADT 5.31, Bit 37.29, Jars 37.29 SCR @ 10972' MD, 3923' TVD, MW 10.2 ppg, 19:15 hrs #1 @ 20 = 500 psi, @ 30 = 700 psi #2 @ 20 = 490 psi, @ 30 = 680 psi 9/10/2018 9/10/2018 6.00 PROD3 DRILL DDRL P Directional drill 3/4" L2 hole f/ 11,211.0 11,460.0 00:00 06:00 11211'- 11460' MD, 3901' TVD, 270 gpm, 2350 psi, FO 19%,120-100 rpm, Tq 8K, WOB 2-6K, ECD 12.0, off btm 2320 psi, PU 135K, SO 68K, ROT 98K, Tq 8K, Max gas 180, ADT 4.77, Bit 42.06, Jars 42.06 OA 160 psi 9/10/2018 9/10/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 11,460.0 11,789.0 06:00 12:00 11460'- 11789' MD, 3875' TVD, 270 gpm, 2409 psi, FO 19%, 150 rpm, Tq 8.6K, WOB 2-10K, ECD 12.18, off btm 2400 psi, PU 136K, SO 65K, ROT 100K, Tq 8.4K, Max gas 183, ADT 4.39, Bit 46.45, Jars 46.45 SCR @ 11636' MD, 3890' TVD, MW 10.2 ppg, 10:00 hrs #1 @ 20 = 560 psi, @ 30 = 740 psi #2 @ 20 = 540 psi, @ 30 = 720 psi 9/10/2018 9/10/2018 6.00 PROD3 DRILL DDRL P Directional drill 3/4" L2 hole f/ 11,789.0 12,047.0 12:00 18:00 11789'- 12047' MD, 3866' TVD, 270 gpm, 2423 psi, FO 20%,150 rpm, Tq 10K, WOB 1-12K, ECD 12.23, off btm 2405 psi, PU 136K, SO 64K, ROT 98K, Tq 8.5K, Max gas 265, ADT 5.09, Bit 51.54, Jars 51.54 OA 155 psi 9/10/2018 9/11/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 12,047.0 12,270.0 18:00 00:00 112047'- 12270' MD, 3856' TVD, 270 gpm, 2450 psi, FO 20%,150 rpm, Tq 8K, WOB 1-12K, ECD 12.25, off btm 2420 psi, PU 137K, SO 62K, ROT 96K, Tq 8.5K, Max gas 36, ADT 5.0, Bit 56.54, Jars 56.54 SCR @ 11636' MD, 3890' TVD, MW 10.2 ppg, 10:00 hrs #1 @ 20 = 560 psi, @ 30 = 740 psi #2 @ 20 = 540 psi, @ 30 = 720 psi 9/11/2018 9/11/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 12,270.0 12,766.0 00:00 0600 12270' MD, 3856' TVD - 12,766' MD 3,833' TVD, 270 gpm, 2500 psi, FO 20%, 150 rpm, Tq 8K, WOB 1-6K, ECD 12.28, off btm 2480 psi, PU 142K, SO 53K, ROT 90K, Tq 8.5K, Max gas 46, ADT 4.36, Bit 60.9, Jars 60.9 Page 30136 Report Printed: 9124/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stall Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation Stan Depth (flKB) End Depth(ftKB) 9/11/2018 9/11/2018 6.00 PRODS DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 12,766.0 13,460.0 06:00 1200 12,766' MD 3,833' TVD - 13,460' MD 3,836' TVD, 270 gpm, 2631 psi, FO 21%, 170 rpm, Tq 11.5K, WOB 1-81K , ECD 12.37, off btm 2630 psi, PU 150K, SO OK, ROT 103K, Tq 9K, Max gas 330. ADT 4.23, Bit 65.13, Jars 65.13 SCR @ 12,773' MD, 3834' TVD, MW 10.2 ppg, 0600 hrs #1 @ 20 = 540 psi, @ 30 = 740 psi #2 @ 20 = 520 psi, @ 30 = 720 psi 9/11/2018 9/11/2018 6.00 PROD3 DRILL DDRL P Directional drill 63/4"L2 holef/ - 13,460.0 14,1020 12:00 18:00 13,460' MD 3,836' TVD - 14,107' MD 3,911' TVD, 270 gpm, 2765 psi, FO 20%, 170 rpm, Tq 9K, WOB 1-7K, ECD 12.86, off btm 2,745 psi, PU 163K, SO OK, ROT 103K, Tq 10K, Max gas 189. ADT 4.13, Bit 69.26, Jars 69.26 9/11/2018 9/12/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 14,107.0 14,442.0 18:00 0000 14,107' MD 3,911' ND - 14,442' MD 3,909' TVD, 270 gpm, 2,917 psi, FO 20%, 130 rpm, Tq 9K, WOB 2-14K, ECD 12.76, off btm 2,900 psi, PU 167K, SO OK, ROT 106K, Tq 9K, Max gas 71. ADT 4.93, Bit 74.19, Jars 74.19 SCR @ 14,353' MD, 3906' TVD, MW 10.2 ppg, 2230 hrs #1 @ 20 = 640 psi, @ 30 = 880 psi #2 @ 20 = 600 psi, @ 30 = 860 psi 9/12/2018 9/12/2018 6.00 PROD3 DRILL DDRL P Directional drill 3/4" L2 hole f/ 14,442.0 14,932.0 00:00 0600 14,442' MD 3,909' TVD - 14,932' MD 3,862' TVD, 270 gpm, 3,041 psi, FO 20%,130 rpm, Tq 9.8K, WOB 6K, ECD 12.78, off btm 2,989 psi, PU 170K, SO OK, ROT 105K, Tq 9K, Max gas 39. ADT 4.49, Bit 78.68, Jars 78.68 9/12/2018 9/12/2018 6.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole t/ 14,932.0 15,637.0 06:00 12:00 14,932' MD 3,862' TVD - 15,637' MD 3,857' TVD, 270 gpm, 3,175 psi, FO 20%,120 rpm, Tq 10K, WOB 6K, ECD 13, off btm 3,168 psi, PU 192K, SO OK, ROT 110K, Tq 10K, Max gas 279. ADT 4.46, Bit 83.14, Jars 83.14 SCR @ 15,000' MD, 3,860' TVD, MW 10.2 ppg, 0615 hrs #1 @ 20 = 680 psi, @ 30 = 920 psi #2 @ 20 = 660 psi, @ 30 = 900 psi Page 31136 Report Printed: 9/24/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartTime End Tyne Our (hr) M Cada op C Activity Code Time P -T -X Operatlan start rt De Stan Depm End Depm (N(B) 9/12/2018 9/12/2018 3.00 PROD3 DRILL DDRL P Directional drill 6 3/4" L2 hole f/ 15,637.0 15,872.0 12:00 15:00 15,637' MD 3,857' TVD - 15,872' MD 3,864' TVD, 270 gpm, 3,269 psi, FO 20%,120 rpm, Tq 10K, WOB 8K, ECD 13.02, off btm 3,268 psi, PU 189K, SO OK, ROT 114K, Tq 10K, Max gas 53. ADT 2.14, Bit 85.28, Jars 85.28 SCR @ 15,822' MD, 3,867' TVD, MW 10.2 ppg, 1700 hrs #1 @ 20 = 720 psi, @ 30 = 1,000 psi #2 @ 20 = 680 psi, @ 30 = 960 psi 9/12/2018 9/12/2018 1.50 PROD3 CASING CIRC P Rotate and reciprocate from 15,872' 15,872.0 15,872.0 15:00 16:30 MD - 15,827' MD 270 GPM @ ICP 3,269 PSI - FCP = 3,236 PSI. IECD = 13.02, FECD = 12.8 EMW. 120 RPM 8.5K TQ. UP WT=183K, DWN WT= 0, ROT WT = 105K. total stks pumped = 5,010. 9/12/2018 9/12/2018 0.50 PROD3 CASING OWFF P OWFF (drop 4'). 15,872.0 15,872.0 16:30 17:00 9/12/2018 9/13/2018 7.00 PROD3 CASING BKRM P BKRN OOH from 15,872' MD -13,0001 15,872.0 13,000.0 17:00 00:00 MD with 270 GPM @ 3,236 PSI. 20% F/O, 120 RPM 8.5K TQ, 105K ROT, UP WT = 125K w/pumps. 9/13/2018 9/13/2018 11.50 PRODS CASING BKRM P BKRM OOH from 13,100' MD - 8,507' 13,000.0 8,507.0 00:00 11:30 MD. 270 GPM @ ICP 2,600 PSI, 20% F/O, 120 RPM, 5-7K TQ, ECD = 11.73, UP WT = 95K pumps on. 9/13/2018 9/13/2018 0.50 PROD3 CASING TRIP P POOH on elevators from 8,507' MD - 8,507.0 8,032.0 11:30 12:00 8,032' MD. pulling BHAthrough window. UP WT= 125K, DWN WT= 83K, Monitor clap via TT. No overpull witnessed. 9/13/2018 9/13/2018 2.00 PROD3 CASING CIRC P Pump out stand 81 and rack back. 8,032.0 7,936.0 12:00 14:00 ROT/Recip while weight up to 10.4 PPG, frin 7,840'-7,936' MD. 270 GPM @ 2,088 PSI, 17% F/O, 11.95 ECD, 120 RPM 5K TQ. UP WT = 120K, DWN WT=83K, ROT WT=95K Total stks = 5,786 pumped. 9/13/2018 9/13/2018 0.50 PROD3 CASING OWFF P OWFF. (static) pump dry job. BD/TD. 7,936.0 7,936.0 14:00 14:30 9/13/2018 9/13/2018 0.50 PRODS CASING SVRG P Service TO. 7,936.0 7,936.0 14:30 15:00 9/13/2018 9/13/2018 6.00 PRODS CASING PULD P POOH on elevators from 7,936' MD to 7,936.0 339.0 15:00 21:00 339' MD laying down sideways 4" OR UP WT=120K, DWN WT=83K. Monitor disp via TT. 9/13/2018 9/13/2018 1.50 PROD3 CASING SHAH P Break down and lay down 6 3/4" L2 339.0 0.0 21:00 22:30 drilling BHA. 9/13/2018 9/13/2018 0.50 50MPZ3 FISH BHAH P MU Baker BHA for whipstock retrieval 0.0 0.0 22:30 23:00 while scribe tool face. 9/13/2018 9/14/2018 1.00 COMPZ3 FISH TRIP P RIH with whipstock retrieval system on 0.0 1,300.0 23:00 00:00 1 4" DP from Derrick. 9/14/2018 9/14/2018 3.50 COMPZ3 P Continue to trip in hole with whipstock 1,300.0 8,148.0 00:00 03:30 JFISW7P retrieval system from 1,300' MD - 8,148' MD UP WT = 140K DWN WT = 109K. Monitor disp via TT. Page 32136 Report Printed: 9/24/2018 Operations Summary (with Timelog Depths) IH -104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time Enol Time Dur (m) Phase Op Code Adivily Code Time P -T -X Operation Start Depth (XKB) Enol Depth(RKB) 9/14/2018 9/14/2018 0.50 COMPZ3 FISH FISH P Orient tool face to wash whipstock 8,148.0 8,172.0 03:30 0400 slot. reciprocate at 250 GPM 1,980 PSI to 8,172' MD. Orient and latch whipstock 20 DEG left. Slack off 1 OK OWN WT then pull 1 OK over to confirm hook. Pull 40K over slowly to allow for jars to bleed. Pull 80K straight pull and sheared at 75K. Stand back stand 142K UP WT. 9/14/2018 9/14/2018 2.00 COMPZ3 FISH CIRC P Circulate 2 bottoms up at 250 GPM 8,172.0 8,080.0 04:00 06:00 1,550 PSI. 5,000 STKS pumped 9/14/2018 9/14/2018 2.50 COMPZ3 FISH OWFF T OWFF-- Observe flow back @ 5.95 8,080.0 8,248.0 06:00 08:30 BPH. reduce to .45 BPH. 9/14/2018 9/14/2018 0.25 COMPZ3 FISH CIRC T Stage pumps up to 200 GPM @ 1,171 8,248.0 8,248.0 08:30 08:45 PSI with 17% F/O. Observe erratic returns with 3 BBL pit gain. and 1,555 units of gas. Shut down pumps and observe perculating fluid. fluid level dropped 1'. 9/14/2018 9/14/2018 0.50 COMPZ3 FISH OWFF T Close annular and monitor DPP and 8,248.0 8,248.0 08:45 09:15 casing pressure for 30 min. observe 0 PSI. 9/14/2018 9/14/2018 1.75 COMPZ3 FISH CIRC T Circulate through choke at 4 BPM, 8,248.0 8,248.0 09:15 11:00 171 GPM, ICP 880 PSI, FCP 900 PSI. Total STKS pumped 3,165. Loss of 8 BBLS during circ. 9/14/2018 9/14/2018 0.50 COMPZ3 FISH OWFF T OWFF. Monitor pressure observe 0 8,248.0 8,248.0 11:00 11:30 PSI gain on choke and DP 9/14/2018 9/14/2018 1.50 COMPZ3 FISH CIRC T Open bag and circulate at 200 GPM 8,248.0 8,248.0 11:30 13:00 1,183 PSI with 15% F/O while increasing MW to 10.4 PPG. total stks pumped 4,434 with a 7 BBL loss during circ. 9/14/2018 9/14/2018 0.25 COMPZ3 FISH OWFF T OWFF. note 6 BBL bleed back. 8,248.0 8,248.0 13:00 1315 9/14/2018 9/14/2018 1.00 COMPZ3 FISH CIRC T Continue to circ BU with 10.5 PPG @ 8,248.0 8,248.0 13:15 14:15 180 GPM 966 PSI 15% F/O, total stks pumped 2,538. Observe no gas to surface 10 BBL loss during circ. 9/14/2018 9/14/2018 2.50 COMPZ3 FISH OWFF T Observe well for flow. Rate decreased 8,248.0 8,248.0 14:15 16:45 from 15 BPH - .16 BPH. Good to go. 9/14/2018 9/14/2018 4.50 COMPZ3 FISH TRIP P Drop 1.875" rabbit and POOH on 8,248.0 173.0 16:45 21:15 elevators from 8,248' MD - 173' MD. Monitor disp via TT. recover drift in stnd#1. 9/14/2018 9/14/2018 0.25 COMP73 FISH OWFF P OWFF. Observe gas breaking out. 173.0 173.0 21:15 21:30 Fluid level dropped 2'. 9/14/2018 9/15/2018 2.50 COMPZ3 FISH BHAH P LD whipstock BHA system as per 173.0 0.0 21:30 00:00 1 Baker rep. Monitor disp via TT. 9/15/2018 9/15/2018 1.50 COMPZ3 FISH BORE T Test BOPE to 250/3,500 PSI F 5/5 0.0 0.0 00:00 01:30 charted min with exception of Superchoke t 2,000 PSI, W 4 and 4/1/2" test joint. choke valves 1,3,5,6 test witness waived by Bob Noble. Sim ops clean rig floor. 9/15/2018 9/15/2018 0.50 COMPZ3 CASING BOPE T Pull test plug and set wear bushing. 0.0 0.0 01:30 0200 9/15/2018 9/15/2018 2.00 COMPZ3 CASING SLP C P Slip and cut 75' Drill line 0.0 0.0 02:00 0400 9/15/2018 9/15/2018 0.50 COMPZ3 CASING SVRG P Service rig and c/o washpipe, test 0.0 0.0 04:00 04:30 same to 3,500 PSI, Page 33/36 Report Printed: 9124/2018 Operations Summary (with Timelog Depths) 1H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time Dur hr)Phase Op Cotle Adivity Cotle Time P -T -X Operation (ftKB) End Depth(ttKB) 9/15/2018 9/15/2018 9.00 COMPZ3 CASING PUTB P PJSM and RIH with 4 1/2" 12.6# L-80 0.0 5,700.0 04:30 1330 IBTM liner to 4,807' MD' Monitor disp via TT UPWT=81K DWNWT= 72K, 9/15/2018 9/15/2018 0.50 COMPZ3 CASING SVRG P Lubricate pipe skate 5,700.0 5,700.0 13:30 1400 9/15/2018 9/15/2018 2.50 COMPZ3 CASING PUTB P Continue to RIH with 4 1/2" L-80 12.5# 5,700.0 7,640.0 14:00 1630 IBTM liner from 5,700' MD - 7,640' MD. UP WT=96K DWN WT=78K. Monitor disp via TT 9/15/2018 9/15/2018 0.50 COMPZ3 CASING OTHR P PU/MU Baker flanged hook hanger 7,640.0 7,690.0 16:30 1700 and SLMD slimpulse MWD. Orient & RIH from 7,640' MD - 7,690' MD UP WT=96K DWN WT=78K Monitor disp via TT. 9/15/2018 9/15/2018 0.50 COMPZ3 CASING DHEQ P RIH with lower completion on 4" DP 7,690.0 8,132.0 17:00 17:30 7,690' MD - 8,132' MD Shallow hole test MWD at 86 GPM, 315 PSI 12% F/O. Passed. 9/15/2018 9/15/2018 5.00 COMPZ3 CASING RUNL P RIH with L2 lower completion from 8,132.0 15,655.0 17:30 22:30 8,132' MD- 15,655' MD UP WT - 160K. DWN WT = 87K. Monitor disp via TT 9/15/2018 9/16/2018 1.50 COMPZ3 CASING HOSO P Kelly up and wash down from 15,655' 15,655.0 15,827.0 22:30 00:00 MD while orienting to 180 deg. Wash down 5' past window (shoe depth) 15,830' MD. PU above window and orient 24 DEG left.. Set hook hanger at shoe depth of 15,827' MD with 20K dwn M. P/U 15' and confirm tag. Observe toolface rool to 18 DEG L. Drop 29/32" ball and pump down at 3 BPM, 1,070 PSI 9/16/2018 9/16/2018 0.75 COMPZ3 CASING HOSO P Continue to pump 29/32" ball down 15,827.0 15,827.0 00:00 00:45 follow BOT pup schedule. Final rate of 1 BPM ball on seat at 703 stks. Pressure up and shear out ball set at 4,430 PSI. raise rate to 2 BPM and PU above liner top to 8,150' MD UP WT = 139K, DWN WT = 105K. 9/16/2018 9/16/2018 1.50 COMPZ3 WELLPR DISP P Circulate while reciprocate form 8,150- 8,150.0 8,150.0 00:45 02:15 8,040' MD. Displace well f/10.4 PPG brine @ 340 GPM, 2,100 PSI, 24% F/O, max gas = 3,370 units. Total stks pumpede 4,180. MW in = 10.4 MW out = 10A UP WT = 135K, DWN WT = 113K. 9/16/2018 9/16/2018 0.75 COMPZ3 WELLPR CRIH P Spot 20 BBLS Cito 7,150' MD. Chase 8,150.0 8,150.0 02:15 03:00 with 76 BBLS brine at 5 BPM, 5 BPM 650 PSI. 16% F/O. 9/16/2018 9/16/2018 0.50 COMPZ3 WELLPR OW FF P OWFF. Timed flow back with 8,150.0 8,150.0 03:00 0330 diminishing rate. start 1gt/10 sec - i QT/44 SEC. prep to POOH. 9/16/2018 9/16/2018 2.50 COMPZ3 WELLPR TRIP P POOH from 8,150 MD - 1,985' MD. 8,150.0 1,985.0 03:30 0600 Monitor disp via TT UP WT = 73K, DWN WT = 75K. 9/16/2018 9/16/2018 1.00 COMPZ3 WELLPR TRIP P POOH from 1,985' MD - 85' MD. 1,985.0 85.0 06:00 0700 Monitor disp via TT. 9/16/2018 9/16/2018 0.75 COMPZ3 WELLPR BHAH P Lay down liner running tools and 85.0 0.0 07:00 07:45 slimpulse MWD. Clean rig floor and prep for ZXP/LEM 9/16/2018 9/16/2018 1.00 COMPZ3 RWRID RURD P RU GBR casing running tools and TO 0.0 0.0 07:45 08:45 turn equipment. Page 34136 Report Printed: 9/2412018 Operations Summary (with Timelog Depths) IH -104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log ataM1 Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (fixe) End Death(ftKa) 9/16/2018 9/16/2018 2.25 COMPZ3 RWRID PUTB P PJSM / MU L2 LEM/ZXP as per 0.0 303.0 08:45 11:00 detail from 0- 269' MD. Monitor disp via TT. Slimpulse and liner top pkr. UP WT = 48K, DIAN WT = 53K. 9/16/2018 9/16/2018 5.00 COMPZ3 RWRID RCST P RIH with LEM/ZXP from 303' MD to 303.0 8,192.0 11:00 1600 8,192' MD on 4" DP out of derrick. UP WT= 142K DWN WT= 113K. Monitor disp via TT. 9/16/2018 9/16/2018 0.75 COMPZ3 RWRID RCST P Wash down from 8,192 MD - 8,287' 8,192.0 8,302.0 16:00 16:45 MD with 120 GPM 603 PSI, 12% F/O. orient to 60 DEG L high side. Wash down to 8,302' MD set dwn 15K. Observed shift to 30 DEG left high side. Pulled up IOK over pull to confirm latch. Set down 10K. 9/16/2018 9/16/2018 0.75 COMPZ3 RWRID PACK P Drop 1.625 OD ball and pump dwn at 8,302.0 8,302.0 16:45 17:30 3BPM 738 PSI 10% F/O. Reduce rate at 400 STKS. to 2 BPM, 330 PSI, 9% F/O. Ball on seat at 609 stks. Pressure up to 4,000 PSI and set PKR & release. bleed pressure to 0 PSI. 9/16/2018 9/16/2018 1.00 COMPZ3 RWRID PRTS P Pick up 1' with 140K UP WT to confirm 8,302.0 8,004.0 17:30 18:30 release. close upper rams. Pump down kill line and pressure test IA to 3,500 PSI charted. (PASSED). LD 3 singles. 9/16/2018 9/16/2018 0.50 COMPZ3 RWRID OWFF P OWFF. Note fluid dropped 1'. 8,004.0 8,004.0 18:30 19:00 9/16/2018 9/17/2018 5.00 COMPZ3 RWRID PULD P POOH laying down 4" DP sideways 8,004.0 4,830.0 19:00 00:00 from 8,004' MD - 4,830' MD. Removing SS on rig floor. monitor disp via TT. UP WT = 92K, DNW WT = 84K. 9/17/2018 7.75 COMPZ3 RWRID PULD P Continue to POOH laying down 4,830.0 0.0 19/17/2018 00:00 07:45 singles and pulling super sliders off on rig floor. Monitor disp via TT. UP WT =64K, DWN WT=66K. 9/17/2018 9/17/2018 0.75 COMPZ3 RWRID BHAH P LD Baker (inner running tools and 0.0 0.0 07:45 08:30 wash stack. BD top drive 9/17/2018 9/17/2018 0.50 COMPZ3 RPCOMP WWWH P Wash stack pull wear ring. 0.0 0.0 08:30 09:00 9/17/2018 9/17/2018 2.00 COMP73 RPCOMP RURD P RIG up SLB control line systems 0.0 0.0 09:00 11:00 clamps/and GBR running equip. Rig up to RIH with 4 1/2" 12.6# L-80 IBTM upper completion. 9/17/2018 9/18/2018 13.00 COMPZ3 RPCOMP PUTB P PU/MU4 1/2" 12.6# L-80 IBTM upper 0.0 7,039.0 11:00 00:00 completion a RIH from surface to 7,039' MD with DHG wire conection testing realtime to 9,500 PSI. Install clamps on every collar. At 3,400' UP WT=74K DNW WT=72K. Monitoring disp via TT UP WT = 94K DWN WT = 78K. 9/18/2018 9/18/2018 1.75 COMPZ3 RPCOMP PUTB P Continue to RIH with 4 1/2" L-80 12.6# 7,039.0 8,020.0 00:00 01:45 (BTM upper completion from 7,039' MD to 8,020' MD. (stall clamps on every collar and TQ all conneciton to 4,500 Ft/LBS. Monitor disp via TT. UP WT = 98K, DWN WT = 78K. Total full cannon clamp count = 267. Total half clamps = 6 Page 35136 ReportPrinted: 9/24/2018 Operations Summary (with Timelog Depths) 1 H-104 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time our On Phase Op Code Activity Code Time P -T -X Operation Stan Depth (MB) End Depth(flKB) 9/18/2018 9/18/2018 1.00 COMP23 RPCOMP HOSO P Bring on pumps to 1 BPM and wash 8,020.0 7,963.0 01:45 02:45 down from 8,020' MD to observe seals enter seal asym at 8,036.47' MD, DO pumps and no go out at 8,054.15 MD. with 20K DWN WT LD 4 joints to 7,963' MD 9/18/2018 9/18/2018 1.50 COMPZ3 RPCOMP HOSO P MU space out pups of 7.82' / 3.90' rig 7,963.0 7,963.0 02:45 04:15 up circ lines / hanger / landing joint. 9/18/2018 9/18/2018 1.25 COMPZ3 RPCOMP CRIH P Circulate and spot corrosion inhibitor 7,963.0 7,963.0 04:15 0530 145 BELS. 4 BPM @ 245 PSI, 12 F/0. chase with 120 BBLS brine. simops with termination of tech wire. 9/18/2018 9/18/2018 1.50 COMPZ3 RPCOMP WWSP P LAnd hanger and RILDS. PT upper / 7,963.0 8,054.0 05:30 0700 lower seals to 5,000 PSI for 10 min each. 9/18/2018 9/18/2018 2.00 COMPZ3 RPCOMP PRTS P PT IA to 1,000 PSI for 5 min to confirm 8,054.0 8,054.0 07:00 09:00 seals are fully located , bleed off psi . Drop B&R and r/U to test tog. Test TBG to 3,500 PSI for 30 Charted min. Bleed off tbg to 2,100 PSI and pressure test IA to 3,500 charted PIS for 30 min. Bleed off tbg and shear SOV. 9/18/2018 9/18/2018 1.00 COMPZ3 WHDBOP MPSP P LD landing joint and install BPV. / 8,054.0 8,054.0 09:00 10:00 jPressure test BPV to 2,500 PSI from below for 5 min. 9/18/2018 9/18/2018 2.00 COMPZ3 WHDBOP OTHR P LD mouse hole and pull riser. Install 8,054.0 8,054.0 10:00 12:00 drip nipple 9/18/2018 9/18/2018 1.50 COMPZ3 WHDBOP NUND P ND BOPE 0.0 0.0 12:00 13:30 9/18/2018 9/18/2018 2.00 COMPZ3 WHDBOP NUND P Clean well head and install test dart. 0.0 13:30 15:30 MU tree as per Vetco rep. 9/18/2018 9/18/2018 2.50 COMPZ3 WHDBOP PRTS P PT void on tree/ hanger seals / to 15:30 18:00 5,000 PSI for 10 min as per Vetco rep. Finalize termination of tech wire and verify reading PSI and tempurature. CO rep verify test. 9/18/2018 9/18/2018 3.25 COMPZ3 WHDBOP FRZP P PJSM / Pull test dart / ru and freeze 18:00 21:15 protect well IA -Tub with 112 BBLS diesel at 3 BPM 1,650 PSI final 2.5 BPM @ 2,000 PSI holding 100 PSI BP. Install BPV and test same to 1,500 PSI from direction of Flow. RD lubricator. Final pressures read before installing BPV were tubing 250 psi, IA 30 psi and OA= 0 psi. 9/18/2018 9/19/2018 2.75 DEMOB MOVE RURD P Clean cellar while prepping to move 21:15 00:00 rig. Rig release 2359 hrs. Page 36/36 ReportPrinted: 9/24/2018 NADConversion Kuparuk River Unit Kuparuk 1H Pad 1 H-104 1H-104 ConocoPhillips Definitive Survey Report 10 September, 2018 Final Definitive Survey Verified and Signed -off Ali targets and/or well position objectives have been achieved. Ed yes I7 No I have checked to the best of my abilty that the following data is correct.' -1 Surface Coordinates Declination & Convergence J GRS Surrey Corrections —_ Survey Tool Codes Brandon Temple Digitally018.8301d by Brard:1029 0800' e SLB DE r' Date :2018.083010:1029-0900' 5rart�-s=�— Client Representative: scott.a.brunswick@conocophillips.corf---•^ Date: vill'XXX.MMMI ConocoPhillips I ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Referonce: Well Rig: 1H-104 Project: Kuperuk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Site: Kupemk 1H Pad MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: 1H-1 D4 Survey Calculation Method: Minimum Curvature Design: 1 H-104 Database: OAKEDMP2 rroject Kupamk River Unit, North Slope Alaska, United States Asp System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Asp Zone: Alaska Zone 04 Using geodetic scale factor Nell Rig: 1H -1D4 From To Audit Notes: (usft) (usft) Survey (Wellbore) Nell Position +WS 0.00 usft Northing: 5,980,782.43 usft Latitude: 70' 21'29.809 f Depth From (TVD) +E/ -W 0.00 usft Easting: 549,568.74 usft Longitude: 149' 35'50.655 V rosition Uncertainty 10,809.00 1 H-1 04PB 1 Srvy 6-0UAL+GMAG+SAG 0.00 usft Wellhead Elevation: usft Ground Level: 54.10 ustl Weibom 1H-104 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (9 (1 (nT) BGGM2018 8/15/2018 17.04 80.01 57,448 Design 1H-104 Data From To Audit Notes: (usft) (usft) Survey (Wellbore) Tool Name 130.47 Version: 1.0 Phase: ACTUAL Te On Depth: 10,809.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction MWD+IFR2+HDS+MS (usft) (usft) (usft) (I 10,809.00 1 H-1 04PB 1 Srvy 6-0UAL+GMAG+SAG 38.69 0.00 0.00 67.27 Survey Program Data From To (usft) (usft) Survey (Wellbore) Tool Name 130.47 1,098.56 1H-104 Srvy 1 - SLB _GWD70 (1H-104PS GYD-GCSS 1,194.67 1,804.101H-104 Srvy 2-SLB_WD+GMAG(1 H- M MWD+IFR-AK-CAZ-SC 1,901.24 1,901.241H-104 SrW 3-SLB_MWD-INC-ONLY_F MWD-INC_ONLY 1,977.75 9,446.781H-104 Srvy 4- SLB _DUAL+GMAG+SA MWD+IFR2+HDS+MS 9,484.37 9,484.371H-104 Srvy 5-SLB_MWD_INC-Only-Fi MWD-INC_ONLY 9,579.45 10,809.00 1 H-1 04PB 1 Srvy 6-0UAL+GMAG+SAG MWD+IFR2+HDS+MS 10,831.11 15,954.201H-104 Srvy 7-SLB_DUAL+GMAG+SA MWD+IFR2+HDS+MS Description Survey Date Gymclata gyro single shots 8/6/2018 10:47:1 MWD+IFR AK CAZ SCC 8/6/2018 10:55:( MWD-INC_ONLY_FILLER 8/9/2018 10:05:( OWSG MWD + IFR2 + HDS + Multi -Station Conece/9/2018 10:07:( MWD-INC_ONLY_FILLER 8/16/2018 10:07 OWSG MWD + IFR2 + HDS + Mufti -Station Correc8/18/2018 10:07 OWSG MWD + IFR2 + HDS + Multi -Station Correc8/17/2018 11:31: Survey Map Map vertical MD bac AN TVD TVDSS +NIS +E/ -W Northing Fasting DLS Section (usft) (') (1) (WIN) (usft) (usft) (usft) (to (ft) (°/1001 (it) Survey Tool Name 38.69 D.DO 0.00 38.69 54.10 0.00 0.00 5,980,782.43 549,568.74 0.00 0.00 UNDEFINED 130.47 0.03 108.52 130.47 37.68 -0.01 0.02 5,980,782.42 549,558.76 0.03 0.02 GYD-GCSS(1) 170.09 0.12 87.41 170.09 77.30 4.01 0.07 5,980,782.42 549,568.81 0.23 0.06 GYD-GCSS 01 259.84 2.03 116.87 259.82 167.03 -0.72 1.59 5,960,781.72 549,570.33 2.15 1.18 GYD-GCSS(1) 357.41 4.01 124.19 357.25 264.46 5.42 5.95 5,980,779.05 549,574.71 2.06 4.17 GYD-GCSS(1) 449.01 5.79 114.28 448.51 355.72 -7.12 12.81 5,980,775.39 549,581.60 2.14 9.06 GYD-GC-SS(1) 540.15 6.91 118.50 539.09 446.30 -11.63 21.82 5,980,770.95 549,590.64 1.33 15.63 GYD-GCSS(1) 631.94 8.38 116.36 630.06 537.27 -17.23 32.67 5,980,765.42 549,601.52 1.63 23.47 GYD-GCSS(1) 722.47 10.68 118.44 719.34 626.55 -24.16 45.96 5,980,758.58 649,614.85 2.57 33.05 GYD-GCSS(1) 9/10/2018 3:00:31PM Page 2 COMPASS 5000.14 Build 85 i I ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Project: Kupamk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: 1 H-104 actual @) 92.79usft (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: 1H-104 Survey Calculation Method: Minimum Curvature Design: 1 H-104 Database: OAKEDMP2 Survey Map Map vertical MD Inc AN TVD TVDSS +WS +E.1 -W Northing Easting DLS Section WOO (•) (1) ("11) (ustt) Wait) (usfp (it) (R) r/100') (ft) Survey Tool Name 813.86 12.56 116.31 808.85 716.05 32.60 62.31 5,980,750.25 549,631.26 2.11 44.88 GYD-GC-SS (1) 909.29 15.48 116.02 901.43 808.64 42.78 83.06 5,980,740.20 549,652.07 3.06 60.08 GYD-GCSS(1) 1,003.79 16.85 113.72 992.19 899.40 53.83 106.94 5,980,729.32 549,676.02 1.60 77.83 GYD-GCSS(1) 1,098.56 18.48 111.78 1,082.49 989.70 54.93 133.46 5,980,718.39 549,702.61 1.83 98.01 GYD-GC-SS(1) 1,194.67 20.89 113.70 1,172.98 1,080.19 -77.47 163.30 5,980,706.05 549,732.53 2.60 120.68 MWDAFR-AK-CA2-13C(2) 1,234.61 22.13 113.61 1,210.14 1,117.35 -83.34 176.71 5,980,700.27 549,745.98 3.11 130.79 MWD+IFR-AK-CAZ-SC (2) 1,329.20 25.32 113.89 1,2%.72 1,203.93 -98.67 211.54 5,980,685.17 549,780.91 3.37 156.98 MWD+IFR-AK-CAZSC (2) 1,421.11 29.49 113.16 1,378.30 1,285.51 -115.54 250.33 5,980,668.56 549,819.80 4.55 186.24 MWDAFR-AK-CAZSC(2) 1,517.95 33.20 112.62 1,460.99 1,368.20 -135.12 296.73 5,980,649.29 549,8611.33 3.84 221.48 MWD+IFR-AK-CAZ-SC(2) 1,613.27 33.72 113.53 1,540.51 1,447.72 -155.72 345.08 5,980,629.01 549914.81 0.76 258.11 MWD+IFR-AK-CAZSC(2) 1,708.42 33.08 113.61 1619.95 1,527.16 -176.66 393.09 5,980,608.39 549,962.95 0.67 294.30 MWD+IFR-AK-CAZSC(2) 1,804.10 33.67 115.86 1,699.85 1,607.06 -198.69 440.88 5,980,586.68 550,010.89 1.43 329.67 MWD+IFR-AK-CAZ-SC(2) 1,901.24 37.21 118.00 1,778.99 1,686.20 -224.23 491.07 5,980,56147 550,061.23 3.86 356.28 MWD -INC ONLY(3) 1,977.75 39.23 117.71 1,839.09 1,746.30 -246.35 532.92 5,980,539.64 550,103.22 2.65 396.34 MWD+IFR2+HDS+MS(4) 2,007.00 40.35 117.25 1,861.57 1,768.78 -254.98 549.52 5,980,531.11 550,119.89 3.96 408.32 MWD+IFR2+HDS+MS (4) 2,037.00 41.52 116.92 1,884.23 1,791.44 -263.93 567.02 5,980,522.28 550,137.44 3.97 421.00 MWD+IFR2+HDS+MS(4) 2,067.0 42.58 116.71 1,906.51 1,813.72 -273.00 584.96 5,980,513.34 550,155.43 3.56 434.04 MWD+IFR2+HDS+MS(4) 2,097.00 43.63 116.51 1,928.41 1,835.62 -282.18 603.29 5,980,504.28 550,173.82 3.53 447.40 MWD+IFR2+HDS+MS (4) 2,127.00 44.75 116.43 1,949.92 1,857.13 -291.50 622.00 5,980,495.08 550,192.0 3.74 461.06 MWD+IFR2+HDS+MS(4) 2,157.00 45.87 116.47 1,971.02 1,878.23 -301.00 641.10 5,980,485.71 550,211.75 3.73 475.00 MWD+1FR2+HDS+MS(4) 2,187.00 47.08 116.52 1,991.68 1,898.89 310.70 660.57 5,980,476.14 550,231.28 4.04 489.21 MWD+IFR2+HDS+MS(4) 2,217.00 48.40 116.44 2,011.85 1,919.06 320.60 680.44 5,980,466.37 550,251.22 4.40 503.71 MWD+IFR2+HDS+MS(4) 2,247.0 49.68 116.16 2,031.52 1,938.73 330.64 700.75 5,980,456.47 550,271.59 4.32 518.57 MWD+IFR2+HDS+MS(4) 2,277.00 50.84 115.84 2,050.70 1,957.91 340.75 721.48 5,980,446.50 550,292.39 3.95 533.78 MWD+IFR2+HDS+MS(4) 2,307.00 51.95 115.63 2,069.42 1,976.63 350.93 742.60 5,980,436.46 550,313.58 3.74 549.33 MWD+IFR2+HDS+MS(4) 2,337.00 53.10 115.68 2,087.67 1,994.88 361.24 764.06 5,980,426.29 550,335.10 3.84 565.14 MWD+IFR2+HDS+MS(4) 2,367.00 54.38 115.81 2,105.41 2,012.62 37174 785.85 5,980,415.93 550,356.96 4.26 581.17 MWD+1FR2+HDS+MS(4) 2,397.00 55.64 115.93 2,122.61 2,029.82 382.47 807.96 5,980,405.35 550,379.14 4.21 597.43 MWD+IFR2+HDS+MS(4) 2,427.00 56.61 116.02 2,139.34 2,046.55 -393.38 830.36 5,980,394.59 MOX1.60 3.24 613.86 MWD+IFR2+HDS+MS(4) 2,457.00 57.38 116.10 2,155.68 2,062.89 404.43 852.96 5,980,383.69 550,424.27 2.58 630.44 MWD+IFR2+HDS+MS(4) 2,487.00 58.37 116.14 2,171.63 2,078.84 415.61 875.77 5,980,372.66 550,447.15 3.30 647.16 MWD+IFR2+HDS+MS (4) 2,517.00 59.50 115.95 2,187.11 2,094.32 426.90 898.86 5,980,361.53 550,470.31 3.81 664.09 MWD+IFR2+HDS+MS(4) 2,547.00 60.42 115.63 2,202.13 2,109.34 438.20 922.24 5,980,350.39 550,493.77 3.20 681.29 MWD+IFR2+HDS+MS(4) 2,577.00 61.29 115.29 2,216.74 2,123.95 449.46 945.90 5,980,339.28 550,517.50 3.06 698.76 MWD+1FR2+HDS+MS(4) 2,607.00 62.12 114.85 2,230.96 2,138.17 460.65 969.82 5,980,328.25 550,541.50 3.05 716.50 MWD+IFR2+HDS+MS(4) 2,637.00 63.06 114.32 2,244.77 2,151.98 471.73 994.04 5,980,317.33 550,565.78 3.50 734.56 MWD+IFR2+HDS+MS(4) 2,667.00 64.06 113.78 2,258.13 2,165.34 482.68 1,018.57 5,980,306.55 550,590.38 3.70 752.96 MWD+IFR2+HDS+MS(4) 2,697.00 65.08 113.33 2,271.01 2,178.22 493.50 1,043.41 5,980,295.89 550,615.29 3.68 771.68 MWD+IFR2+HDS+MS(4) 2,727.0 66.25 112.97 2,283.37 2,190.58 504.25 1,068.54 5,980,285.31 550,640.49 4.05 790.71 MND+IFR2+HDS+MS(4) 2,757.00 67.57 112.62 2,295.14 2,202.35 514.94 1,093.98 5,900,274.79 550,668.00 4.53 810.04 MND+IFR2+HDS+MS(4) 9/10/2018 3:00:31PM Page 3 COMPASS 5000.14 Build 85 I ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1 H-104 project Kupamk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Sib: Kupamk 1H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbors: 1 H-104 Survey Calculation Method: Minimum Curvature Design: 1 H-104 Database: OAKEDMP2 Survey Map Map VerBaal MD Inc AN TVD TVDSS +NIS +ElAV Northing Eassng DLS Section (usft) C) PI (usft) (Wfy (usft) (Wft) (1) (It) ('/1001 (1t) survey Tool Name 2,787.00 68.78 112.39 2,306.29 2,213.50 525.60 1,119.71 5,980,264.30 550,691.79 4.10 829.65 1AWD+IFR2+HD5+MS(4) 2,817.00 69.85 112.35 2,316.89 2,224.10 536.28 1,145.66 5,980,253.79 550,717.81 3.57 849.46 MWD+IFR2+HDS+MS(4) 2,647.00 70.90 112.35 2,326.96 2,234.17 547.03 1,171.80 5,980,243.22 550,744.02 3.50 869.42 MWD+IFR2+HDS+MS (4) 2,877.00 71.12 112.39 2,336.72 2,243.93 557.82 1,198.03 5,980,232.60 550,770.32 0.74 889.44 MWD+IFR2+HDS+MS (4) 2,907.00 70.87 112.55 2,346.49 2,253.70 568.67 1,224.24 5,980,221.93 550.796.60 0.99 909.42 MWD+IFR2+HD5+MS(4) 2,937.00 70.73 112.76 2,356.36 2,263.57 -579.58 1,250.38 5,980,211.19 550,822.81 0.78 929.32 MWD+IFR2+HDS+MS(4) 2,967.00 71.42 112.94 2,366.09 2,273.30 590.60 1,276.54 5,980,200.35 550,849.03 2.37 949.18 MWD+IFR2+HDS+MS(4) 2,997.00 72.16 113.02 2,375.46 2,282.67 -601.73 1,302.77 5,980,189.40 550,875.34 2.48 969.08 MWD+IFR2+MDS+MS (4) 3,027.00 72.76 113.06 2,384.50 2,291.71 -612.92 1,329.09 5,980,178.38 550,901.73 2.00 989.03 MWD+IFR2+HDS+MS(4) 3,057.00 73.19 113.13 2,393.29 2,300.50 524.17 1,355.48 5,980,167.30 550,928.19 1.45 1,009.02 MWD+IFR2+HDS+MS(4) 3,087.00 73.23 113.35 2,401.95 2,308.16 635.51 1,381.87 5,960,156.14 550,954.65 0.75 1,028.99 MWD+IFR2+HDS+MS(4) 3,117.00 73.26 113.71 2,410.60 2,317.81 646.98 1,408.21 5,980,144.85 550,981.06 1.12 1,048.64 MWD+IFR2+HD5+MS (4) 3,147.00 73.72 114.04 2,419.13 2,326.34 658.62 1,434.51 5,960,133.38 551,007.44 1.86 1,068.60 MWD+IFR2+HDS+MS (4) 3,177.00 74.22 114.10 2427.41 2,334.62 -670.38 1,460.83 5,980,121.79 551,033.84 1.68 1,088.34 MWD+IFR2+HDS+MS(4) 3,207.00 74.27 113.93 2,435.56 2,342.77 682.13 1,48221 5,980,110.22 551,060.29 0.57 1,108.13 MWD+IFR2+HDS+MS(4) 3,237.00 74.45 113.75 2,443.65 2,350.86 -693.81 1,513.63 5,980,098.72 551,(186.78 0.83 1,127.99 MWD+IFR2+HDS+MS(4) 3,267.00 74.41 113.51 2,451.70 2,358.91 -705.39 1,540.11 5,98,087.31 551,113.33 0.78 1,147.93 MWD+IFR2+HDS+MS (4) 3,297.00 74.24 113.22 2459.80 2,367.01 -716.85 1,566.62 5,980,076.03 551,139.92 1.09 1,167.96 MWD+IFR2+HDS+MS(4) 3,327.00 74.32 112.91 2,467.93 2,375.14 -728.16 1,593.19 5,980,064.90 551,166.56 1.03 1,188.09 MWD+IFR2+HD5+MS(4) 3,357.00 74.22 112.61 2,476.06 2,383.27 -739.33 1,619.82 5,98,053.90 551,193.26 1.02 1,208.34 MWD+IFR2+HDS+MS(4) 3,387.00 74.13 112.34 2,484.25 2391.6 -750.37 1,646.49 5,960,043.05 551,220.00 0.92 1328.67 MWD+IFR2+HDS+MS (4) 3,417.00 74.29 112.06 2,492.41 2,399.62 -761.27 1,673.22 5,980,032.32 551,246.80 1.04 1,249.11 MWD+IFR2+HDS+MS(4) 3,447.00 74.40 111.80 2,500.50 2,407.71 -772.06 1,700.02 5,980,021.71 551,273.6 0.91 1,269.66 MWD+IFR2+HDS+MS(4) 3,477.00 74.33 111.55 2,508.59 2,415.80 -782.73 1,726.85 5,98,011.22 551,300.58 0.80 1,290.30 MWD+IFR2+HDS+MS(4) 3,507.00 74.20 111.34 2,516.73 2,423.94 -793.29 1,753.74 5,980,000.83 551,327.52 0.83 1,311.00 MWD+IFR2+HDS+MS(4) 3,537.00 73.93 111.12 2,524.96 2,432.17 603.74 1,780.63 5,979,990.57 551,354.48 1.14 1,331.77 MWD+IFR2+HDS+MS(4) 3,567.00 73.69 110.92 2,533.33 2,440.54 614.07 1,807.52 5,979,980.41 551,381.43 1.02 1352.58 MWD+IFR2+HDS+MS(4) 3,597.00 73.76 110.74 2,541.73 2,448.94 -824.31 1,834.44 5,979,970.35 551,408.41 0.62 1,373.45 MWD+IFR2+HDS+MS(4) 3.627.00 73.77 110.57 2,550.12 2,49.33 -834.48 1,861.39 5,979,960.37 551,435.43 0.55 1,394.36 MWD+IFR2+HDS+MS(4) 3,657.00 73.86 110.48 2,558.48 2,465.69 644.58 1,888.37 5,979,950.45 551,462.48 0.42 1,415.35 MWD+IFR2+HDS+MS(4) 3,687.00 73.77 110.44 2,566.85 2474.06 4154.65 1,915.37 5,979,940.56 551,489.53 0.33 1,436.37 MWD+IFR2+HDS+MS(4) 3,717.00 73.67 110.0 2,575.26 2,482.47 664.70 1,942.35 5,979,930.69 551,516.58 0.36 1,457.38 MWD+IFR2+HDS+MS(4) 3,747.00 73.89 110.46 2,583.64 2,490.85 674.75 1,969.35 5,979,920.82 551,543.64 0.76 1,478.39 MWD+IFR2+HDS+MS(4) 3,777.00 73.58 110.60 2,592.04 2,499.25 -884.85 1,996.32 5,979,910.90 551,570.67 1.13 1,499.35 MWD+IFR2+HDS+MS(4) 3,807.00 73.22 110.74 2,600.61 2,507.82 695.00 2,023.22 5,979,900.93 551,597.64 1.28 1,520.25 MWD+IFR2+HDS+MS(4) 3,837.00 73.72 110.88 2,609.14 2,516.35 -905.22 2,050.10 5,979,890.89 551,624.59 1.73 1,541.10 MWD+IFR2+HDS+MS(4) 3,867.00 73.59 111.00 2,617.59 2,524.80 -915.50 2,076.99 5,979,880.78 551651.54 0.58 1,561.92 MWD+IFR2+HDS+MS(4) 3,897.00 73.33 111.13 2,626.13 2533.34 -925.84 2,103.62 5,979,870.62 551,678.44 0.96 1,582.68 MWD+IFR2+HDS+MS (4) 3,927.0 73.55 111.24 2,634.68 2,541.89 -836.23 2,130.63 5,979,860.41 551705.32 0.81 1,603.40 MWD+IFR2+HDS+MS(4) 3,957.0 73.44 111.35 2,643.20 2,550.41 -946.68 2,157.43 5,979,850.14 551,732.18 0.51 1,624.08 MWD+IFR2+HDS+MS(4) 9/10/2018 3.00:31PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1H-104 Pm)ect Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) SRO: Kuparuk 1 H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Won: Rig: 1H-104 North Reference: True Wellbore: 11-1-104 Survey Calculation Method: Minimum Curvature Design: 1H-104 Database: OAKEDMP2 Survey Map Map vertical MD Inc AN TVD TVDSS +N1S +E/ -W Northing Easting DLS Section Nam r) P) (usft) (usft) (uslt) Waft) (ft) (fes (.1100') (ft) Survey Tool Name 3,987.00 73.38 111.45 2,651.77 2,558.98 -957.17 2,184.20 5,979,839.83 551,759.02 0.38 1,644.71 MWD+IFR2+HDS+MS (4) 4,017.00 73.38 111.51 2,660.35 2,567.56 -967.70 2,210.95 5,979,829.48 551,785.83 0.19 1,665.32 MWD+IFR2+HDS+MS(4) 4,047.00 73.44 111.43 2,668.91 2,576.12 -978.22 2,237.71 5,979,819.14 551,812.66 0.32 1,685.93 MWD+IFR2+HDS+MS(4) 4,077.00 73.29 111.32 2,677.50 2,584.71 -988.70 2,264.48 5,979,808.84 551,839.49 0.61 1,706.57 MWD+1FR2+HDS+1VS(4) 4,107.00 73.46 111.22 2,686.08 2,593.29 .99.12 2,291.26 5,979,798.59 551,866.34 0.65 1,727.25 MWD+IFR2+HDS+MS(4) 4,137.00 73.64 111.16 2,694.58 2,601.79 -1,009.52 2,318.09 5,979,788.37 551,893.24 0.63 1,747.97 MWD+IFR2+HDS+MS(4) 4,167.00 73.40 111.13 2,703.09 2,610.30 -1,019.90 2,344.92 5,979,778.17 551920.13 0.81 1,768.71 MWD+IFR2+HDS+MS(4) 4,197.0 73.50 111.07 2,711.64 2,618.85 -1,030.25 2,371.75 5,979,767.99 551,94203 0.38 1,789.46 MWD+IFR2+HDS+MS(4) 4,227.00 73.61 110.94 2,720.13 2,627.34 -1,040.57 2,398.61 5,979,757.86 551,973.95 0.55 1,810.25 MWD+IFR2+HDS+MS(4) 4,257.00 73.43 110.75 2,728.64 2,635.85 -1,050.80 2,425.50 5,979,747.80 552,000.90 0.85 1,831.09 MWD+1FR2+HDS+1VS(4) 4,287.00 73.30 110.56 2,737.23 2,644.44 -1,060.94 2,452.39 5,979,737.84 552,027.86 0.75 1,851.98 MWD+IFR2+HDS+MS(4) 4,317.00 73.34 110.39 2,745.84 2,653.05 -1,071.00 2,479.32 5,979,727.97 552,054.85 0.56 1,872.92 MWD+IFR2+HDS+MS (4) 4,347.00 73.38 110.23 2,754.43 2,661.64 -1,080.97 2,506.27 5,979,718.17 552,081.87 0.53 1,893.93 MWD+IFR2+HDS+MS(4) 4,377.00 73.48 110.07 2,762.98 2,670.19 -1,090.88 2,533.27 5,979,708.45 552,108.92 0.61 1,915.00 MWD+IFR2+HDS+MS(4) 4,407.00 73.40 110.10 2,771.53 2,678.74 -1,100.75 2,560.27 5,979,698.75 552,135.99 0.28 1,936.09 MWD+IFR2+HDSWS(4) 4,437.00 73.36 110.34 2,780.12 2,687.33 -1,110.69 2,587.25 5,979,688.99 552,163.03 0.78 1,957.14 MWD+IFR2+HDS+MS(4) 4,467.00 73.15 110.60 2,788.76 2,695.97 -1,120.73 2,614.16 5,979,679.13 552,190.01 1.09 1,976.08 MWD+IFR2+HDS+MS(4) 4,497.00 73.16 110.83 2,797.45 2,704.66 -1,130.89 2,641.02 5,979,669.15 552,216.93 0.73 1,998.92 MWD+IFR2+HDS+MS(4) 4,527.00 73.31 111.00 2,806.11 2,713.32 -1,141.14 2,667.85 5,979,659.07 552,243.82 0.74 2,019.71 MWD+IFR2+HDS+MS(4) 4,557.00 73.32 111.16 2,814.72 2,721.93 -1,151.48 2,694.66 5,979,648.92 552,270.70 0.51 2,040.45 MWD+1FR2+HDS+MS(4) 4,587.00 73.28 111.36 2,823.34 2,730.55 -1,161.90 2,721.44 5,979,638.68 552,297.55 0.65 2,061.12 MWD+1FR2+HD6+1VS(4) 4,617.00 73.39 111.62 2,031.94 2,739.15 -1,172.43 2,748.19 5,979,628.33 552,324.36 0.91 2,081.72 MWD+IFR2+HDS+MS (4) 4,647.00 73.46 111.91 2,840.50 2,747.71 -1,183.09 2,774.89 5,979,617.(14 552,351.13 0.96 2,102.23 MWD+IFR2+HDS+MS(4) 4,677.00 73.31 112.19 2,849.08 2,756.29 -1,19388 2,801.53 5,979,607.23 552,377.84 1.02 2122.63 MWD+IFR2+HDS+MS(4) 4,707.00 73.35 112.45 2,857.69 2,764.90 -1,204.80 2,828.12 5,979,596.49 552,400.50 0.80 2,142.94 MWD+IFR2+HDS+MS(4) 4,737.00 73.29 112.71 2,866.30 2,773.51 -1,215.83 2,854.65 5,979,585.63 552,431.10 0.85 2,163.15 MWD+IFR2+HDS+MS(4) 4,767.00 73.33 112.% 2,874.91 2,782.12 -1,226.98 2,881.14 5,979,574.66 552,457.65 0.81 2,183.26 MWD+IFR2+HDS+MS(4) 4,797.00 73.32 113.14 2,883.52 2,790.73 -1,238.24 2,907.58 5,979,563.58 552,484.17 0.58 2,203.31 MWD+IFR2+HDS+MS(4) 4,827.00 73.33 113.28 2,892.13 2,799.34 -1,249.56 2,934.0 5,979,552.43 552,510.65 0.45 2,223.29 MWD+IFR2+HDS+MS(4) 4,857.0 73.26 113.40 2,900.75 2,807.96 -1,260.95 2,960.38 5,979,541.22 552,537.11 0.45 2,243.23 MWD+IFR2+HDS+MS(4) 4,887.00 73.23 113.39 2,909.40 2,816.61 -1,272.35 2,986.74 5,979,529.99 552,563.55 0.10 2,263.14 MWD+IFR2+HDS+MS(4) 4,917.00 73.23 113.26 2,918.06 2,825.27 -1,283.72 3,013.12 5,979,518.80 552,590.00 0.41 2,283.07 MWD+IFR2+HOS+MS(4) 4,947.00 73.08 113.12 2,926.75 2,833.96 -1,295.03 3,039.51 5,979,507.67 552,616.46 0.67 2,303.4 MWD+IFR2+HDS+MS(4) 4,977.00 73.13 113.01 2,935.47 2,842.68 -1,306.28 3,065.92 5,979,496.60 552,642.94 0.39 2,323.06 MWD+IFR2+HDS+MS(4) 5,007.00 73.36 112.94 2,944.12 2,851.33 -1,317.49 3,092.37 5,979,485.56 552,669.46 0.80 2,343.12 MWD+IFR2+HDS+MS(4) 5,037.00 73.47 112.87 2,952.68 2,859.89 -1,328.68 3,118.86 5,979,474.55 552,696.02 0.43 2,363.22 MWD+1FR2+HDS+MS(4) 5,067.00 73.63 112.70 2,961.17 2,868.38 -1,339.82 3,145.38 5,979,463.58 552,722.61 0.76 2,383.38 MWD+IFR2+HDS+MS(4) 5,097.00 73.67 112.35 2,969.62 2,876.83 -1,350.85 3,171.97 5,979,452.73 552,749.27 1.13 2,403.65 MWD+IFR2+HDS+MS(4) 5,127.0 73.61 111.98 2,97887 2,885.28 -1,361.71 3,198.63 5,979,442.05 552,776.00 1.20 2,424.04 MWD+IFR2+HDS+MS(4) 5,157.0 73.70 111.71 2,986.51 2,893.72 -1,372.42 3,225.35 5,979,431.51 552,802.79 0.91 2,444.54 MWD+IFR2+HDS+MS(4) 9/10!2018 3:00:31PM Page 5 COMPASS 5000.14 Build 85 I ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Project; Kuparuk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Sib: Kuparuk 1 H Pad MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Wall: Rig: 1H-104 North Reference: True Wa0bow IH -104 Survey Calculation Method: Minimum Curvature Design: IH -104 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azl TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (wit) (1) Pl (uatt) (ustt) (uslt) (usft) (m (it) (°/1001 (R) Survey Tool Name 5,187.00 73.65 111.73 2,994.95 2,902.16 -1,383.08 3,252.10 5,979,421.04 552,829.60 0.18 2,465.10 MWD+IFR2+HDS+MS(4) 5,217.00 73.57 111.84 3,003.41 2,910.62 -1,393.76 3,278.82 5,979,410.53 552,856.40 0.44 2,485.62 MWD+IFR2+HDS+MS(4) 5,247.00 73.62 111.97 3,011.88 2,919.09 -1,404.49 3,305.52 5,979,399.98 552,883.16 0.45 2,506.10 MWD+IFR2+HDS+MS(4) 5,277.00 73.66 112.22 3,020.33 2,927.59 -1,415.32 3,332.20 5,979,389.33 552,909.90 0.81 2,526.51 MWD+IFR2+HDS+MS(4) 5,307.00 73.70 112.52 3,028.76 2,935.97 -1,426.28 3,358.82 5,979,378.55 552,936.60 0.97 2,546.64 MWD+IFR2+HDS+MS(4) 5,337.00 73.62 112.60 3,037.20 2,944.41 -1,437.37 3,385.39 5,979,367.63 552,963.23 0.93 2,567.05 MWD+IFR2+HDS+MS(4) 5,367.00 73.58 112.90 3,045.67 2,952.88 -1,448.55 3,411.91 5,979,356.63 552,989.83 0.35 2,587.20 MWD+IFR2+HDS+MS(4) 5,397.00 73.67 112.87 3,054.13 2,961.34 -1,459.74 3,438.42 5,979,345.62 553,016.41 0.31 2,607.33 MWD+IFR2+HDS+MS(4) 5,427.00 73.71 112.86 3,062.56 2,969.77 -1,470.93 3,464.95 5,979,334.61 553,043.02 0.14 2,627.48 MWD+IFR2+HDS+MS(4) 5,457.00 73.77 112.99 3,070.96 2,978.17 -1,482.15 3,491.48 5,979,323.56 553,069.61 0.46 2647.61 MWD+IFR2+HDS+MS(4) 5,487.00 73.86 113.23 3,079.32 2,966.53 -1,493.45 3,517.98 5,979,312.43 553,096.18 0.82 2,667.68 MWD+IFR2+HDS+MS(4) 5,517.00 73.71 113.48 3,087.70 2,994.91 -1,504.87 3,544.43 5,979,301.19 553,122.70 0.94 2,687.65 MWD+IFR2+HDS+MS(4) 5,547.00 73.70 113.64 3,096.11 3,003.32 -1,516.38 3,570.82 5,979,289.86 553,149.17 0.51 2,707.56 MWD+IFR2+HDS+MS(4) 5,577.00 73.63 113.67 3,104.55 3,011.76 -1,527.93 3.597.19 5,979,278.48 553,175.61 0.25 2,727.41 MWD+IFR2+HDS+MS(4) 5,607.00 73.62 113.69 3,113.01 3,020.22 -1,539.49 3.623.55 5,979,267.10 553,202.05 0.07 2,747.26 MWD+IFR2+HDS+MS (4) 5,637.00 73.73 113.82 3,12144 3,028.65 -1,551.09 3,649.90 5.979,255.67 553,228.47 0.55 2,767.08 MWD+IFR2+HDS+MS(4) 5,667.00 73.82 114.13 3,129.82 3,037.03 -1,562.80 3,676.22 5,979,244.15 553,254.86 1.04 2,766.84 MWD+IFR2+HDS+MS(4) 5,697.00 73.79 114.48 3,138.19 3,045.40 -1,574.65 3,702.48 5,979,232.46 553,281.20 1.12 2,806.47 MWD+IFR2+HDS+MS(4) 5,727.00 73.78 114.83 3,146.57 3,053.78 -1,586.67 3,728.66 5,979,220.62 553,307.45 1.12 2,825.98 MWD+IFR2+HDS+MS(4) 5,757.00 73.82 115.15 3,154.94 3,062.15 -1,598.84 3,754.77 5,979,208.62 553,333.64 1.03 2,845.35 MWD+IFR2+HDS+MS (4) 5,787.00 73.84 115.46 3,163.29 3,070.50 -1,611.16 3,780.82 5,979,196.48 553,359.77 0.99 2,864.62 MWD+IFR2+HDS+MS (4) 5,817.00 73.89 115.74 3,171.63 3,078.84 -1,623.61 3,806.81 5,979,184.20 553,385.84 0.91 2,883.78 MWD+IFR2+HDS+M$(4) 5,847.00 73.90 115.90 3,179.95 3,087.16 -1,635.16 3,832.75 5,979,171.82 553,411,W 0.51 2,902.86 MWD+IFR2+HDS+MS(4) 5,877.0 73.69 115.99 3,188.32 3,095.53 -1,648.77 3,858.66 5,979,159.39 553,437.85 0.76 2,921.88 MWD+IFR2+HDS+MS(4) 5,907.00 73.80 116.07 3,196.72 3,103.93 -1,661.41 3,884.54 5,979,146.93 553,463.81 0.45 2,940.87 MWD+IFR2+HDS+MS(4) 5,937.00 73.88 116.06 3,205.07 3,112.28 -1,674.07 3,910.42 5,979,134.44 553,489.77 0.27 2,959.85 MWD+IFR2+HDS+M$(4) 5,967.00 73.96 115.97 3,213.38 3,120.59 -1,665.71 3,936.33 5,979,121.97 553,515.76 0.39 2,978.86 MWD+IFR2+HDS+MS(4) 5,997.0 73.82 115.88 3,221.70 3,128.91 -1,699.31 3,962.25 5,979,109.54 553,541.76 0.55 2,997.90 MWD+IFR2+HDS+MS(4) 6,027.00 73.67 115.68 3,230.10 3,137.31 -1,711.84 3,988.18 5,979,097.19 553,567.77 0.81 3,016.98 MWD+IFR2+HDS+MS(4) 6,057.00 73.44 115.36 3,238.60 3,145.81 -1,724.23 4,014.15 5,979,084.96 553,593.82 1.28 3,036.14 MWD+IFR2+HDS+MS(4) 6,087.00 73.19 115.04 3,247.21 3,154.42 -1,736.47 4,040.15 5,979,072.90 553,619.90 1.32 3,055.39 MWD+IFR2+HDS+M$(4) 6,117.00 73.23 114.70 3,255.87 3,163.08 -1,748.55 4,066.21 5,979,061.0 553,646.03 1.09 3,074.76 MWD+IFR2+HDS+MS(4) 6,147.00 73.45 114.35 3,264.48 3,171.69 -1,760.48 4,092.35 5,979,049.24 553,672.26 1.34 3,094.27 MWD+IFR2+HDS+MS(4) 6,177.00 73.40 113.99 3,273.03 3,180.24 -1,772.25 4,118.59 5,979,037.64 553,698.56 1.16 3,113.91 MWD+IFR2+HDS+MS(4) 6,207.00 73.38 113.64 3,281.61 3,188.82 -1783.86 4,144.89 5,979,026.21 553,724.94 1.12 3,133.68 MWD+IFR2+HDS+MS(4) 6,237.00 73.48 113.30 3,290.16 3,197.37 -1,795.31 4,171.26 5,979,014.94 553,751.38 1.14 3,153.59 MWD+IFR2+HDS+MS(4) 6,267.00 73.36 112.96 3,298.73 3,205.94 -1,806.60 4,197.70 5,979,003.82 553,777.90 1.16 3,173.61 MWD+IFR2+HDS+MS(4) 6,297.0 73.24 112.60 3,307.35 3,214.56 -1,817.73 4,224.20 5,978,992.87 553,804.46 1.22 3,193.75 MWD+IFR2+HDS+MS(4) 6,327.00 73.34 112.17 3,315.97 3,223.18 -1,828.67 4,250.76 5,978,982.10 553,831.10 1.41 3,214.02 MWD+IFR2+HDS+MS(4) 6,357.00 73.44 111.72 3,324.55 3,231.76 -1,839.42 4,277.43 5,978,971.54 553,857.83 146 3,234.47 MWD+IFR2+HDS+MS(4) 9/10!2018 3:00:31PM Page 6 COMPASS 5000.14 Build 85 Conocoftillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Project Kuparuk River Unit TVD Reference: 1H-104 actual @j 92.79usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbona: 1H-104 Survey Calculation Method: Minimum Curvature Design: 1 H-104 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS •N148 *El -W Northing Emitting OLS Section (-it) (1) (1) (usfp (usft) (weft) (usft) (10 (ft) (°1100) (ft) Survey Tool Name 6,38TD0 73.36 111.33 3,333.12 3,240.33 -1849.97 4,304.17 5,978,961.17 553,884.64 1.27 3,255.06 MWD+IFR2+HDS+MS(4) 6,417.0 73.27 111.27 3,341.73 3,248.94 -1,860.40 4,330.95 5,978,950.91 553,911.48 0.36 3,275.72 MWD+IFR2+HDS+MS(4) 6,447.00 73.44 111.41 3,350.32 3,257.53 -1,870.86 4,357.72 5,978,940.63 553,938.32 0.72 3,296.37 MWD+IFR2+HDS+MS(4) 6,477.00 73.38 111.55 3,358.89 3,266.10 -1,881.39 4,384.47 5,978,930.28 553,965.14 0.49 3,316.98 MWD+IFR2+HDS+MS (4) 6,507.00 73.42 111.56 3,367.46 3,274.67 -1,891.95 4,411.21 5,978,919.89 553,991.95 0.14 3,337.56 MWD+IFR2+HDS+MS(4) 6,537.00 73.47 111.48 3,376.01 3,283.22 -1,902.50 4,437.97 5,978,909.52 554,016.77 0.31 3,358.16 MWD+IFR2+HDS+MS (4) 6,567.00 73.40 111.0 3,384.56 3,291.77 -1,913.01 4,464.73 5,978,899.19 554,045.60 0.35 3,378.78 MWD+IFR2+HDS+MS (4) 6,597.00 73.61 111.25 3,393.08 3,300.29 -1,923.47 4,491.53 5,978,888.91 554,072.46 0.85 3,399.45 MWD+IFR2+HDS+M$(4) 6,627.00 73.57 111.4 3,401.56 3,308.77 -1,933.85 4,518.37 5,978,878.70 554,099.37 0.68 3,420.20 MWD+IFR2+HDS+MS(4) 6,657.00 73.54 110.82 3,410.05 3,317.26 -1,944.13 4,545.24 5,978,868.61 554,126.30 011 3,441.01 MWD+IFR2+HDS+MS(4) 6,687.00 73.62 110.66 3,418.53 3,325.74 -1,954.32 4,572.15 5,978,858.59 554,153.28 0.58 3,461.90 MWD+IFR2+HDS+MS(4) 6,717.00 73.61 110.58 3,426.99 3,334.20 -1,964.46 4,599.9 5,978,848.64 554,180.28 0.26 3,482.83 MWD+IFR2+HDS+MS (4) 6,747.00 73.57 110.52 3,435.47 3,342.68 -1,974.56 4,626.04 5,978,838.72 554,207.29 0.23 3,503.78 MW0+IFR2+HDS+MS(4) 6,777.00 73.57 110.35 3,443.95 3,351.16 -1,984.61 4,653.00 5,978,828.85 554,234.32 0.54 3,524.77 MWD+IFR2+HDS+MS (4) 6,807.00 73.63 109.97 3,452.42 3,359.63 -1,994.53 4,680.02 5,978,819.11 554,261.40 1.23 3,545.85 MWD+IFR2+HDS+MS (4) 6,837.00 73.54 109.54 3,460.90 3,368.11 -2,004.25 4,707.10 5,978,609.56 554,288.54 1.41 3,567.07 MWD+IFR2+HDS+MS(4) 6,867.00 73.49 109.18 3,469.41 3,376.62 -2,013.79 4,734.24 5,978,800.21 554,315.74 1.16 3,588.42 MWD+IFR2+HDS+MS(4) 6,897.00 73.38 109.08 3,477.97 3,385.18 -2,023.21 4,761.41 5,978,790.97 554,342.97 0.49 3,609.84 MWD+IFR2+HDS+MS(4) 6,927.00 73.48 109.07 3,486.52 3,393.73 -2,032.61 4,788.58 5,978,781.75 554,370.20 0.33 3,631.27 MWD+IFR2+HDS+MS(4) 6,957.00 73.67 109.09 3,495.00 3,402.21 -2,042.02 4,815.78 5,978,772.52 554,397.46 0.64 3,652.72 MWD+IFR2+HDS+MS(4) 6,987.0 73.69 109.24 3,503.43 3,410.64 -2,051.47 4,842.97 5,978,763.25 554,424.71 0.48 3,674.15 MWD+IFR2+HDS+MS(4) 7,017.0 73.62 109.47 3,511.88 3,419.09 -2,061.01 4,870.13 5,978,753.89 564,451.93 0.77 3,695.51 MVM+IFR2+HDS+MS (4) 7,047.00 73.63 109.69 3,520.33 3,427.54 -2,070.65 4,897.25 5,978,744.43 554,479.11 0.70 3,716.80 MWD+IFR2+HDS+MS (4) 7,077.0 73.67 109.89 3528.78 3,435.99 -2,080.40 4,924.34 5,978,734.86 554,50.26 0.65 3,738.02 MWD+IFR2+HDS+MS (4) 7,107.00 73.57 110.0 3,537.24 3,444.45 -2,090.24 4,951.39 5,978,725.20 554,633.37 0.69 3,759.16 MWD+IFR2+HDS+MS(4) 7,137.0 73.62 110.25 3,54511 3,452.92 -2,10.16 4,978.40 5,978,715.46 554,560.45 0.57 3,780.25 MWD+IFR2+HDS+MS(4) 7,167.0 73.65 110.29 3,554.17 3,461.38 -2,110.13 5,05.41 5,978,705.67 554,587.51 0.16 3,801.30 MWD+1FR2+11DS+MS(4) 7,197.0 73.0 110.17 3,562.62 3,469.83 -2,120.08 5,032.41 5,978,695.90 554,614.58 0.42 3,822.36 MWD+IFR2+HDS+MS (4) 7,227.0 73.84 110.04 3,571.03 3,478.24 -2,129.98 5,059.45 5,978,666.18 554,641.69 0.90 3,843.48 MWD+IFR2+HDS+MS (4) 7,257.00 74.75 109.63 3,579.15 3,486.36 -2,139.78 5,086.62 5,978,676.56 554,668.91 3.31 3,864.75 1RW1)+IFR2+HDS+MS(4) 7,287.00 75.63 108.83 3,586.82 3,494.0 -2,149.33 5,114.01 5,978,667.19 554,696.36 3.91 3,886.32 MWD+IFR2+HDS+MS(4) 7,317.00 76.08 107.97 3,594.15 3,501.36 -2,158.52 5,141.61 5,978,658.19 554,724.02 3.16 3,908.23 MWD+IFR2+HDS+MS(4) 7,347.00 76.14 107.16 3,01.36 3,508.57 -2,167.30 5,169.37 5,978,649.59 554,751.84 2.63 3,930.44 MWD+IFR2+HDS+MS(4) 7,377.00 76.04 106.47 3,608.57 3,545.78 -2,175.73 5,197.25 5,978,641.35 554,779.77 2.26 3,952.89 MWD+IFR2+HDS+MS(4) 7,407.0 75.64 105.80 3,615.91 3,523.12 -2,163.81 5,225.19 5,978,633.45 554,807.76 2.54 3,975.54 MWD+IFR2+HDS+MS(4) 7,437.0 75.00 105.0 3,623.51 3,530.72 -2,191.53 5,253.17 5,978,625.93 554,835.78 3.27 3,998.37 MWD+IFR2+HDS+MS(4) 7,467.0 74.49 10.91 3,631.40 3,538.61 -2,198.76 5,281.19 5,978,618.88 554,863.85 3.98 4,021.42 MWD+IFR2+HDS+MS(4) 7,497.0 74.59 102.64 3,639.40 3,546.61 -2,205.40 5,309.33 5,978,612.43 554,892.03 4.09 4,044.81 MWD+IFR2+HDS+MS t4) 7,527.00 75.07 101.38 3.647+25 3,554.46 -2,211.42 5,337.65 5,978,60.59 554,920.39 4.36 4,08.0 MWD+IFR2+HDS+MS(4) 7,557.00 75.66 100.36 3,654.83 3,562.04 -2,216.0 5,366.16 5,978,601.31 554,948.93 3.83 4,092.78 MWD+IFR2+HDS+MS(4) 91102018 3:00:31PM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Project: Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: 1 H-104 Survey Calculation Method: Minimum Curvature Design: 1H-104 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azl TVD TVDSS +NIS +El -W Northing Easting DLS Section (uaft) (1 (1) Wall) (uslt) (usft) (usR) (m (ft) 011001 (fry Survey Tool Name 7,587.00 76.67 99.52 3,662.00 3,569.21 -2,221.92 5,394.85 5,978596.47 554,977.65 4.33 4,117.30 MND+IFR2+HDS+MS(4) 7,617.00 77.66 98.72 3,668.67 3,575.88 -2,226.66 5,423.73 5,978,592.03 555,006.56 4.20 4,142.14 MND+IFR2+HDS+MS(4) 7,647.00 77.74 97.57 3,675.06 3,582.27 -2,230.71 5,452.75 5,978,588.07 555,035.60 3.75 4,167.30 MWD+IFR2+HDS+MS(4) 7,677.00 76.97 96.18 3,681.63 3,5B8.84 -2,234.22 5,481.81 5,978,584.75 555,064.68 5.20 4,192.75 MWD+IFR2+HDS+MS(4) 7,707.00 76.42 95.01 3,688.53 3,595.74 -2,237.06 5,510.86 5,978,582.10 555,093.75 4.21 4,218.45 MWD+IFR2+HDS+MS (4) 7,737.00 76.21 93.80 3,695.63 3,602.84 -2,239.30 5,539.92 5,978,580..9 555,122.82 3.98 4,244.39 MWD+IFR2+HDS+MS(4) 7,767.00 76.15 92.39 3,702.80 3,610.01 -2,240.88 5,569.01 5,978,578.67 555,151.92 4.57 4,270.61 MWD+IFR2+HDS+MS(4) 7,797.00 76.26 90.92 3,709.95 3,617.16 -2,241.72 5,598.13 5,978,578.02 555,181.04 4.77 4,297.14 MWD+IFR2+HDS+MS(4) 7,827.00 76.47 89.20 3,717.02 3,624.23 -2,241.75 5,627.29 5,978,578.19 555,210.19 5.62 4,324.02 MWD+IFR2+HDS+MS(4) 7,857.00 76.61 87.30 3,724.01 3,631.22 -2,240.86 5,656.45 5,978,579.27 555,239.34 6.18 4,351.26 MWD+IFR2+HDS+MS(4) 7,887.00 76.83 85.81 3,730.90 3,638.11 -2,239.10 5,685.59 5,978,561.22 555,268.47 4.89 4,378.62 MWD+IFR2+HDS+MS(4) 7,917.00 77.40 84.41 3,737.59 3,644.80 -2,236.61 5,714.73 5,978,583.90 555,297.59 4.93 4,406.66 MWD+IFR2+HDS+MS (4) 7,947.00 78.05 82.74 3,743.97 3,651.18 -2,233.33 5,743.86 5,978,587.38 555,326.69 5.86 4,434.79 MWD+IFR2+HDS+MS (4) 7,977.00 78.51 81.08 3,750.06 3,657.27 -2,229.19 5,772.94 5,978,591.70 555,355.74 5.63 4,463.21 MWD+IFR2+HDS+MS(4) 8,007.0 78.91 79.43 3,755.93 3,663.14 -2,224.21 5,801.93 5,978,596.87 555,384.70 5.56 4,491.88 MWD+IFR2+HDS+MS(4) 8,037.0 79.38 78.49 3,761.58 3,668.79 -2,218.57 5,830.85 5,978,602.71 555,413.58 3.45 4,520.73 MWD+IFR2+HDS+MS(4) B4O67.0 79.62 77.91 3,767.05 3,674.26 -2,212.54 5,859.72 5,978,608.93 555,442.41 2.06 4,549.69 MWD+1FR2+H0S+MS(4) 8,097.00 79.44 77.39 3,772.50 3,679.71 -2,206.23 5,888.54 5,978,615.43 555,471.18 1.81 4,578.71 MWD+IFR2+HDS+MS(4) 8,127.00 79.47 77.20 3,777.99 305.20 -2,199.74 5,917.31 5,978,622.11 555,499.90 0.63 4,607.75 MWD+IFR2+HDS+MS(4) 8,157.00 79.34 77.19 3,783.51 3,690.72 -2,193.21 5,946.07 5,978,628.83 555,526.61 0.43 4,636.80 MWD+IFR2+HDS+MS(4) 8,187.00 79.61 77.17 3,788.99 3,696.20 -2,186.66 5,974.83 5,978,635.56 555,557.32 0.90 4,665.86 MWD+IFR2+HDS+MS(4) 8,217.00 79.72 76.98 3,794.37 3,701.58 -2,180.06 6,003.59 5,978,642.36 555,586.04 0.72 4,694.94 MWD+IFR2+HDS+MS(4) 8,247.00 78.95 76.67 3,799.92 3,707.13 -2,173.34 6,032.30 5,978,649.26 555,614.70 2.76 4,724.01 MWD+IFR2+111)S+MS(4) 8,27700 79.01 76.36 3,805.66 3,712.87 -2,166.48 6,060.93 5,978,656.32 555,643.29 1.03 4,753.07 MWD+IFR2+HDS+MS(4) 8,307.00 79.24 76.18 3,811.32 3,718.53 -2,159.48 6,089.55 5,978,663.50 555,671.86 0.97 4,782.17 MWD+IFR2+HDS+MS (4) 8,33200 79.40 76.14 3,816.88 3,724.09 -2,152.43 6,118.18 5,978,670.74 555,700.43 0.55 4,811.30 MWD+IFR2+HDS+MS(4) 8,367.00 79.37 76.11 3,822.40 3,729.61 -2,145.36 6,146.80 5,978,678.00 555,729.01 0.14 4,840.43 MWD+IFR2+HDS+MS(4) 8,397.00 79.46 76.05 3,827.91 3,735.12 -2,138.27 6,175.43 5,978,685.28 555,757.58 0.36 4,869.58 MND+1FR2+HDS+MS (4) 8,427.00 79.46 75.94 3,833.40 3,740.61 -2,131.13 6,204.04 5,978,692.61 555,786.15 0.36 4,898.73 MWD+IFR2+HDS+MS(4) 8,457.00 79.28 75.83 3,838.94 3,746.15 -2,123.94 6,232.64 5,978,699.99 555,814.69 0.70 4,927.88 MWD+IFR2+HDS+MS(4) 8,487.00 78.31 75.65 3,844.77 3,751.98 -2,116.69 6,261.16 5,976,707.43 555,643.16 3.29 4,956.99 MWD+IFR2+HDS+MS(4) 8,517.0 76.87 75.34 3,851.21 3,758.42 -2,109.35 6,289.52 5,978,714.95 555,871.47 4.90 4,985.98 MWD+IFR2+HDS+MS(4) 6,547.00 75.44 74.98 3,858.39 3,765.60 -2,101.89 6,317.68 5,978,722.60 555,899.58 4.91 5,014.84 MND+IFR2+HDS+MS(4) 8,577.00 74.18 74.66 3,856.25 3,773.46 -2,094.31 6,345.62 5,978,730.36 555,927.46 4.32 5,043.54 MWD+IFR2+HDS+MS(4) 8,607.00 73.18 74.42 3,874.68 3,781.89 -2,086.64 6,373.37 5,978,738.22 555,955.16 3.42 5,072.09 MND+IFR2+HDS+MS (4) 8,637.0 72.20 74.23 3,883.61 3,790.82 -2,078.90 6,400.95 5,978,746.14 565,982.68 3.32 5,100.52 MWD+IFR2+HDS+MS(4) 8,667.00 71.25 74.06 3,893.02 3,800.23 -2, D71.11 6,428.35 5,978,754.10 556,010.03 3.21 5,12B.80 MND+IFR2+HDS+MS(4) 8,697.00 70.15 74.03 3,902.93 3,810.14 -2,063.33 6,455.57 5,978,762.06 556,03720 3.67 5,156.92 MN4D+IFR2+HDS+MS(4) 8,727.00 68.99 74.07 3,913.40 3,820.61 -2,055.61 6,482.60 5,978,769.97 555,064.17 3.87 5,184.83 MWD+IFR2+HDS+MS(4) 8,757.00 68.40 74.12 3,924.30 3,831.51 -2,047.95 6,509.48 5,978,777.80 556,091.0 1.97 5,212.58 MWD+IFR2+HDS+MS(4) 91102018 3:00:31PM Page 8 COMPASS 5000.14 Build 85 Conocolohillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1 H-104 Project: Kupamk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: 1 H-104 Survey Calculation Method: Minimum Curvature Design: 1 H-104 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Asi TVD TVDSS +NIS +EI -W Northing Easting DLS Section Wit) P) P) (usft) (usft) (usft) (usft) (ft) (ft) (°11001 (ft) Survey Tool Name 8,787.00 68.42 74.29 3,935.34 3,842.55 -2,040.35 6,536.32 5,978,785.57 556,117.79 0.53 5,240.27 MWD+IFR2+HDS+MS(4) 8,817.00 68.36 74.56 3,946.39 3,853.60 -2,032.87 6,563.19 5,978,793.24 556,144.60 0.86 5,267.95 MWD+IFR2+HDS+MS(4) 8,847.00 69.02 74.84 3,957.29 3,854.50 -2,025.49 6,590.15 5,978,80079 556,171.51 2.37 5,295.66 MWD+IFR2+HDS+MS(4) 8,877.00 70.66 75.06 3,967.63 3,674.84 -2,018.18 6,617.34 5,978,808.28 556,198.65 5.51 5,323.57 MWD+IFR2+HDS+MS(4) 8,907.00 72.37 75.19 3,977.14 3,884.35 -2,010.87 6,644.84 5,978,815.76 556,226.10 5.71 5,351.76 MWD+IFR2+HDS+MS(4) 8,937.00 73.90 75.13 3,985.85 3,893.06 -2,003.52 6,672.59 5,978,823.30 556,253.80 5.10 5,380.19 MWD+IFR2+HDS+MS(4) 8,957.00 75.43 75.04 3,993.78 3,900.99 -1,996.08 6,700.55 5,978,830.93 556,281.70 5.11 5,408.85 MWD+IFR2+HDS+MS(4) 8,997.00 76.79 75.08 4,000.98 3,908.19 -1,988.57 6,728.69 5,978,838.62 556,309.78 4.54 5,437.71 MWD+IFR2+HDS+MS(4) 9,027.00 77.82 75.00 4,007.57 3,914.78 -1,981.01 6,756.96 5,978,846.37 556,338.01 3.44 5,466.71 MWD+IFR2+HDS+MS(4) 9,057.00 78.77 74.83 4,013.66 3,920.87 -1,973.37 6,785.32 5,978,854.20 556,366.31 3.21 5,495.82 MWD+IFR2+HDS+MS (4) 9,087.00 79.71 74.67 4,019.26 3,926.47 -1,965.62 6,813.76 5,978,862.14 556,394.69 3.18 5,525.04 MWD+IFR2+HDS+MS (4) 9,117.0 79.92 74.51 4,024.57 3,931.78 -1,957.77 6,842.22 5,978,870.17 556,423.10 0.87 5,554.33 MWD+IFR2+HDS+MS (4) 9,147.00 79.71 74.36 4,029.87 3,937.08 -1,949.85 6,070.67 5,978,878.28 556,451.49 0.86 5,583.62 MWD+IFR2+HDS+MS (4) 9,177.0 79.74 74.25 4,035.22 3,942.43 -1,941.86 6,899.09 5,978,886.45 556,479.86 0.37 5,612.92 MWD+IFR2+HDS+MS(4) 9,207.00 79.69 74.14 4,040.58 3,947.79 -1,933.82 6,927.49 5,978,894.68 556,508.20 0.40 5,642.22 MWD+IFR2+HDS+MS(4) 9,237.00 79.76 74.04 4,045.93 3,953.14 -1,925.73 6,955.88 5,978,902.96 556,536.53 0.40 5,671.53 MWD+IFR2+HDS+MS(4) 9,267.00 79.65 74.00 4,051.29 3,95&50 -1,917.60 6,984.25 5,978,911.27 556,554.85 0.39 5,700.85 MWD+IFR2+HDS+MS(4) 9,297.00 79.64 73.98 4,056.68 3,963.89 -1,909.46 7,012.62 5,978,919.60 556,593.16 0.07 5,730.15 MWD+IFR2+HDS+MS(4) 9,327.00 79.70 73.95 4,062.06 3,969.27 -1,901.31 7,040.99 5,978,927.94 556,621.47 0.22 5,759.47 MWD+IFR2+HDS+MS (4) 9,357.00 79.69 73.79 4,067.43 3,974.64 -1,893.11 7,069.34 5,978,936.32 556,649.77 0.53 5,788.79 MWD+IFR2+HDS+MS(4) 9,387.00 79.93 73.52 4,072.74 3,979.95 -1,884.80 7,097.67 5,978,944.82 556,676.04 1.19 5,818.13 MWD+IFR2+HDS+MS(4) 9,417.00 81.23 73.26 4,077.65 3,984.86 -1,876.34 7,126.03 5,978,953.47 556,706.34 4.42 5,847.56 MWD+IFR2+HDS+MS(4) 9,446.78 82.84 73.19 4,081.77 3,988.98 -1,867.83 7,154.27 5,978,962.16 556,734.52 5.41 5,876.89 MWD+IFR2+HDS+MS(4) 9,484.37 85.60 73.00 4,085.56 3,992.77 -1,855.96 7,190.05 5,978,973.27 556,770.22 7.36 5,914.09 MWD-INC_ONLY (5) 9,579.45 88.57 71.42 4,090.39 3,997.60 -1,827.95 7,280.45 5,979,002.88 556,860.42 3.54 6,008.68 MWD+IFR2+HDS+MS(6) 9,609.00 90.20 70.68 4,090.71 3,997.92 -1,818.35 7,308.40 5,979,012.66 556,888.30 6.06 6,038.17 MWD+IFR2+HDS+MS(6) 9,639.0 91.22 69.88 4,090.34 3,997.55 -1,8N+23 7,335.64 5,979,022.96 556,916.47 4.32 6,068.12 MWD+IFR2+HDS+MS (6) 9,669.0 90.54 68.96 4,089.88 3,997.09 -1,797.69 7,364.72 5,979,033.69 556,944.48 3.81 6,098.10 MWD+IFR2+HDS+MS(6) 9,699.00 89.98 67.59 4,089.74 3,996.95 -1,786.58 7,392.59 5,979,041.98 556,972.27 4.93 6,128.09 MWD+IFR2+HDS+MS(6) 9,729.00 89.52 66.01 4,089.87 3,997.08 -1,774.76 7,420.16 5,979,056.98 556,939.76 5.49 6,158.09 MWD+IFR2+HDS+MS(6) 9,759.00 88.99 64.20 4,090.26 3,997.47 -1762.14 7,447.37 5,979,069.78 557,026.88 6.29 6,188.6 MWD+IFR2+HDS+MS(6) 9,789.00 88.43 62.75 4,090.94 3,998.15 -1,748.74 7,474.20 5,979883.35 557,053.62 5.18 6,217.99 MWD+IFR2+HDS+MS(6) 9,819.00 87.88 61.50 4,091.90 3,999.11 -1,734.72 7,50071 5,979,097.55 557,080.03 4.55 6,247.85 MND+IFR2+HDS+MS (6) 9,849.00 87.30 60.25 4,093.17 4,000.38 -1720.14 7,526.89 5,979,112.31 557,106.12 4.59 6,277.64 MWD+IFR2+HDS+MS(6) 9,879.00 86.99 59.37 4,094.66 4,001.87 -1,705.07 7,552.79 5,979,127.54 557,131.91 3.11 6,307.35 MWD+IFR2+HDS+MS(6) 9,909.00 87.20 58.86 4,096.18 4,003.39 -1,689.69 7,578.50 5,979,143.09 557,157.52 1.64 6,337.1 MWD+IFR2+HDS+MS(6) 9,939.00 88.55 58.36 4,097.29 4,004.50 -1,674.07 7,604.09 5,979,158.87 557,183.00 4.80 6,366.64 MWD+IFR2+HDS+MS(6) 9,969.00 89.78 57.61 4,097.73 4,004.94 -1,658.17 7,629.53 5,979,174.94 557,208.33 4.80 6,396.24 MWD+IFR2+NDS+MS(6) 9,999.00 90.64 56.32 4,097.62 4,004.83 -1,641.82 7,654.68 5,979,191.46 557,233.37 5.17 6,425.76 MWD+IFR2+HDS+MS(6) 10,029.00 90.80 55.02 4,097.24 4,004.45 -1.624.90 7,679.45 5,979,208.54 557,258.02 4.37 6,455.14 MWD+IFR2+HDS+MS (6) 9/1012018 3:00:31PM Page 9 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Project: Kuparuk River unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Site: Kupamk 1H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: Rig: 1H -1D4 North Reference: True Wellborn: 1 H-104 Survey Calculation Method: Minimum Curvature Design: 1 H-104 Database: OAKEDMP2 Survey Nap Limp Vertical MD Inc AN TVD TVDSS +W -S +E/ -W Northing Easting DLS Section (usfry 11 (1) (-it) (usR) (usft) (usf) (ft) (ft) (°11001 (try Survey Tool Name 10,059.00 90.48 53.70 4,096.91 4,004.12 -1,607.42 7,703.83 5,979,226.18 557,28228 4.53 6,484.38 MWD+IFR2+HDS+MS(6) 10,089.00 8994 52.29 4,096.80 4,004.01 -1,589.37 7,727.78 5,979,244.39 557,306.12 5.03 6,513.46 MWD+IFR2+HDS+MS(6) 10,119.00 89.25 50.96 4,097.01 4,004.22 -1,570.74 7,751.30 5,979,263.17 557,329.51 4.99 6,542.34 MWD+IFR2+HDS+MS(6) 10,149.00 88.49 49.79 4,097.60 4,004.81 -1,551.61 7,774.40 5,979,282.45 557,352.48 4.65 6,571.04 MWD+IFR2+HDS+MS(6) 10,179.00 87.91 48.47 4,098.54 4,005.75 -1,531.99 7,797.08 5,979,302.21 557,375.02 4.80 6,599.54 MWD+IFR2+HDS+MS(6) 10,209.00 87.43 47.30 4,099.76 4,006.97 -1,511.89 7,819.31 5,979,322.46 557,397.12 4.21 6,627.81 MWD+IFR2+HDS+MS(6) 10,239.00 87.18 46.58 4,101.17 4,008.38 -1,491.43 7,841.21 5,979,343.[6 557,418.88 2.54 6,655.91 MWD+IFR2+HDS+MS (6) 10,269.00 87.62 45.55 4,102.53 4,009.74 -1,470.64 7,862.79 5,979,364.00 557,440.32 3.73 6,683.85 MWD+IFR2+HDS+MS (6) 10,299.00 88.35 44.12 4,103.59 4,010.80 -1,449.38 7,883.93 5,979,385.39 557,46132 5.36 6,711.55 MWD+IFR2+HDS+MS(6) 10,329.00 89.68 41.97 4,104.10 4,011.31 -1,427.46 7,904.40 5,979,407.45 557,481.64 8.41 6,738.92 MWD+1FR2+HDS+MS(6) 10,359.00 90.69 40.71 4,104.00 4,011.21 -1,404.94 7,924.21 5,979430.10 557,501.31 5.38 6,765.89 MWD+IFR2+HDS+MS(6) 10,389.00 90.89 40.03 4,103.59 4,010.80 -1,382.08 7,943.64 5,979,453.08 557,520.58 2.36 6,792.65 MWD+IFR2+HDS+MS(6) 10,419.00 91.59 39.35 4,1 D2.94 4,010.15 -1,359.00 7,962.80 5,979,476.28 557,539.58 3.25 6,819.23 MWD+IFR2+HDS+MS(6) 10,449.W 92.06 38.97 4,101.99 4,009.20 -1,335.75 7,981.73 5,979,499.65 557,558.36 2.01 6,845.68 MWD+IFR2+HDS+MS(6) 10,479.00 91.98 38.95 4,100.93 4,008.14 -1,312.44 8,000.58 5,979,523.09 557,577.06 0.27 6,872.07 MWD+IFR2+HDS+MS(6) 10,500.00 91.85 38.94 4,099.93 4,007.14 -0,289.12 8,019.43 5,979,646.53 557,595.75 0.43 6,898.47 MWD+IFR2+HDS+MS (6) 10,539.00 91.15 39.19 4,009.14 4,006.35 -1,265.83 8,038.33 5,979,569.94 557,614.49 2.48 6,924.90 MWD+IFR2+HDS+MS(6) 10,569.00 90.65 40.05 4,098.67 4,005.88 -1,242.73 8,057.46 5,979,593.17 557,633.46 3.32 6,951.47 MWD+IFR2+HDS+MS(6) 10,599.00 90.60 40.92 4,008.34 4,005.55 -1,219.91 8,076.93 5,979,616.11 557,652.78 2.90 6,978.25 MWD+IFR2+HDS+MS(6) 10,629.00 91.03 41.82 4,097.91 4,005.12 -1,197.40 8,096.76 5,979,638.75 557,672.46 3.32 7,005.23 MWD+IFR2+HDS+MS(6) 10,659.00 Well 42.83 4,097.41 4,004.62 -1,175.23 8,116.96 5,979,66106 557,692.51 3.40 7,032.43 MWD+IFR2+HDS+MS(6) 10,689.00 91.06 43.85 4,096.91 4,004.12 -1,153.41 8,137.54 5,979,683.W 557,712.95 3.45 7,059.84 MWD+IFR2+HDS+MS(6) 10,719.00 91.81 44.73 4,096.16 4,OW.37 -1,131.94 8,158.48 5,979,704.61 557,733.74 3.85 7,087.45 MWD+IFR2+HDS+MS(6) 10,749.00 91.58 44.42 4,095.27 4,002.48 -1,110.58 8,179.53 5,979,726.11 557,754.65 1.29 7,115.12 MWD+IFR2+HDS+MS(6) 10,779.W 91.55 43.88 4,094.45 4,001.66 4,089.07 8,200.42 5,979,747.76 557,775.39 1.80 7,142.70 MWD+IFR2+HDS+MS(6) 10,800.00 91.57 43.29 4,093.63 4,WD.84 -1,067.34 8,221.09 5,979,769.62 557,795.92 1.97 7,170.16 MWD+IFR2+HDS+MS(6) 10,831.11 92.33 43.36 4,002.88 4,000.00 -1,05127 8,236.26 5,979,785.79 557,810.97 3.45 7,190.36 MWD+IFR2+HDS+MS(7) 10,839.00 92.30 43.23 4,092.56 3,999.77 -1,045.53 8,241.66 5,979,791.56 557,Bi6.34 1.69 7,197.56 MWDHFR2+HDS+MS(7) 10,869.00 91.76 42.93 4,091.49 3,998.70 -1,D23.63 8,262.14 5,979,813.59 557,836.67 2.00 7,224.91 MWD+IFR2+HDS+MS (7) 10,899.00 90.11 43.29 4,001.00 3,998.21 -1,001.73 8,282.64 5,979,835.62 557,857.02 5.69 7,252.28 MWD+IFR2+HDS+MS(7) 10,929.00 88.38 43.1D 8091.39 3,998.60 -979.87 8,303.17 5,979,657.62 557,877.40 5.80 7,279.66 MWD+IFR2+HDS+MS(7) 10,959.00 88.31 42.50 4,092.26 3,999.47 -957.86 8,323.54 5,979,879.76 557,897.63 2.01 7,306.96 MWD+IFR2+HDS+MS (7) 10,989.00 89.19 41.90 4,092.91 4,00.12 -935.64 8,343.69 5,979,902.11 557,917.63 3.55 7,334.12 MWD+IFR2+HDS+MS (7) 11,019.00 88.93 41.63 4,093.41 4,000.62 -913.27 8,363.67 5,979,924.61 557,937.46 1.25 7,361.20 MWD+IFR2+HDS+MS(7) 11,099.00 88.87 41.75 4,093.98 4,001.19 -990.87 8,383.62 5,979,947.14 557,957.26 0.45 7,388.25 MWD+IFR2+HDS+MS(7) 11,079.00 88.23 41.86 4,094.74 4,001.95 .868.52 8,403.61 5,979,969.62 557,977.10 2.16 7,415.33 MWD+IFR2+HDS+MS(7) 11,109.00 87.01 41.84 4,095.99 4,003.20 -846.19 8,423.61 5,979,992.08 557,996.94 4.07 7,442.40 MWD+IFR2+HDS+MS(7) 11,139.00 86.76 41.49 4,097.62 4,004.83 -823.81 8,443.52 5,980,014.59 558,016.71 1.43 7,469.41 MWD+IFR2+HDS+MS(7) 11,169.00 87.51 41.14 4,099.12 4,006.33 -801.31 8,463.30 5,980,037.22 558,036.34 2.76 7,496.36 MWD+IFR2+HDS+MS(7) 11199.00 89.47 40.58 4,099.91 4,007.12 -778.63 8,482.92 5,980,060.03 558,055.80 6.79 7,523.21 MWD+IFR2+HDS+MS (7) 9/10/2018 3:00:31PM Page 10 COMPASS 5000.14 Build 85 Company: Project: Site: Well: Wellbore: Design: Survey NADConversion Kuparuk River Unit Kuparuk 1H Pad Rig: 1H-104 1H-104 1H-104 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 1 H-104 IH -104 actual @ 92.79usft (Doyon 142) 1H-104 actual @ 92.79usft (Doyan 142) True Minimum Curvature OAKEDMP2 9/102018 3:00.31PM Page 11 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc AM TVD TVDSS +WS +E/.W Northing Easting DLS Section (usft) (1) r) (usft) (usft) (usft) (usft) (h) (ft) rifoo.) (ft) Survey Tool Name 11,229.00 91.43 39.35 4,099.67 4,006.88 -755.64 8,502.19 5,9801083.14 558,074.92 7.71 7,549.87 MWD+IFR2+HDS+MS (7) 11,259.00 92.77 37.87 4,098.57 4,005.78 -732.21 8,520.90 5,980,106.69 558,093.47 6.65 7,576.17 MWD+IFR2+HDS+MS(7) 11,289.00 93.98 WAS 4,096.81 4,004.02 -708.30 8,538.93 5,980,130.71 558,111.34 6.92 7,602.4 1OND+IFR2+11DS+MS(7) 11,319.00 94.88 35.30 4,094.49 4,001.70 -684.03 8,556.40 5,980,155.10 558,128.65 4.19 7,627.54 MWD+IFR2+HDS+MS(7) 11,349.00 94.57 34.90 4,092.02 3,999.23 559.57 8,573.59 5,980,179.68 558,145.68 1.68 7,652.85 MWD+IFR2+HDS+MS(7) 11,379.0 94.47 34.80 4,089.65 3,996.86 -635.02 8,590.68 5,980,204.33 558,162.60 0.47 7,678.09 MWD+IFR2+HDS+MS(7) 11,409.00 94.23 35.16 4,087.38 3,994.59 510.51 8,607.83 5,980,228.95 558,179.59 1.44 7,703.38 MND+IFR2+HDS+MS(7) 11,439.00 94.2 35.66 4,085.22 3,992.43 -5W.13 8,625.17 5,980,253.45 558,196.76 1.80 7,72B.79 MND+IFR2+HDS+MS (7) 11,469.00 93.55 36.16 4,083.24 3,990.45 561.88 8,642.73 5,980,277.81 558,214.15 2.28 7,754.36 MND+IFR2+HDS+MS (7) 11,499.00 93.36 36.30 4,081.43 3,988.64 637.72 8,660.42 5,980,302.08 558,231.69 0.79 7,780.01 MND+IFR2+HDS+MS (7) 11,529.00 93.38 36.24 4,079.67 3,986.88 513.58 8,678.14 5,980,326.34 558,249.25 0.21 7,805.68 MWD+IFR2+HDS+MS(7) 11,559.00 93.08 WAS 4,077.98 3,985.19 489.41 8,695.84 5,980,350.62 558,266.78 1.01 7,831.34 MND+IFR2+HDS+MS(7) 11,589.00 92.78 35.52 4,076.44 3,983.65 -465.13 8,713.39 5,98,375.01 558,284.17 2.44 7,856.91 MWD+IFR2+HDS+MS(7) 11,619.00 92.71 34.22 4,075.01 3,982.22 440.55 8,73D.52 5,980,399.71 558,301.13 4.33 7,882.21 MWD+IFR2+HDS+MS(7) 11,648.00 92.51 32.92 4,073.64 3,98D.85 415.58 8,747.09 5,980,424.78 558,317.54 4.38 7,907.15 MWD+IFR2+HDS+MS (7) 11,679.00 92.76 32.04 4,072.26 3,979.47 JW.30 8,763.18 5,980,450.17 558,333.46 3.05 7,931.76 MND+IFR2+HDS+MS (7) 11,709.00 93.78 31.36 4,070.55 3,977.76 4164.81 8,778.92 5,98,475.75 558,349.03 4.08 7,956.12 MND+IFR2+HDS+MS (7) 11,739.00 95.11 29.19 4,068.23 3,975.44 J38.99 8,794.00 5,980,501.68 558,363.93 8.47 7,980.01 MND+IFR2+HDS+MS (7) 11,769.00 95.79 27.28 4,065.38 3,972.59 -312.68 8,808.13 5,980,528.08 658,377.89 6.73 8,003.20 MWD+IFR2+HDS+MS(7) 11,799.00 95.87 26.46 4,062.33 3,969.54 -286.05 8,821.61 5,980,554.78 558,391.20 2.73 8,025.93 MWD+IFR2+HDS+MS(7) 11,829.00 95.95 25.75 4,059.24 3,966.45 -259.26 8,834.75 5,980,581.66 558,404.15 2.37 8,048.39 MWD+IFR2+HDS+MS(7) 11,859.0 95.89 25.00 4,056.15 3,963.36 -232.30 8,847.53 5,980,WB.71 558,416.76 2.49 8,070.61 MWD+IFR2+HDS+MS(7) 11,889.00 95.88 24.06 4,053.07 3,960.28 -205.15 8,859.92 5,98,635.93 558,428.96 3.12 8,092.52 MWD+IFR2+HDS+MS(7) 11,919.00 95.44 23.09 4,50.11 3,957.32 -177.79 8,871.85 5,980,653.37 558,44012 3.54 8,114.11 MWD+IFR2+HDS+MS(7) 11,949.00 94.71 22.11 4,047.46 3,954.67 -150.20 8,883.34 5,980,691.03 558,452.02 4.06 8,135.36 MWD+IFR2+HDS+MS(7) 11,979.00 94.15 20.96 4,045.14 3,952.35 -122.38 8,694.32 5,980,718.92 558,462.81 4.25 8,156.24 MND+IFR2+HDS+MS(7) 12.09.00 93.63 19.76 4,043.10 3,950.31 -94.32 8,904.74 5,98,747.05 558,473.04 4.35 8,176.68 MND+IFR2+HDS+MS(7) 12,039.00 93.04 18.56 4,041.36 3,948.57 66.03 8,914.57 5,980,775.40 558,482.68 4.45 8,196.68 MWD+IFR2+HDS+MS(7) 12,069.00 92.86 17.09 4,039.82 3,947.03 -37.51 6,923.74 5,980,803.98 558,491.66 4.93 8,216.16 MWD+IFR2+HDS+MS(7) 12,099.0 92.75 15.49 4,038.35 3,945.56 -315 8,932.14 5,98,832.79 558,499.88 5.34 8,235.02 MWD+IFR2+HDS+MS (7) 12,129.00 91.64 13.88 4,037.20 3,944.41 20.25 8.939.74 5,980,861.83 558,507.28 6.52 8,253.24 MWD+IFR2+HDS+MS (7) 12,159.00 90.82 12.38 4,036.55 3,943.76 49.6 8,946.55 5,980,891.08 558,513.90 5.70 8,270.81 MND+IFR2+HDS+MS(7) 12,189.00 90.85 11.00 4,036.12 3,943.33 78.83 8,952.63 5,980,920.50 558,519.78 4.60 8,287.76 MWD+IFR2+HDS+MS(7) 12,219.00 90.83 9.61 4,035.68 3,942.89 108.35 8,958.00 5,980,950.04 558,524.95 4.63 8,304.11 MWD+IFR2+HDS+MS(7) 12,249.00 90.88 8.64 4,035.23 3,942.44 137.96 8,962.75 5,980,979.68 558,529.51 3.24 8,319.95 MND+IFR2+HDS+MS (7) 12,279.00 91.03 8.54 4,034.73 3,941.94 167.62 8,967.23 5,961,009.37 558,533.80 0.60 8,335.54 MWD+IFR2+HDS+MS(7) 12,309.00 91.67 8.46 4,034.02 3,941.23 197.28 8,971.67 5,981,039.6 558,538.03 2.15 8,351.09 MND+IFR2+HDS+MS (7) 12,339.00 92.12 8.36 4,033.03 3,940.24 226.94 8,976.05 5,981,068.74 558,542.22 1.54 8,366.59 MN4D+IFR2+HOS+MS (7) 12,369.0 92.35 8.16 4,031.86 3,939.07 256.61 8,980.36 5,981,098.44 558,546.33 1.02 8,382.03 MWD+IFR2+HDS+MS(7) 12,399.00 92.73 7.95 4,030.53 3,937.74 286.29 8,984.56 5,981,12B.13 558,550.33 1.45 8,397.37 MWD+IFR2+HDS+MS(7) 9/102018 3:00.31PM Page 11 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: 1H-104 Project: Kuparuk River Unit TVD Reference: iH-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Well: Rig: iH-104 North Reference: True Wellbore: 1H-104 Survey Calculation Method: Minimum Curvature Design: 1 H-104 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Aid TVD TVDSS +NIS +E/.W Northing Seating DIS Section (tuft) C) C) (U*R) Will (usft) (uefq IN) (1q C/1001 (ft) Survey Tool Name 12,429.00 92.97 7.75 4,029.04 3,93515 315.97 8,988.65 5,981,157.84 558,554.23 1.04 8,412.61 MWD+IFR2+HDS+MS(7) 12,459.00 92.96 7.56 4,027.49 3,934.70 345.66 8,992.64 5,981,187.56 558,558.02 0.63 8427.77 MWD+IFR2+HDS+MS(7) 12,489.00 92.67 7.38 4,025.96 3,933.17 375.37 8,996.64 5,981,217.28 558,561.72 0.67 8,442.84 MWD+IFR2+HDS+MS(7) 12,519.00 92.40 7.17 4,024.58 3,931.79 405.09 9,000.33 5,981,247.03 558,565.32 1.72 8,457.83 MWD+IFR2+HDS+MS(7) 12,549.00 92.40 6.77 4,023.33 3,930.54 434.85 9,003.97 5,981,276.81 556,568.76 1.33 8,472.68 MWD+IFR2+HDS+MS (7) 12,579.00 92.36 6.33 4,022.08 3,929.29 464.62 9,007.39 5,981,306.60 558,571.98 1.47 8,487.34 MND+IFR2+HDS+MS (7) 12,609.00 91.42 5.91 4,021.09 3,92B.30 494.44 9,010.59 5,981,336.43 558,574.98 3.43 8,501.80 MND+IFR2+HDS+MS(7) 12,639.00 90.43 5.94 4,020.61 3,927.82 524.27 9,013.68 5,981,366.29 558,577.88 3.30 8,516.19 MWD+IFR2+HDS+MS(7) 12,669.00 90.40 6.15 4,020.39 3,927.60 554.10 9,016.84 5,981,396.14 558,580.84 0.71 8,530.63 MND+IFR2+HDS+MS (7) 12,699.00 89.45 6.37 4,020.43 3,927.64 583.93 9,020.11 5,981,425.97 558,583.91 3.25 8,545.17 MWD+IFR2+HDSWS(7) 12,729.00 88.84 6.26 4,020.88 3,928.09 613.74 9,023.41 5,981,455.81 558,587.02 2.07 8,559.73 MWD+IFR2+HDS+MS(7) 12,759.00 88.50 5.96 4,021.57 3,928.78 643.56 9,026.60 5,981485.65 558,590.01 1.51 8,574.20 MWD+IFR2+HDS+MS(7) 12,789.00 89.74 5.66 4,022.03 3,929.24 673.40 9,029.64 5,981,515.50 558,592.85 4.25 8,588.53 MWD+IFR2+HDS+MS(7) 12,819.00 89.96 4.97 4,022.11 3,929.32 703.27 9,032.42 5,981,545.39 558,595.43 2.41 8,602.64 MWD+IFR2+HDS+MS(7) 12,849.00 89.95 3.49 4,022.14 3,929.35 733.19 9,034.63 5,981,575.32 558,597.44 4.93 8,616.24 MWD+IFR2+HDS+MS(7) 12,879.00 91.07 2.02 4,021.87 3,929.08 763.15 9,036.07 5,981,605.29 558,598.69 6.16 8,629.14 MWD+IFR2+HDS+MS(7) 12,909.00 91.54 0.73 4,021.19 3,928.40 793.14 9,036.79 5,981,635.27 558,599.21 4.58 8,641.39 MWD+IFR2+HDS+MS(7) 12,939.00 91.52 0.24 4,020.38 3,927.59 823.13 9,037.05 5,981,665.26 558,599.26 1.63 8,653.21 MWD+IFR2+HDS+MS(7) 12,969.00 91.81 359.59 4,019.51 3,926.72 853.11 9,037.00 5,981,695.24 558,599.02 2.37 8,664.76 MWD+IFR2+HDS+MS(7) 12,999.00 91.94 359.08 4,018.53 3,925.74 883.09 9,036.66 5,981,725.22 558,598.47 1.75 8,676.02 MWD+IFR2+HDS+MS (7) 13,029.00 91.73 356.81 4,017.57 3,924.78 913.07 9,036.10 5,981,755.19 558,597.72 1.14 8,667.10 MWD+IFR2+HDS+MS 17) 13,059.00 91.39 358.57 4,016.75 3,923.96 943.05 9,035.42 5,981,785.16 558,596.84 1.39 8,698.05 MWD+IFR2+HDS+MS (7) 13,089.00 91.15 356.30 4,016.09 3,923.30 973.04 9,034.60 5,981,815.13 558,595.82 1.20 8,708.88 M1AD+IFR2+HDS+MS (7) 13,119.00 90.99 357.54 4,015.53 3,922.74 1,W3.01 9,033.51 5,981,845.10 558,594.54 2.59 8,719.6 MWD+IFR2+HDS+MS(7) 13,149.00 90.69 356.59 4,015.09 3,922.30 1,032.97 9,031.97 5,981,875.04 558,592.80 3.32 8,729.62 MWD+IFR2+HDS+MS(7) 13,179.00 90.17 355.65 4,014.86 3,922.07 1,062.90 9,029.94 5,981,904.95 558,590.57 3.58 8,739.31 MWD+IFR2+HDS+MS(7) 13,209.00 90.21 354.37 4,014.76 3,921.97 1,092.78 9,027.33 5,981,934.82 558,587.77 4.27 8,748.5 MWD+IFR2+HDS+MS(7) 13,239.00 89.79 352.87 4,014.76 3,921.97 1,122.60 9,024.00 5,981,964.61 558,584.24 5.19 8,756.90 MWD+IFR2+HDS+MS(7) 13,269.00 90.04 351.36 4,014.81 3,922.02 1,152.31 9,019.89 5,961,994.29 558,579.93 5.10 8,764.58 MWD+IFR2+HDS+MS(7) 13,299.00 90.23 350.39 4,014.74 3,921.95 1,181.93 9,015.13 5,982,023.88 558,574.97 3.29 8,771.64 MWD+IFR2+HDS+MS(7) 13,329.00 90.01 349.94 4,014.68 3,921.89 1,211.49 9,010.00 5,982,053.40 558,569.65 1.67 8,778.33 MND+IFR2+HDS+MS (7) 13,359.00 90.73 349.50 4,014.48 3,921.69 1,241.01 9,004.65 5,982,082.88 558,564.11 2.81 8,784.80 MND+IFR2+HDS+MS (7) 13,389.00 91.10 349.52 4,014.W 3,921.21 1,270.50 8,999.19 5,982,112.33 558,558.45 1.24 8,791.16 MND+IFR2+HDS+MS(7) 13,419.00 91.31 350.37 4,013.37 3,920.58 1,300.04 8,993.95 5,982,141.83 558,553.02 2.92 8,797.74 MWD+IFR2+HDS+MS(7) 13,449.00 91.42 351.22 4,012.66 3,919.87 1,329.64 8,989.15 5,982,171.40 558,540.03 2.86 8,804.76 MND+IFR2+HDS+MS(7) 13,479.00 91.69 352.09 4,011.84 3,919.05 1,359.31 8,984.80 5,982,201.03 558,543.48 3.04 8,812.21 MND+IFR2+HDS+MS (7) 13,609.00 91.70 353.01 4,010.96 3,918.17 1,389.05 8,980.91 5,982,23014 558,539.39 3.07 8,820.11 MND+IFR2+HDS+MS (7) 13,539.00 91.92 353.93 4,010.01 3,917.22 1,418.84 8,977.50 5,982,260.50 558,535.79 3.15 8,828.48 MND+IFR2+HDS+MS(7) 13,569.00 92.W 354.49 4,008.98 3,916.19 1,448.66 8,974.48 5,982,290.31 558,532.56 1.88 8,637.21 MND+IFR2+HDS+MS(7) 13,599.00 91.95 353.85 4,007.95 3,915.16 1,478.49 8,971.44 5,982,320.11 558,529.32 2.11 8,845.93 MND+IFR2+HDS+MS (7) 9110/2018 3:00:31PM Pape 12 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Project: Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: 1H-104 Survey Calculation Method: Minimum Curvature Design: 1 H-104 Database: OAKEDMP2 Survey 9/10/2018 3:00:31PM Page 13 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Aid TVD TVDSS +NI.4 +E/ -W Northing Easting DLS Section (usfl) (1) (1) (usft) (usR) ("it) (-in (1q (In r/1001 (it) Survey Tool Name 13,629.00 92.21 353.14 4,006.86 3,914.07 1,508.28 8,968.04 5,982,349.87 558,525.73 2.55 8,854.31 M AFR2+HDS+MS (7) 13,659.00 92.51 352.47 4,005.62 3,912.83 1,538.02 8,964.29 5,982,379.58 558,521.78 2.45 8,862.34 MWD+IFR2+HDS+MS(7) 13,689.00 92.65 352.05 4,004.27 3,911.48 1,567.71 8,960.25 5,982,409.25 558,517.55 1.47 8,870.09 MWD+IFR2+HDS+MS(7) 13,719.00 91.97 351.66 4,003.06 3,910.27 1,597.39 B,956.01 5,982,43BS9 558,513.11 2.61 8,877.64 MWD+IFR2+HDS+MS(7) 13,749.00 89.99 351.21 4,002.55 3,909.76 1,627.05 8,951.54 5,982,468.52 558,508.45 6.77 8,884.98 MWD+IFR2+HDS+MS(7) 13779.00 88.27 350.36 4,003.01 3,910.22 1,656.65 8,946.73 5,982,498.09 558,50345 6.40 8,891.99 MWD+IFR2+HDS+MS(7) 13,809.00 86.65 349.46 4,004.34 3,911.55 1,686.16 8,941.48 5,982,527.56 558,490.00 6.18 8,898.55 MWD+IFR2+HDS+MS(7) 13,839.D0 85.02 348.61 4.06.51 3,913.72 1,715.53 8,935.79 5,982,556.89 558,492.12 6.12 8,904.65 MWD+IFR2+HDS+MS(7) 13,869.00 83.68 348.12 4.09.47 3,916.68 1,744.77 8,929.77 5,982,586.09 558,485.90 4.75 8,910.39 MWD+IFR2+HDS+M$(7) 13,899.00 82.29 347.69 4,013.13 3,920.34 1]73.89 8,923.53 5,982,615.16 558,479.47 4.85 8,915.89 MWD+IFR2+HDS+MS(7) 13,929.00 81.08 347.20 4,017.47 3,924.68 1,802.66 8,917.08 5,982,644.08 558,472.83 4.35 8,921.13 MWD+IFR2+HDS+MS(7) 13,959.00 79.93 346.08 4,022.42 3,929.63 1,831.65 8,910.25 5,982,672.82 558,465.80 5.32 8,925.95 MWD+IFR2+HDS+MS(7) 13,989.00 78.94 344.80 4,027.92 3,935.13 1,860.19 8,902.83 5,982,701.31 558,458.20 5.34 8,930.14 MWD+IFR2+HDS+MS (7) 14,019.00 78.80 343.51 4,033.71 3,940.92 1,888.51 8,894.B0 5,882,729.57 558,449.98 4.24 8,933.67 MWD+IFR2+HDS+MS(7) 14,049.00 78.94 341.95 4,039.50 3,946.71 1,916.62 8,886.6 5,9B2,757.62 558,441.06 5.12 8,936.47 MWD+IFR2+HDS+MS(7) 14,079.00 79.01 340.30 4,045.24 3,952.45 1,944.48 8,876.53 5,982,785.42 558,431.35 5.40 8,938.45 MWD+IFR2+HDS+MS(7) 14,109.00 79.17 338.64 4,050.92 3,958.13 1,972.06 8,866.20 5,982,812.93 558,420.84 5.46 8,939.58 MWD+IFR2+HDS+MS(7) 14,139.00 79.67 336.76 4,056.43 3,963.64 1,999.35 8,855.01 5,982,840.13 558,409.47 6.38 8,939.81 MWD+IFR2+HDS+MS(7) 14,169.00 80.51 334.78 4,061.59 3,968.80 2,026.29 8,842.88 5,982,867.00 558,397.16 7.08 8,939.03 MWD+IFR2+HDS+MS(7) 14,199.00 81.40 332.80 4,066.31 3,973.52 2,052.87 8,829.80 5,982,893.49 558.383.90 7.16 8,937.23 MWD+IFR2+HDS+MS(7) 14,229.00 82.22 331.13 4,D70.58 3,977.79 2,079.08 8,815.84 5,982,919.60 558,369.77 6.15 8,934.49 MWD+IFR2+HDS+MS(7) 14,259.00 83.03 329.62 4,074.43 3,981.64 2,104.94 8,801.14 5,982,945.36 558,354.90 5.68 B,930.92 MWD+IFR2+HDS+MS(7) 14,289.00 84.62 328.12 4,077.66 3,984.87 2,130.47 8,785.72 5,9B2,970.79 558,339.31 7.27 8,926.56 MWD+IFR2+HDS+MS(7) 14,319.00 86.82 326.43 4,079.90 3,987.11 2,155.64 8,769.54 5,982,995.84 558,322.9B 9.24 8,921.37 MWD+IFR2+HDS+MS 17) 14,349.00 89.29 324.61 4,080.92 3,988.13 2,180.35 8,752.57 5,983,020.49 558,305.84 10.22 8,915.26 MWD+IFR2+HDS+MS(7) 14,379.00 90.53 322.79 4,080.96 3,988.17 2204.53 8,734.81 5,983,044.49 558,287.92 7.34 6,908.22 MWD+IFR2+HDS+MS (7) 14,409.00 92.12 321.85 4,080.27 3,987.48 2,228.26 8,716+8 5,983,060.11 558,269.44 6.16 8,900.49 MWD+IFR2+HDS+MS (7) 14,439.00 94.22 321.78 4,078.61 3,985.82 2,251.80 8,697.96 5,983,091.52 558,250.77 7.00 8,892.51 MWD+IFR2+HDS+MS (7) 14,469.00 95.14 321.71 4,076.16 3,983.37 2275.28 8,679.45 5,983,114.88 558,232.10 3.08 8,884.50 MWD+IFR2+HDS+MS (7) 14,499.00 95.01 321.67 4,073.51 3,980.72 2,298.73 8,660.93 5,983,138.211 558,213.42 0.45 8,876.48 MWD+IFR2+HDS+MS (7) 14,529.00 95.66 321.66 4,070.72 3,977.93 2,322.16 8,642.40 5,983,161.50 558,194.74 2.17 B,Wo," MWD+IFR2+HDS+MS(7) 14,559.00 96.99 321.66 4,067.42 3,974.63 2,345.55 8,623.90 5,983,184.76 558,176.10 4.43 8,860.42 MWD+IFR2+HDS+MS (7) 14.589.00 97.52 321.44 4,063.63 3,970.84 2,368.85 8505.40 5,983,207.95 558,157.44 1.91 8,852.36 MWD+1FR2+HDS+MS (7) 14,619.00 95.71 320.85 4,060.17 3,967.38 2,392.06 8,586.70 5,983,231.02 558,138.59 6.34 8,844.08 MWD+IFR2+HDS+MS(7) 14,649.00 93.67 320.25 4,057.72 3,964.93 2.415.15 8,567.71 5,983,253.98 558,119.44 7.09 8,835.48 MWD+IFR2+HDS+MS (7) 14,679.00 91.95 319.59 4,056.25 3,963.46 2,438.07 8,548.41 5,983,276.78 558,100.00 6.14 8,826.54 MWD+IFR2+HDS+MS(7) 14,709.00 92.01 318.77 4,055.21 3,962.42 2,460.76 8,528.82 5,983,299.33 558,080.26 2.74 8,817.23 MWD+IFR2+HDS+MS(7) 14,739.00 92.15 317.96 4,054.12 3,961.33 2,483.17 8,508.90 5,983,321.61 558,060.19 2.74 8,807.52 MWD+IFR2+HDS+MS(7) 14,769.00 92.27 317.04 4,052.97 3,960.18 2,505.27 8,488.65 5,983,343.57 558.39.80 3.09 8,797.38 MWD+IFR2+HDS+MS(7) 14,799.00 92.24 315.84 4,051.78 3,958.99 2,526.99 8,467.99 5,983,365.16 558,019.00 4.00 8,786.72 MWD+IFR2+HDS+MS(7) 9/10/2018 3:00:31PM Page 13 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Project: Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Dayan 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: 1H-104 Survey Calculation Method: Minimum Curvature Design: 1 H-104 Database: OAKEDMP2 Survey 9110/2018 3:00:31PM Page 14 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +WS +E/ -W Northing Easting DLS Section (usft) (1) (°) (usl) NO" (Wft) Wall) (ft) (fU (°1100') (ft) Survey Tool Name 14,629.00 92.25 314.64 4,050.61 3,957.82 2,54828 8,446.88 5,983,386.30 557,997.75 4.00 8,775.48 MWD+IFR2+HDS+MS(7) 14,859.00 92.55 313.41 4,049.35 3,956.56 2,569.11 8,425.33 5,983,406.98 557,976.07 4.22 8,763.65 MWD+IFR2+HDS+MS(7) 14,889.00 92.83 312.12 4,047.95 3,955.16 2,589.45 8,403.33 5,983,427.18 557,953.93 4.40 8,751.22 MWD+IFR2+HDS+MS(7) 14,919.00 92.77 310.83 4,046.48 3,953.69 2,609.30 8,380.88 5,983,446.88 557,931.35 4.30 8,738.18 MWD+IFR2+HDS+MS(7) 14,949.00 92.80 309.59 4,045.02 3,952.23 2.628.64 8,358.00 5,983,466.07 557,908.35 4.13 8,724.55 MW13+IFR2+HDS+MS(7) 14,979.00 92.35 308.54 4,043.67 3,950.88 2,647.53 8,334.73 5,983,484.80 557,884.96 3.80 8,710.39 MWD+IFR2+HDS+MS(7) 15,009.0 91.12 307.50 4,042.77 3,949.98 2,666.W 8,311.11 5,983,503.11 557,861.21 5.37 8,695.74 MWD+IFR2+HDS+MS(7) 15,039.00 89.89 306.39 4,042.50 3,949.71 2,684.03 8,287.13 5,983,520.98 557,837.12 5.52 8,680.59 MWD+IFR2+HDS+MS(7) 15,069.00 89.34 304.91 4,042.70 3,949.91 2,701.51 8,262.75 5,983,538.30 557,812.63 5.26 8,664.86 MWD+1FR2+HDS+MS(7) 1509.00 89.87 302.61 4,042.91 3,950.12 2,718.18 8,237.82 5,983,554.80 557,787.59 7.87 8,648.30 MWD+IFR2+HDS+MS(7) 15,129.00 91.76 300.06 4,042.48 3,949.69 2,733.78 8,212.20 5,983,570.23 557,761.87 10.58 8,630.70 MWD+IFR2+HDS+MS(7) 15,159.W 93.74 299.04 4,041.04 3,948.25 2,748.56 8,1%.13 5,983,584.83 557,735.71 7.42 8,612.37 MWD+IFR2+HDS+MS(7) 15,189.W 93.33 298.20 4,039.19 3,946.40 2,762.90 8,159.85 5,983,599.00 557,709.33 3.11 8,593.67 MWD+IFR2+HDS+MS(7) 15,219.W 90.46 297.31 4,038.20 3,945.41 2,776.86 8,133.32 5,983,612.78 557,682.71 10.02 8,574.59 MWD+IFR2+HDS+MS(7) 15,249.06 89.95 296.07 4,W8.09 3,&15.30 2,790.34 8,106.51 5,983,626.08 557,655.82 4.47 8,555.08 MWD+IFR2+HDS+MS(7) 15,279.00 90.83 294.78 4,037.89 3,945.10 2,803.22 8,079.42 5,983,638.78 557,628.65 5.21 8,535.07 MWD+IFR2+HDS+MS(7) 15,306.00 91.96 293.62 4,037.16 3,944.37 2,815.51 8,052.07 5,983,650.89 557,601.22 5.40 8,514.59 MWD+IFR2+HDS+MS(7) 15,339.00 92.74 293.52 4,035.93 3,943.14 2,827.50 8,024.59 5,983,662.69 657,573.67 2.62 8,493.88 MWD+IFR2+HDS+MS(7) 15,369.00 92.73 293.66 4,034.50 3,941.71 2,839.49 7,997.13 5,983,674.50 557,546.13 0.47 8,473.18 MWD+IFR2+HDS+MS (7) 15,399.00 92.52 293.75 4,033.12 3,940.33 2,851.54 7,969.69 5,983,685.36 557,518.61 0.76 B,452.53 MWD+IFR2+HDS+MS (7) 15,429.00 92.28 293.32 4,031.87 3,939.08 2,863.60 7,942.21 5,983598.15 557,491.06 1.64 8,431.81 MWD+IFR2+HDS+MS (7) 15,459.00 91.20 292.75 4,030.96 3,93B.17 2,875.24 7,914.62 5,983,709.70 557,463.39 4.07 8,410.89 MWD+IFR2+HDS+MS(7) 15,489.00 90.74 292.23 4,030.45 3,937.66 2,886.71 7,886.90 5,983,720.99 557,435.60 2.31 8,389.76 MWD+1FR2+HDS+MS(7) 15,519.00 90.39 292.35 4,030.15 3,937.36 2,898.09 7,859.14 5,9B3,732.1B 557,407.77 1.23 8,368.56 MWD+IFR2+HDS+MS(7) 15,549.00 89.68 292.69 4,030.14 3,937.35 2,909.58 7,831.43 5,983,743.49 557,379.99 2.62 8,347.44 MWD+IFR2+HDS+MS(7) 15,579.00 88.79 293.02 4,030.54 3,937.75 2,921.23 7,803.79 5,983,754.95 557,352.27 3.16 B,326.44 MWD+IFR2+HDS+MS(7) 15,609.W 88.54 292.85 4,01.23 3,938.44 2,932.92 7,776.17 5,983,766.46 557,324.58 1.01 8,305.48 MVD+1FR2+HDS+1AS(7) 15,639.00 B9.24 292.48 4,031.82 3,939.03 2,944.48 7,748.49 5,983,777.83 557,296.82 2.64 8,284.42 MWD+IFR2+HDS+MS (7) 15,869.W 89.71 292.12 4,032.09 3,939.30 2,955.86 7,720.74 5,983,789.03 557,269.00 1.97 8,263.22 MWD+IFR2+HDS+MS (7) 15,699.00 89.73 292.21 4,032.24 3,939.45 2,967.18 7,692.95 5,983,800.16 557,241.14 0.31 8,241.97 MWD+IFR2+HD5+MS(7) 15,729.00 90.20 292.49 4,032.26 3,939.47 2,978.59 7,665.21 5,983,811.38 557,213.32 1.82 8,220.79 MWD+IFR2+HDS+MS(7) 15,759.00 90.81 292.76 4,031.99 3,939.20 2,990.13 7,63752 5,983,822.74 557,185.56 2.22 8,199.71 MWD+1FR2+HDS+MS(7) 15,789.00 90.96 293.66 4,031.53 3,938.74 3,001.95 7.609.95 5,983,834.38 557,157.92 3.04 8,178.85 MWD+IFR2+HDS+MS(7) 15,819.00 91.30 294.88 4,030.94 3,938.15 3,014.28 7,582.61 5,983,846.62 557,130.50 4.22 8,158.39 MWD+IFR2+HDS+MS(7) 15,849.W 91.47 2%.06 4,030.21 3,937.42 3,027.18 7,555.53 5,983,859.25 557,103.34 4.07 8,138.41 MVA+IFR2+HDS+MS(7) 15,879.W 91.79 296.96 4,029.36 3,936.57 3,040.57 7,528.70 5,983,872.46 557,076.43 3.09 8,118.84 MND+IFR2+HDS+MS(7) 15,909.00 91.90 297.61 4,028.39 3,935.60 3,054.32 7,502.05 5,983,886.03 557,049.69 2.20 8,099.57 MWD+IFR2+HDS+MS (7) 15,939.W 91.77 298.26 4,027.43 3,934.64 3,068.36 7,475.56 5,9B3,899.90 557,023.11 2.21 8,080.56 MWD+IFR2+HDS+MS (7) 15,954.20 91.71 298.58 4,026.97 3,934.18 3,075.59 7,462.20 5,983,907.4 557,009.70 2.14 8,071.03 MWD+1FR2+HDS+MS(7) 16,014.00 91.71 298.58 4,025.19 3,932.40 3,104.19 7,409.71 5,983,935.28 556,957.03 0.00 8,033.67 PROJECTED to TD 9110/2018 3:00:31PM Page 14 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Project: Kuparuk River Unit ND Reference: Site: Kuparuk 1 H Pad MD Reference: Well: Rig: 1H-104 North Reference: Wellbore: 1H-104 Survey Calculation Method: Design: 11-1-104 Database: Well Rig: IH -104 iH-104 actual @ 92.79usft (Doyon 142) 1 H-104 actual @ 92.79usft (Doyon 142) True Minimum Curvature OAKEDMP2 9/10!2018 3:00:31PM Page 15 COMPASS 5000 14 Build 85 NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H-104PB1 1H-104PB1 ConocoPhillips Definitive Survey Report 12 September, 2018 Final Definitive Survey Verified and Signed -off All targets and/or wek poskion obfectives have been achieved. U Yes Ii No I have checked to the best of my abkky that the foftowing data is correct: J Surface Coordinates ;] Declination & Convergence '.I GRS Surrey Corrections iJ Survey Tool Codes Brandon Temtt-� le Digitally signed by Brandon Temple SLB DE: f•' Date: 2018.10.0810:18:46-08'00' scott.a.brunswick@conocophillipsgrk" '•;=%+ "" Client Representative: rnm Date: X.VIII.MNVVIII ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Project: Kupamk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: 1 H-104 actual @ 92.7gusft (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: 1H-104PBI Survey Calculation Method: Minimum Curvature Design: 1H -104P61 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Rig: 1H-104 Audit Notes: To Well Position +NIS 0.00 usft Northing: 5,980,782.43 usft Latitude: 70° 21' 29.809 N 38.69 +E/ -W 0.00 usft Easting: 549,568.74 usft Longitude: 149° 35. 50.655 W Position Uncertainty (usR) 0.00 usft Wellhead Elevation: usft Ground Level: 54.10 usft Wellbore 1H-104PBI Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) r) (nn BGGM2018 8/15/2018 17.04 80.91 57,448 Design 1H-104PB1 Data Audit Notes: To Version: 1.0 Phase: ACTUAL Tee On Depth: 38.69 Vertical Section: Depth From (TVD) +NIS +E/4M Direction 1,194.67 (usft) (usR) (usft) (1) 1,901.24 38.69 0.00 0.00 350.00 Survey Program Data From To (uefq (ueR) Survey (WWNbore) Tool Name Description Survey Date 130.47 1,098.56 1 H-104 Srvy 1 - SLB_GWD70 It H-104PB GYD-GCSS Gymdata gyro single shots 8/6/2018 10:47:[ 1,194.67 1,804.101H-104Srvy2-SLB_MWD+GMAG(i H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/6/201810:55:[ 1,901.24 1,901.241H-104Srvy3-SLB_MWD-INC-ONLY_F MWD -INC ONLY MWD4NC_ONLY_FILLER 8/9/201810:05:( 1,977.75 9,446.781H-104 Srvy 4-SLBDUAL+GMAG+SA MWD+IFR2+HDS+MS OWSG MWD + IFR2 + HDS + Multi -Station Corre8/9/201810:071 9,484.37 9,484.371H-104 Srvy 5- SLB _MWD_INC-Only-Fi MWD -INC ONLY MWD -INC -ONLY -FILLER 8/16/2018 10:07 9,579.45 11,166.71 IH-104PBI Srvy6-DUAL+GMAG+SAG MWD+IFR2+HDS+MS OWSG MWD + IFR2 + HDS + Multi -Station Correc8/16/201810:07 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI4N Northing Easting DLS Section (-R) r) r) (usft) (usft) (usft) lust) (try (ft) (°/100-) (ft) Survey Tool Name 38.69 0.00 0.00 38.69 54.10 0.00 0.00 5,980,782.43 549,568.74 0.00 0.00 UNDEFINED 130.47 0.03 108.52 130.47 37.68 -0.01 0.02 5,980,782.42 549,568.76 0.03 -0.01 GYD-GCSS(1) 170.09 0.12 87.41 170.09 77.30 -0.01 0.07 5,980,782.42 549,568.81 0.23 -0.02 GYD-GCSS(1) 259.84 2.03 116.87 259.82 167.03 -0.72 1.59 5,980,781.72 649,570.33 2.15 -0.99 GYD-GCSS(1) 357.41 4.01 124.19 357.25 264.46 -3.42 5.95 5,980,779.05 549,574.71 2.06 -0.40 GYD-GCSS(1) 499.01 5.79 114.28 448.51 355.72 -7.12 12.81 5,980,775.39 549,581.60 2.14 5.24 GYD-GCSS (1) 540.15 6.91 118.50 539.09 446.30 -11.63 21.82 5,980,770.95 549,590.64 1.33 -15.24 GYD-GCSS (1) 631.94 8.38 116.35 630.06 537.27 -17.23 32.67 5,980,765.42 549,601.52 1.63 -22.64 GYD-GCSS(1) 722.47 10.68 118.44 719.34 626.55 -24.16 45.96 5,980,758.58 549,614.85 2.57 J1.77 GYD-GCSS (1) 813.86 12.56 116.31 808.85 716.06 52.60 62.31 5,980,750.25 549,631.26 2.11 42.92 GYD-GCSS(1) 9/12/2018 7:06:27AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Project: Kupamk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Well: Rig: 11-1-104 North Reference: True Wellbore: 1H-104PBI Survey Calculation Method: Minimum Curvature Design: 1H-104PBI Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +WS +E1 -W Northing Pasting DLS Section (usft) V) (1) (usfo Wait) WI) (usft) (fl) (ft) (.1100') (1t) Survey Tool Name 99.29 15.48 116.02 901.43 808.64 42.78 83.06 5,980,740.20 549,652.07 3.06 56.56 GYD-GCSS (1) 1,003.79 16.85 113.72 992.19 899.40 53.83 106.94 5,980,729.32 549,676.02 1.60 -71.58 GYD-GCSS (1) 1,098.55 18.48 111.78 1,082.49 989.70 84.93 133.46 5,980,718.39 549,702.61 1.83 -87.11 GYD-GCSS (1) 1,194.67 20.89 113.70 1,172.98 1,080.19 -77.47 163.30 5,980,706.05 549,732.53 2.60 -104.65 MWD+IFR-AK-CAZ-SC(2) 1,234.61 22.13 113.61 1,210.14 1,117.35 -83.34 176.71 5,980,700.27 549,745.98 3.11 -112.76 MWDAFR-AK-CAZ-SC(2) 1,329.20 25.32 113.89 1,296.72 1,203.93 08.67 211.54 5,98,685.17 549,780.91 3.37 -133.91 MM+IFR-AK-CAZ-SC (2) 1,421.11 29.49 113.16 1,378.30 1,285.51 -115.54 250.33 5,980,668.56 549,819.80 4.55 -157.25 MWD+IFR-AK-CAZ-SC (2) 1,517.95 33.20 112.62 1,460.99 1,368.20 -135.12 2%.73 5,980,649.29 549,866.33 3.84 -184.59 MWD+IFR-AK-CAZ-SC (2) 1,613.27 33.72 113.53 1,540.51 1,447.72 -155.72 345.06 5,98,629.01 549,914.81 0.76 -213.27 MWD+IFR-AK-CAZ-SC (2) 1,708.42 33.08 113.61 1,619.95 1,527.16 -176.65 393.09 5,980,69.39 549962.95 0.67 -242.24 MWD+IFR-AK-CAZ-SC (2) 1,804.10 33.67 115.86 1,699.85 1,607.% -198.69 440.86 5,98,586.68 550,010.89 1.43 -272.23 MWD+IFR-AK-CA7-SC (2) 1,901.24 37.21 118.00 1,778.99 1,686.20 -224.23 491.07 5,980,561.47 550,061.23 3.86 -306.10 MWD4NC ONLY(3) 1,977.75 39.23 117.71 1,839.09 1,746.30 -246.35 532.92 5,980,539.64 550,103.22 2.65 535.14 MWD+IFR2+HDS+MS(4) 2,007.% 40.35 117.25 1,861.57 1,768.78 -254.98 549.52 5,980,531.11 550,119.89 3.96 -346.53 MWD+IFR2+HDS+MS(4) 2,037.00 41.52 116.92 1,884.23 1,791.44 -263.93 567.02 5,980,522.28 550,137.44 3.97 358.38 MWD+IFR2+HDS+MS(4) 2,067.0 42.58 116.71 1,906.51 1,813.72 -273.00 584.96 5,980,513.34 550,155.43 3.56 -370.42 MWD+IFR2+HDS+MS(4) 2,097.9 43.63 116.51 1,928.41 1,835.62 -282.18 603.29 5,980,504.28 550,173.82 3.53 582.65 MWD+IFR2+HDS+MS(4) 2,127.9 44.75 116.43 1,949.92 1,857.13 -291.50 622.00 5,98,495.08 550,192.60 3.74 -395.08 MWD+IFR2+HDS+MS(4) 2,157.9 45.87 116.47 1,971.02 1,878.23 -301.9 641.10 5,980,485.71 550,211.75 3.73 -407.75 MWD+IFR2+HDS+MS(4) 2,187.9 47.% 116.52 1,991.68 1,898.89 310.70 660.57 5,980,476.14 550,231.28 4.04 420.69 MWD+IFR2+HDS+MS (4) 2,217.9 48.40 116.44 2,011.85 1,919.% 320.60 680.44 5,98,466.37 550,251.22 4.40 -433.89 MWD+IFR2+HDS+MS (4) 2,247.00 49.68 116.16 2,031.52 1,938.73 330.64 79.75 5,980,456.47 550,271.59 4.32 -447.30 MIND+IFR2+HDS+MS (4) 2,277.00 50.84 115.84 2,050.70 1,957.91 -340.75 721.48 5,980,446.50 550,292.39 3.95 -460.86 MWD+IFR2+HDS+MS (4) 2,307.00 51.95 115.63 2,%9.42 1,976.63 350.93 742.60 5,980,436.46 550,313.58 3.74 474.55 MWD+IFR2+HDS+MS (4) 2,337.9 53.10 115.68 2,087.67 1,994.88 561.24 764.% 5,980,426.29 550,335.10 3.84 488.43 MWD+IFR2+HDS+MS (4) 2,367.9 54.38 115.81 2,105.41 2,012.62 371.74 785.85 5,980,415.93 550,355.% 4.28 802.56 MWD+IFR2+HDS+MS(4) 2,397.9 55.64 115.93 2,122.61 2,029.82 -382.47 807.96 5,980,405.35 550,379.14 4.21 516.96 MWD+IFR2+HDS+MS (4) 2,427.9 56.61 116.02 2,139.34 2,046.55 393.38 830.36 5,980,394.59 550,401.60 3.24 531.59 MWD+IFR2+HDS+MS(4) 2,457.9 57.38 116.10 2,155.68 2,062.89 404.43 852.96 5,980,383.69 550,424.27 2.58 -546.40 MWD+IFR2+HDS+MS(4) 2,48].00 58.37 116.14 2,171.63 2,078.84 415.61 875.77 5,980,372.66 550,447.15 3.30 561.38 MWD+IFR2+HDS+MS (4) 2,517.9 59.50 115.95 2,187.11 2,094.32 426.90 B98.66 5,980,361.53 550,470.31 3.81 -576.50 MWD+IFR2+HDS+MS(4) 2,54].00 60.42 115.63 2,202.13 2,19.34 -438.20 922.24 5,980,350.39 55,493.77 3.20 591.68 MWD+IFR2+HDS+MS(4) 2,57700 61.29 115.29 2,216.74 2,123.95 449.46 945.90 5,980,339.28 55,517.50 3.06 S06.88 MWD+IFR2+HDS+MS(4) 2,607.00 62.12 114.85 2,230.% 2,138.17 -460.65 969.82 5,980,328.25 550541.50 3.05 822.06 MWD+IFR2+HDS+MS(4) 2,637.9 63.06 114.32 2,244.77 2,151.98 471.73 994.04 5,980,317.33 560,665.78 3.50 537.18 MWD+IFR2+HDS+MS(4) 2,657.9 64.06 113.78 2,258.13 2,165.34 482.68 1,018.57 5,980,30&55 550,590.38 3.70 552.22 MWD+IFR2+HDS+MS(4) 2,697.00 65.08 113.33 2,271.01 2,178.22 493.50 1,043.41 5,980,295.89 550,615.29 3.66 867.19 MWD+IFR2+HDS+MS(4) 2,727.00 65.25 112.97 2,283.37 2,190.58 804.25 1,068.54 5,980,285.31 550,640.49 4.05 882.14 MWD+IFR2+HDS+MS(4) 2,757.9 67.57 112.62 2,295.14 2,202.35 814.94 1,093.98 5,980,274.79 550,666.00 4.53 597.09 MWD+IFR2+HDS+MS (4) 2,787.00 68.78 112.39 2,306.29 2,213.50 525.60 1,119.71 5,980,264.30 55091.79 4.10 -712.05 MWD+IFR2+HDS+MS (4) 9/12/2016 7:06:27AM Page 3 COMPASS 5000.14 Build 85 Survey ConocoPhillips Definitive Survey Report Map Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Project: Kuparuk River Unit TVD Reference: 1H-104 actual (off 92.79usR (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-104 actual @ 92.79us0 (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: 1H-104PB1 Survey Calculation Method: Minimum Curvature Design: 1H-104PB1 Database: OAKEDMP2 Survey 9/1272018 7:05:27AM Page 4 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc AN TVD TVDSS •1117-3 •E1 -W Northing Easting DLS Section (usft) (1) (1) (-R) (usft) (usft) (usft) (ft) Ito (°71001 (ft) Survey Tool Name 2,817.00 69.85 11235 2,316.89 2,224.10 536.28 1,145.66 5,980,253.79 550,717.81 3.57 -72708 MWD+IFR2+HDS+MS(4) 2,847.00 70.90 112.35 2,326.96 2,234.17 -547.03 1,171.80 5,980,243.22 550,744.02 3.50 -742.20 MWD+IFR2+HDS+MS(4) 2,677.00 71.12 112.39 2,336.72 2,243.93 557.82 1,198.03 5,980,232.60 550,77D.32 0.74 -757.36 MWD+IFR2+HDS+MS(4) 2,907.00 70.87 112.56 2,346.49 2,253.70 568.67 1,224.24 5,980,221.93 550,796.60 0.99 -772.61 MWD+IFR2+HDS+MS(4) 2,937.00 70.73 112.76 2,356.36 2,263.57 579.58 1,250.38 6,980,211.19 550,822.81 0.78 -787.90 MWD+IFR2+HDS+MS(4) 2,967.00 71.42 112.94 2,366.09 2,27330 590.60 1,276.54 5,980,200.35 550,849.03 2.37 -803.30 MWD+IFR2+HDS+MS(4) 2,997.00 72.16 113.02 2,375.46 2,282.67 {01.73 1,302.77 5,980,189.40 550,875.34 2.48 -8111.81 MWD+IFR2+HDS+MS(4) 3,027.00 72.76 11306 2,384.50 2,291.71 612.92 1,329.09 5,980,178.38 550,901.73 2.00 -834.41 MWD+IFR2+HDS+MS(4) 3,057.00 73.19 113.13 2,393.29 2,300.50 524.17 1,355.48 5,980,167.30 550,928.19 1.45 -850.07 MWD+1FR2+HDS+MS(4) 3,08200 73.23 113.36 2,401.95 2,309.16 -635.51 1,381.87 5,980,155.14 550,954.65 0.75 -86681 MWD+IFR2+HDS+MS(4) 3,117.00 73.26 113.71 2,410.60 2,317.81 546.98 1,408.21 5,980,144.85 550981.06 1.12 -881.68 MWD+IFR2+HDS+MS(4) 3,147.00 73.72 114.04 2,419.13 2,326.34 558.62 1,434.51 5,980,133.38 551,007.44 1.86 -897.72 MWD+IFR2+HDS+MS(4) 3,177.00 74.22 114.10 2,427.41 2,334.62 .870.38 1,460.83 5,980,121.79 551,033.84 1.68 -913.87 MWD+IFR2+HDS+MS(4) 3,20700 74.27 113.93 2,435.56 2,342.77 -682.13 1,487.21 5,9,110.22 551,60.29 0.57 -830.02 MWD+IFR2+HDS+MS(4) 3,237.00 74.45 113.75 2,443.65 2,350.86 -693.81 1,513.63 5,980,098.72 551,086.78 0.83 -946.11 MWD+IFR2+HDS+MS(4) 3,26700 74.41 113.51 2,451.70 2,358.91 -705.39 1,540.11 5,980,087.31 551,113.33 0.78 -962.11 MWD+IFR2+HDS+MS(4) 3,297.00 74.24 113.22 2,459.80 2,367.01 -716.85 1,566.62 5,980,076.03 551,139.92 1.09 4178.00 MWD+IFR2+HDS+MS(4) 3,327.00 74.32 112.91 2,467.93 2,375.14 -728.16 1,593.19 5,980,064.90 551,166.56 1.03 -993.75 MWD+IFR2+HDS+MS(4) 3,357.00 74.22 112.61 2,476.06 2,383.27 -739.33 1,619.82 5,98,053.90 551,193.26 1.02 -1,009.38 MND+IFR2+HDS+MS (4) 3,387.00 74.13 112.34 2,484.25 2,391.46 -750.37 1,646.49 5,980,043.05 551,220.00 0.92 -1,024.88 MND+IFR2+HDS+MS (4) 3,417.00 74.29 112.D6 2,492.41 2,399.62 -761.27 1,673.22 5,98,032.32 551,246.80 1.04 -1,040.26 MWD+IFR2+HDS+MS(4) 3,447.00 74.40 111.80 2,500.50 2,407.71 -772.06 1,700.02 5,980,021.71 551,273.65 0.91 -1,055.54 MND+IFR2+HDS+MS (4) 3,477.00 74.33 111.56 2,508.59 2,415.80 -782.73 1,725.85 5,980,011.22 551,300.58 0.80 -1,070.71 MWD+IFR2+HDS+MS(4) 3,507.00 74.20 111.34 2,516.73 2,423.94 -793.29 1,753.74 5,980,000.83 551,327.52 0.83 -1,085.78 MWD+IFR2+HDS+MS(4) 3,637.00 73.93 111.12 2,524.96 2,432.17 -803.74 1,780.63 5,979,990.57 551,354.48 1.14 -1,100.73 MWD+IFR2+HDS+MS(4) 3,567.00 73.69 110.92 2,533.33 2,440.54 -814.07 1,807.52 5,979,980.41 551,381.43 1.02 -1,115.58 MWD+IFR2+HDS+MS(4) 3,597.00 7376 110.74 2,541.73 2,448.94 4124.31 1,834.44 5,979,970.35 551,408.41 0.62 -1,130.34 MWD+IFR2+HDS+MS(4) 3,627.00 73.77 110.57 2,550.12 2,457.33 -834.48 1,861.39 5,979,960.37 551,435.43 0.55 -1,145.02 MND+IFR2+HDS+MS (4) 3,657.00 73.86 110.48 2,558.48 2,465.69 -844.58 1,888.37 5,979,950.45 551,462.48 0.42 -1,159.65 MWD+IFR2+HDS+MS (4) 3,687.00 73.77 110.44 2,566.85 2,474,6 -854.65 1,915.37 5,979,940.56 551,489.53 0.33 -1,174.26 MWD+IFR2+HDS+MS(4) 3,717.00 73.67 110.40 2,575.26 2,482.47 -864.70 1,942.35 5,979,930.69 551,516.58 0.36 -1,188.84 MWD+IFR2+HDS+MS(4) 3,747.00 73.89 110.46 2,563.64 2,490.85 4174.75 1,969.35 5,979,920.82 551,543.64 0.76 -1,203.43 MWD+IFR2+HDS+M$(4) 3,777.00 73.58 110.60 2,592.04 2,499.25 -884.85 1,996.32 5,979,910.90 551,570.67 1.13 -1,218.06 MND+IFR2+HDS+MS (4) 3,807.00 73.22 110.74 2.600.61 2,507.82 .895.00 2,023.22 5,979,900.93 551,597.64 1.28 -1,232.73 MND+IFR2+HDS+MS (4) 3,837.00 73.72 110.88 2,609.14 2,516.35 -905.22 2,050.10 5,979,890.89 551,624.59 1.73 -1,247.46 MWD+IFR2+HDS+MS (4) 3,867.00 73.59 111.00 2,617.59 2,524.80 .915.50 2,076.99 5,979,880.78 551,651.54 0.S8 -1,262.26 MWD+IFR2+HDS+MS(4) 3,897.00 73.33 111.13 2,626.13 2,533.34 -925.84 2,103.82 5,979,870.62 551,678.44 0.96 -1,277.10 MWD+IFR2+HDS+MS(4) 3,927.00 73.55 111.24 2,634.68 2,541.89 -836.23 2.130.63 5,979,860.41 551,705.32 0.81 -1,291.99 MWD+IFR2+HDS+MS(4) 3,957.00 73.44 111.35 2,643.20 2,550.41 .946.68 2,157.43 5,979,850.14 551,732.18 0.51 -1,306.93 MWD+IFR2+HDS+MS(4) 3,98].00 73.38 111.45 2,651.77 2,558.98 -957.17 2,184.20 5,979,839.83 551,759.02 0.38 -1,321.91 MWD+IFR2+HDS+MS(4) 9/1272018 7:05:27AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1H-104 Pmjsck Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H-104 actual @ 92.7gusft (Doyon 142) WON: Rig: 1H-104 North Reference: True Wellbore: 1H -104P81 Survey Calculation Method: Minimum Curvature Design: 1 H-104PB1 Database: OAKEDMP2 Survey 9112/2018 7:06:27AM Page 5 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Arl TVD TVDSS +W.S +E/ -W Northing Eastlng DLS Section (usR) (') C) (usf) (usR) (usR) Will) (ft) Ift) (./100') (ft) Survey Tool Name 4,017.00 73.38 111.51 2,660.35 2,567.56 -967.70 2,210.95 5,979,829.46 551,785.83 0.19 -1,335.92 MWD+IFR2+HDS+MS(4) 4,047.00 73.44 111.43 2,668.91 2,576.12 -978.22 2,237.71 5,979,819.14 551,812.66 0.32 -1,351.93 MWD+IFR2+HDS+MS(4) 4,077.00 73.29 111.32 2,677.50 2,584.71 -988.70 2,264.48 5,979,808.84 551,839.49 0.61 -1,366.90 MWD+IFR2+HDS+MS (4) 4,107.00 73.46 111.22 2,686.08 2,593.29 -999.12 2,291.26 5,979,798.59 551,866.34 0.65 -1,381.82 MWD+IFR2+HDS+MS(4) 4,137.00 73.64 111.16 2,694.58 2,601.79 -1,009.52 2,318.09 5,979,788.37 551,893.24 0.63 -1,396.72 MND+IFR2+HDS+MS(4) 4,167.00 73.40 111.13 2,703.09 2,610.30 -1,019.90 2,344.92 5,979,778.17 551,920.13 0.81 -1,411.60 MWD+IFR2+HDS+MS(4) 4,197.00 73.50 111.07 2,711.64 2,618.85 -1,030.25 2,371.75 5,979,767.99 551,947.03 0.38 -1,426.45 MND+IFR2+140S+105(4) 4,227.00 73.61 110.94 2,720.13 2,627.34 -1,040.57 2,398.61 5,979,757.86 551,973.95 0.55 -1,441.27 MND+IFR2+HDS+MS(4) 4,257.00 73.43 110.75 2,728.64 2,635.85 -1,050.80 2,425.50 5,979,747.80 552,000.90 0.85 -1,456.02 MWD+IFR2+HDS+MS(4) 4,287.00 73.30 110.56 2,737.23 2,644.44 -1,060.94 2,452.39 5,979,737.84 552,027.86 0.75 -1,470.68 MND+IFR2+HDS+MS(4) 4,317.00 73.34 110.39 2,745.84 2,653.05 -1,071.00 2,479.32 5,979,727.97 552,054.85 0.56 -1,485.25 MND+IFR2+MDS+MS (4) 4,347.00 73.38 110.23 2,754.43 2,661.64 -1,080.97 2,506.27 5,979,718.17 552,081.87 0.53 -1,499.76 MV4D+IFR2+HDS+MS (4) 4,377+0 73.48 110.07 2,762.98 2,670.19 -1,090.88 2,533.27 5,979,708.45 552,108.92 0.61 -1,514.20 MVD+IFR2+HDS+MS(4) 4,407.00 73.40 110.10 2,771.53 2.670.74 -1,100.75 2,560.27 5,97908.75 552,135.99 0.28 -1,528.62 MWD+IFR2+HDS+MS(4) 4,437.00 73.36 110.34 2,780.12 2,687.33 -1,110.69 2,587.25 5,979,688.99 552,163.03 0.78 -1,543.08 MWD+IFR2+HDS+MS(4) 4,467.00 73.15 110.60 2,788.76 2,695.97 -1,120.73 2,614.16 5,979,679.13 552,190.01 1.09 -1,557.65 MWD+IFR2+HDS+MS(4) 4,497.00 73.16 110.83 2,797.45 2,704.66 -1,130.89 2,641.02 5,979,669.15 552,216.93 0.73 -1,572.32 MWD+IFR2+HDS+MS(4) 4,527.00 73.31 111.00 2,806.11 2,713.32 -1,141.14 2,667.85 5,979,659.07 552,243.82 0.74 -1,587.08 MWD+IFR2+HDS+MS(4) 4,557.00 73.32 111.16 2,814.72 2,721.93 -1,151.46 2,694.66 5,979,648.92 552,270.70 0.51 -1,601.91 MWD+IFR2+HDS+MS(4) 4,587.00 73.28 111.36 2,823.34 2,730.55 -1,161.90 2,721.4 5,979,638.68 552,297.55 0.65 -1,616.82 MWD+IFR2+HDS+MS(4) 4,617.00 73.39 111.62 2,831.94 2,739.15 -1,172.43 2,748.19 5,979,628.33 552,324.36 0.91 -1,631.83 MWD+IFR2+HDS+MS(4) 4,647.00 73..16 111.91 2,840.50 2,747.71 -1,183.09 2,774.89 5,979,617.84 552,351.13 0.96 -1,646.97 MWD+IFR2+HDS+MS (4) 4,677.00 73.31 112.19 2,849.08 2,756.29 -1,193.88 2,801.53 5,979,607.23 552,377.84 1.02 -1552.23 MWD+IFR2+HDS+MS (4) 4,707.00 73.35 112.45 2,857.69 2,764.90 -1,204.80 2,828.12 5,979,596.49 552,404.50 0.84 -1,677.59 MWD+IFR2+HDS+MS(4) 4,737.00 73.29 112.71 2,866.30 2,773.51 -1,215.83 2,854.65 5,979,585.63 552.31.10 0.85 -1,693.07 MVD+IFR2+HDS+MS (4) 4,767.00 73.33 112.96 2,874.91 2,782.12 -1,226.98 2,881.14 5,979,574.66 552,457.65 0.81 -1,708.65 MWD+IFR2+HDS+MS (4) 4,797.00 73.32 113.14 2,883.52 2,790.73 -1,238.24 2,907.58 5,979,563.58 552,484.17 0.58 -1,724.32 MWD+IFR2+HDS+MS(4) 4,827.00 73.33 113.28 2,892.13 2,799.34 -1,249.56 2,934.00 5,979,552.43 552,510.65 0.45 -1,740.06 MW3+IFR2+HDS+MS(4) 4,857.00 73.26 113.40 2,900.75 2,807.96 -1,260.95 2,960.38 5,979,541.22 552,537.11 0.45 -1,755.85 MND+IFR2+HDS+MS(4) 4,887.00 73.23 113.39 2,909.40 2,816.61 -1,272.35 2,986.74 5,979,529.99 552,563.55 0.10 -1,771.66 MND+IFR2+HDS+MS (4) 4,917.00 73.23 113.26 2,918.06 2,825.27 -1,263.72 3,013.12 5,979,518.80 552,590.00 0.41 -1,787.44 MWD+IFR2+HDS+MS(4) 4,947.00 73.08 113.12 2,926.75 2,833.96 -1,295.03 3,039.51 5,979,507.67 552,616.46 0.67 -1,803.16 MWD+IFR2+HDS+MS(4) 4,977.00 73.13 113.01 2,935.47 2,842.68 -1,306.28 3,065.92 5,979,496.60 552,642.94 0.39 -1,818.82 MWD+IFR2+HDS+MS(4) 5,007.00 73.36 112.94 2,944.12 2,851.33 -1,317.49 3,092.37 5,979,485.56 552,659.46 0.80 -1,834.46 MWD+IFR2+HDS+MS(4) 5,037.00 73.47 112.87 2,952.68 2,859.89 -1,328.68 3,118.86 5,979,474.55 552,696.02 0.43 -1,850.08 MWD+IFR2+HDS+MS(4) 5,067+0 73.63 112.70 2,961.17 2,868.38 -1,339.82 3,145.38 5,979,463.58 552,722.61 0.76 -1,865.66 MV4D+IFR2+HDS+MS(4) 5,097.00 73.67 112.35 2,969.62 2,876.83 -1,350.85 3,171.97 5,979,452.73 552,749.27 1.13 -1,881.14 MWD+IFR2+HDS+MS(4) 5,127.00 73.61 111.98 2,978.07 2,885.28 -1,361.71 3,198.63 5,979,442.05 552,776.00 1.20 -1,896.46 MWD+IFR2+HDS+MS(4) 5,157.00 73.70 111.71 2,986.51 2,893.72 -1,372.42 3,225.35 5,979,431.51 652,802.79 0.91 -1,911.65 MWD+IFR2+HDS+MS(4) 5,187.00 73.65 111.73 2,994.95 2,902.16 -1,383.08 3,252.10 5,979,421.04 552,829.60 0.18 -1,926.79 MWD+IFR2+HDS+MS(4) 9112/2018 7:06:27AM Page 5 COMPASS 5000.14 Build 85 ConocoPhiilips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 11-1-104 Project: Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79us0 (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 11-1-104 actual @ 92.79usR (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: IH-104PB1 Survey Calculation Method: Minimum Curvature Design: IH-104PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TvDSS +N/S +E1 -W Northing Easting DLS Section (waft) (1) (1) (Mft) (usR) (Mft) (MR) (R) (ft) (•1100-) (ft) Survey Tool Name 5,217.00 73.57 111.84 3,003.41 2,910.62 -1,393.76 3,278.82 5,979,410.53 552,856.40 0.44 -1,941.95 MWD+IFR2+HDS+MS(4) 5,247.00 73.62 111.97 3,011.68 2,919.09 -1,404.49 3,305.52 5,979,399.98 552,883.16 0.45 -1,957.16 MWD+IFR2+HDS+MS (4) 5,277.00 73.66 112.22 3,020.33 2,927.54 -1,415.32 3,332.20 5,979,389.33 552,909.90 0.81 -1,972.45 MWD+IFR2+HDS+MS(4) 5,307.00 73.70 112.52 3,028.76 2,935.97 -1,426.28 3,358.82 5,979,378.55 552,936.60 0.97 -1,987.86 MWD+IFR2+HDS+MS(4) 5,337.00 73.62 112.80 3,037.20 2,944.41 -1,437.37 3,385.39 5,979,367.63 552,963.23 0.93 -2,03.40 MWD+IFR2+HDS+MS (4) 5,367.0 73.58 112.0 3,045.67 2,952.88 -1,448.55 3,411.91 5,979,356.63 552,989.83 0.35 -2,019.01 MWD+IFR2+HDS+MS(4) 5,397.0 73.67 112.87 3,054.13 2,961.34 -1,459]4 3,438.42 5,979,345.62 553,016.41 0.31 -2,034.64 MWD+IFR2+HDS+MS(4) 5,427.0 73.71 112.86 3,062.56 2,969.77 -1,470.93 3,464.95 5,979,334.61 553,043.02 0.14 -2,050.26 MWD+IFR2+HDS+MS(4) 5,457.0 73.77 112.99 3,070.96 2,978.17 -1,482.15 3,491.8 5,979,323.56 553,069.61 0.4fi -2,065.92 MWD+IFR2+HDS+MS(4) 5,487.00 73.86 113.23 3,079.32 2,986.53 -1,40.45 3,517.98 5,979,312.43 553,096.18 0.82 4.081.66 MWD+IFR2+HDS+MS(4) 5,517.0 73.71 113.48 3,087.70 2,994.91 -1,504.87 3,544.43 5,979,301.19 553,122.70 0.94 -2,097.49 MWD+IFR2+HDS+MS(4) 5,547.0 73.70 113.64 3,096.11 3,03.32 -1,516.38 3,570.82 5,979,289.86 553,149.17 0.51 -2,113.41 MWD+IFR2+HDS+MS(4) 5,577.0 73.63 113.67 3,104.55 3,011.76 -1,527.93 3,597.19 5,979,278.48 553,175.61 0.25 -2,129.37 MWD+IFR2+HDS+MS(4) 5,607.0 73.62 113.69 3,113.01 3,020.22 -1,539.49 3,623.55 5,979,267.10 553,202.05 0.07 -2,145.33 MWD+IFR2+MDS+MS(4) 5,637.0 73.73 113.82 3,121.4 3,028.65 -1,551.09 3,649.90 5,979,255.67 553,228.47 0.55 -2,161.33 MWD+IFR2+HDS+MS(4) 5,667.0 73.82 114.13 3,129.82 3,037.0 -1,562.80 3,676.22 5,979,244.15 553,254.86 1.04 -2,177.42 MWD+IFR2+HDS+MS(4) 5,697.0 73.79 114.48 3,138.19 3,045.40 -1,574.65 3,702.48 5,979,232.46 553,281.20 1.12 -2,193.66 MWD+IFR2+HDS+MS(4) 5,727.0 73.78 114.83 3,146.57 3,053.78 -1,586.67 3,728.66 5,979,220.62 553,307.45 1.12 -2,210.04 MND+IFR2+HDS+MS(4) 5,757.0 73.82 115.15 3,154.94 3,062.15 -1,598.84 3,754.77 5,979,208.62 553,333.64 1.03 -2,226.56 MWD+IFR2+HDS+MS(4) 5,787.0 73.84 115.46 3,163.29 3,070.0 -1,611.16 3,780.82 5,979,196.48 553,359.77 0.99 -2,243.21 MWD+IFR2+HDS+MS(4) 5,817.0 73.89 115.74 3,171.63 3,078.84 -1,623.61 3,806.81 5,979,184.20 553,385.84 0.91 -2,259.99 MWD+IFR2+HDS+MS (4) 5,847.0 73.90 115.90 3,179.95 3,087.16 -1,636.16 3,832.75 5,979,171.82 553,411.86 0.51 -2,276.86 MWD+IFR2+HDS+MS(4) 5,877.00 73.69 115.99 3,188.32 3,095.53 -1,648.77 3,858.66 5,979,159.39 553,437.85 0.76 -2,20.77 MWD+IFR2+HDS+MS(4) 5,907.00 73.80 116.07 3,196.72 3,103.93 -1,661.41 3,884.54 5,979,146.93 553,463.81 0.45 -2,310.71 MWD+IFR2+HDS+MS(4) 5,937.0 73.68 116.0 3,205.07 3,112.28 -1,674.07 3,910.42 5,979,134.44 553,489]7 0.27 -2,327.67 MWD+IFR2+HDS+MS(4) 5,967.00 73.95 115.97 3,213.38 3,120.59 -1,686.71 3,936.33 5,979,121.97 553,515.76 0.39 -2,344.62 MWD+IFR2+HDS+MS(4) 5,997.00 73.82 115.88 3,221.70 3,128.91 -1,699.31 3,962.25 5,979,109.54 553,541.76 0.55 -2,361.53 MWD+IFR2+HDS+MS(4) 6,027.0 73.67 115.68 3,230.10 3,137.31 -1,711.84 3,988.18 5,979,07.19 553,567.77 0.81 -2,378.37 MWD+IFR2+HDS+MS(4) 6,057.0 73.44 115.36 3,238.60 3,145.81 -1,724.23 4,014.15 5,979,084.96 553,593.82 1.28 -2,395.0 MWD+IFR2+HDS+MS(4) 6,087.00 73.19 115.4 3,247.21 3,154.42 -1,736.47 4,040.15 5,979,072.90 553,619.90 1.32 -2,411.65 MWD+IFR2+HDS+MS(4) 6,117.0 73.23 114.70 3,255.87 3,163.08 -1,748.55 4,066.21 5,979,01.0 553,646.03 1.09 -2,42807 MWD+IFR2+HDS+MS (4) 6,147.0 73.45 114.35 3,264.48 3,171.69 -1,70.48 4,092.35 5,979,049.24 553,672.26 1.34 -2,444.35 MWD+IFR2+HDS+MS(4) 6,177.00 73.40 113.99 3,273.03 3,180.24 -1,772.25 4,118.59 5,979,037.64 553,698.56 1.16 -2,460.51 MWD+IFR2+HDS+MS(4) 6,207.0 73.38 113.64 3,281.61 3,188.82 -1,783.86 4,144.89 5,979,026.21 553,724.94 1.12 -2,476.51 MWD+IFR2+HDS+MS(4) 6,237.0 73.48 113.30 3,290.16 3,197.37 -1,795.31 4,171.26 5,979,014.94 553,751.38 1.14 -2,492.37 MWD+IFR2+HDS+MS(4) 6,267.0 73.36 112.96 3,298.73 3,205.94 -1,80.60 4,197.70 5,979,003.82 553,777.90 1.16 -2,508.08 MWD+IFR2+HDS+MS(4) 6,297.0 73.24 112.60 3,307.35 3,214.56 -1,817.73 4,224.20 5,978,992.87 553,804.46 1.22 -2,523.64 MWD+IFR2+HDS+MS(4) 6,327.0 73.34 112.17 3,315.97 3,223.18 -1,828.67 4,250.76 5,978,982.10 553,831.10 1.41 -2,539.0 MWD+IFR2+HDS+MS(4) 6,357.0 73.44 111.72 3,324.55 3,231.76 -1,839.42 4,277.43 5,978,971.54 553,857.83 1.48 -2,554.24 MWD+IFR2+HDS+MS(4) 6,387.00 73.36 111.33 3,333.12 3,240.33 -1,849.97 4,300.17 5,978,961.17 553,88464 1.27 -2,569.27 MWD+IFR2+HDS+MS(4) 9/122018 706:27AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1 H-104 Project: Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Well: Rig: 1H-104 North Reference: True Wellbore: 1H-104PB7 Survey Calculation Method: Minimum Curvature Design: 1 H-104PB1 Database: OAKEDMP2 Survey 9/122018 7:06:27AM Page 7 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Asi TVD TVDSS +W.S +E/ -W Northing Easting DLS Section (usR) (1) 0 (usfq (Wft) (usR) (usN) (R) (ft) (°11001 (R) Survey Tool Name 6,417.00 73.27 111.27 3,341.73 3,248.94 -1,860.40 4,330.95 5,978,950.91 553,911.48 0.36 -2,584.20 MV+D+IFR2+HDS+MS (4) 6,447.00 73.44 111.41 3,350.32 3,257.53 -1,870.85 4,357.72 5,978,940.63 553,938.32 0.72 -2,599.15 MWD+IFR2+HDS+MS(4) 6,477.0 73.38 111.55 3,358.89 3,266.10 -1,881.39 4,384.47 5,978,930.28 553,965.14 0.49 -2,614.16 MWD+IFR2+HDS+MS (4) 6,507.00 73.42 111.56 3,367.46 3,274.67 -1,891.95 4,411.21 5,978,919.89 553,991.95 0.14 -2,629.21 MWD+IFR2+HDS+MS(4) 6,537.00 73.47 111.48 3,376.01 3,283.22 -1,902.50 4,437.97 5,978,909.52 554,018.77 0.31 -2,644.24 MWD+IFR2+HDS+MS(4) 6,567.00 73.40 111.40 3,384.56 3,291.77 -1,913.01 4,464.73 5,978,899.19 554,045.60 0.35 -2,659.24 MWD+1FR2+1113S+MS(4) 6,597.0 73.61 111.25 3,393.08 3,300.29 -1,923.47 4,491.53 5,978,888.91 554,072.46 0.85 -2,674.20 MWD+IFR2+HDS+MS (4) 6,627.00 73.57 111.04 3,401.56 3,308.77 -1,933.85 4,518.37 5,978,878.70 554,099.37 0.68 -2,689.08 MWD+IFR2+HDS+MS(4) 6,657.0 73.54 110.82 3,410.05 3,317.26 -1,944.13 4,545.24 5,978,868.61 554,126.30 071 -2,703.87 MVaD+IFR2+HDS+MS(4) 6,687.0 73.62 110.66 3,418.53 3,325.74 -1,954.32 4,572.15 5,978,858.59 554,153.28 0.58 .2,718.58 MWD+IFR2+HDS+MS(4) 6,717.W 73.61 110.58 3,426.99 3,33420 -1,964.46 4,599.09 5,978,848.64 554,180.28 0.26 -2,733.24 MWD+IFR2+HDS+MS(4) 6,74200 73.57 110.52 3,435.47 3,342.68 -1,974.56 4,626.04 5,978,838.72 554,207.29 0.23 -2,747.87 MWD+IFR2+HDS+MS (4) 6,777.00 73.57 110.35 3,443.95 3,351.16 -1,984.61 4,653.W 5,978,828.85 554,234.32 0.54 -2,762.44 MWD+IFR2+HDS+MS(4) 6,807.W 73.63 109.97 3,452.42 3,359.63 -1,994.53 4,680.02 5,978,819.11 554,261.40 1.23 .2,776.90 MWD+IFR2+HDS+MS(4) 6,837.00 73.54 109.54 3,460.90 3,368.11 -2,004.25 4,707.10 5,978,809.56 554,288.54 1.41 -2,791.18 MWD+IFR2+HDS+MS(4) 6,86TW 73.49 109.18 3,469.41 3,376.62 .2,013.79 4,734.24 5,978,800.21 554,315.74 1.16 -2,805.29 MWD+IFR2+HDS+MS(4) 6,897.90 73.38 109.08 3,477.97 3,385.18 -2,023.21 4,761.41 5,978,790.97 554,342.97 0.49 -2,819.29 MWD+IFR2+HDS+MS(4) 6,927.W 73.48 109.07 3,486.52 3,393.73 -2,032.61 4,788.58 5,978,781.75 554,370.20 0.33 -2,833.26 MWD+IFR2+HDS+MS(4) 6,957.00 73.67 1W.09 3,495.00 3,402.21 -2,042.02 4,815.78 5,978,772.52 554,397.6 0.64 -2,847.24 MWD+IFR2+HDS+MS(4) 6,987.W 73.69 109.24 3,5W.43 3,410.64 .2,051.47 4,842.97 5,978,763.25 554,424.71 0.48 -2,861.28 MWD+IFR2+HDS+MS(4) 7,017.00 73.62 109.47 3,511.88 3,419.09 -2,061.01 4,870.13 5,978,753.89 554,451.93 0.77 -2,875.39 MWD+IFR2+HDS+MS(4) 7,047.W 73.63 109.69 3,520.33 3,427.54 -2,070.65 4,897.25 5,978,744.43 554479.11 0.70 .2,889.60 MWD+IFR2+HDS+MS(4) 7,077.00 73.67 190.89 3,528.78 3,435.99 -2,080.40 4,924.34 5,978.734.66 554,506.26 0.65 -2,903.90 MWD+IFR2+HDS+MS(4) 7,107.00 73.57 110.06 3,537.24 3,444.45 -2,090.24 4,951.39 5,978,725.20 554,533.37 0.69 -2,918.28 MWD+IFR2+HDS+MS (4) 7,137.00 73.62 110.25 3,545.71 3,452.92 -2,1W.16 4,978.40 5,978,715.46 554,550.45 0.57 -2,932.74 MWD+IFR2+HDS+MS(4) 7,167.0 73.65 110.29 3,554.17 3,461.38 -2,110.13 5,005.41 5,978,705.67 554,587.51 0.16 -2,947.25 MWD+IFR2+HDS+MS(4) 7,197.W 73.60 110.17 3,562.62 3,469.83 .2,120.08 5,032.41 5,978,695.90 554,614.58 0.42 -2,961.74 MWD+IFR2+HDS+MS(4) 7,227.00 73.84 110.04 3,571.03 3,478.24 -2,129.98 5,059.45 5,978,686.18 554,641.69 0.90 -2,976.19 MWD+IFR2+HDS+MS (4) 7,257.00 74.75 109.63 3,579.15 3,486.36 -2,139.78 5,086.62 5,978,676.55 554,668.91 3.31 .2,990.56 MWD+IFR2+HDS+MS (4) 7,287.00 75.63 108.83 3,586.82 3,494.03 -2,149.33 5,114.01 5,978,667.19 554,696.35 3.91 3,004.72 MV4D+IFR2+HDS+MS(4) 7,317.W 76.08 107.97 3,594.15 3,501.36 -2,168.52 5,141.61 5,978,658.19 554,724.02 3.16 -3,018.55 MWD+IFR2+HDS+MS(4) 7,347.00 76.14 107.16 3,601.36 3,508.57 -2,167.30 5,169.37 5,978,649.59 554,751.84 2.63 3,032.03 MWD+IFR2+HDS+MS(4) 7,377.90 76.04 106.47 3,608.57 3,515.78 -2,175.73 5,197.25 5,978,641.35 554779.77 2.26 3,045.17 MWD+IFR2+HDS+MS (4) 7,407.00 75.64 105.80 3,615.91 3,523.12 4,183.81 5,225.19 5,978,633.45 554,807.76 2.54 3,057.98 MWD+iFR2+HDS+MS (4) 7,437.00 75.W 105.03 3,623.51 3,530.72 -2,191.53 5,253.17 5,978,625.93 554,835.78 3.27 3,070.44 MWD+IFR2+HDS+MS(4) 7,467.W 74.49 103.91 3,631.40 3,538.61 .2,198.76 5,281.19 5,978,618.88 554,863.85 3.98 3,082.42 MWD+IFR2+HDS+MS(4) 7,497.00 74.59 102.64 3,639.4D 3,646.61 -2,205.40 5,309.33 5,978,612.43 554,892.03 4.09 3,093.85 MWD+IFR2+HDS+MS (4) 7,527.00 75.07 101.38 3,647.25 3,554.46 -2,211.42 5,337.65 5,978,806.59 554,920.39 4.36 .3,104.70 MWD+IFR2+HDS+MS(4) 7,557.00 75.80 100.36 3,654.83 3,562.4 -2,216.90 5,366.16 5,978,601.31 554,948.93 3.83 -3,115.04 MV4D+IFR2+HDS+MS(4) 7,687.00 76.67 99.52 3.662.00 3,569.21 -2,221.92 5,394.85 5,978,596.47 554,977.65 4.33 3,124.97 MWD+IFR2+HDS+MS(4) 9/122018 7:06:27AM Page 7 COMPASS 5000.14 Build 85 Survey ConocoPhillips Definitive Survey Report Map Company: NADConversion Local Coordinate Reference: Well Rig: 1 H-104 Project: Kuparuk River Unit TVD Reference: 1 H-104 actual (d1 92.79usft (Doyon 142) Site: Kuparuk I Pad MD Reference: 1H-104 actual @ 92.79usft (Doyon 142) Well: Rig: 1H-104 North Reference: Two Wellbore: 1H-104PB1 Survey Calculation Method: Minimum Curvature Design: 1H-104PB1 Database: OAKEDMP2 Survey 9H2P1018 7:06:27AM Page COMPASS 5000.14 Build 85 Map Map Vertical MD Inc Azi TVD TVDSS +N14 +E1 -W Northing Basting DLS Section (-ft) (') (1) Wait) (waft) (waft) (USM (ft) (ft) (°1100') (ft) Survey Toot Name 7,617.00 77.66 98.72 3,668.67 3,575.88 -2,226.56 5,423.73 5,978,592.03 555,00656 4.20 -3,134.55 MWD+IFR2+HDS+MS (4) 7,647.00 77.74 97.57 3,675.06 3,582.27 -2,230.71 5,452.75 5,978,588.07 555,035.60 3.75 .7,143.68 MWD+IFR2+HDS+MS(4) 7,677.00 76.97 96.18 3,681.63 3,588.84 -2,234.22 5,481.81 5,978,584.75 555.64.68 5.20 -3,152.18 MWD+IFR2+HDS+MS(4) 7,707.00 76.42 95.01 3,688.53 3,595.74 -2,237.06 5,510.86 5,978,582.10 555,093.75 4.21 -3,160.03 MWD+IFR2+HDS+MS(4) 7,737.00 76.21 93.80 3,695.63 3,602.84 -2,239.30 5,539.92 5,978,580.05 555,122.82 3.98 -3,167.28 MWD+IFR2+HOS+MS (4) 7,767.0 76.15 92.39 3,702.80 3,610.01 -2,240.88 5,569.01 5,978,578.67 555,151.92 4.57 -3,173.88 MWD+IFR2+HDS+MS(4) 7,797.00 76.26 90.92 3,709.95 3,617.16 -2,241.72 5,598.13 5,978,578.02 555,181.04 4.77 3,179.77 MWD+IFR2+HDS+MS(4) 7,827.00 76.47 89.20 3,717.D2 3,624.23 -2,241.75 5,627.29 5,978,578.19 555,210.19 5.62 -3,184.% MWD+IFR2+HDS+MS(4) 7,857.00 76.61 67.30 3,724.01 3,631.22 -2,240.86 5,656.45 5,978,579.27 555239.34 6.18 -3,189.04 MWD+IFR2+HDS+MS (4) 7,887.00 76.83 85.81 3,730.90 3,638.11 -2,239.10 5,685.59 5,978,581.22 555,268.47 4.89 -3,192.38 MWD+IFR2+HDS+MS(4) 7,917.00 77.40 84.41 3,737.59 3,644.80 -2,236.61 5,714.73 5,978,583.90 555,297.59 4.93 -3,194.98 MWD+IFR2+HDS+MS(4) 7,947.00 78.05 82.74 3,743.97 3,651.18 -2,233.33 5,743.86 5,978,587.38 555,326.69 5.86 4,196.81 MWD+IFR2+HOS+MS(4) 7,977.00 78.51 81.08 3,750.06 3,657.27 -2,229.19 5,772.94 5,978,591.70 555,355.74 5.63 5,197.79 MWD+IFR2+HDS+MS(4) 8,007.00 78.91 79.43 3,755.93 3,663.14 -2,224.21 5,801.93 5,978,596.87 555,384.70 5.56 -3,197.92 MWD+IFR2+HDS+MS(4) 8,037.00 79.38 78.49 3,761.58 3,668.79 -2,218.57 5,830.85 5,978,602.71 555,413.58 3.45 -3,197.38 MWD+IFR2+HDS+MS(4) 8,067.00 79.62 77.91 3,767.05 3,674.26 -2,212.54 5,859.72 5,978,608.93 555,442.41 2.06 -3,196.46 MWD+IFR2+HDS+MS(4) 8,097.00 79.44 77.39 3,772.50 3,679.71 -2,206.23 5,888.54 5,978,615.43 555,471.16 1.81 4,195.25 MWD+IFR2+HDS+MS(4) 8,127.00 79.47 77.20 3,777.99 3,685.20 -2,199.74 5,917.31 5,978,622.11 555,499.90 0.63 -3,193.85 MWD+IFR2+HDS+MS(4) 8,157.00 79.34 77.19 3,783.51 3,690.72 -2,193.21 5,946.07 5,978,628.83 555,528.61 0.43 3,192.41 MWD+IFR2+HDS+MS(4) 8,187.00 79.61 77.17 3,788.99 3,696.20 -2,186.66 5,974.83 5,978,635.56 555,557.32 0.90 -3,190.96 MWD+IFR2+HDS+MS (4) 8,217.00 79.72 76.98 3,794.37 3,701.58 -2,180.06 6,003.59 5,978,642.35 655,586.04 0.72 3,189.45 MWD+1FR2+HDS+MS(4) 8,247.00 78.95 76.67 3,799.92 3,707.13 -2,173.34 6,032.30 5,978,649.26 555,614.70 2.76 -3,187.62 MWD+IFR2+HDS+MS(4) 8,277.00 79.01 76.36 3,805.66 3,712.87 -2,166.48 6,060.93 5,978,656.32 555,643.29 1.03 3,186.03 MWD+IFR2+HDS+MS(4) 8,307.00 79.24 76.18 3,811.32 3,718.53 -2,159.48 6,089.55 5,978,663.50 555,671.86 0.97 -3,184.11 MWD+IFR2+HDS+MS(4) 8,337.00 79.40 76.14 3,816.88 3,724.9 -2,152.43 6,118.18 5,978,670.74 555,70043 0.55 3,182.14 MWD+IFR2+HDS+MS(4) 8,367.00 79.37 76.11 3,822.40 3,729.61 -2,145.36 6,146.80 5,978,678.00 555,729.01 0.14 -3,180.15 MWD+IFR2+HDS+MS(4) 8,397.00 79.46 76.05 3,827.91 3,735.12 -2,138.27 6,175.43 5,978,685.28 555,757.58 0.36 -3,178.13 MWD+IFR2+HDS+MS(4) 5427.00 79.46 75.94 3,833.40 3,740.61 -2,131.13 6,204.04 5,978,692.61 555,786.15 0.35 -3,176.07 MWD+IFR2+HDS+MS(4) 8,457.00 79.28 75.83 3,838.94 3,746.15 -2,123.94 6,232.64 5,978,699.99 555,814.69 0.70 4,173.96 MWD+IFR2+HDS+MS(4) 8,487.00 78.31 75.65 3,844.77 3,751.98 -2,116.69 6,261.16 5,978,707.43 555,843.16 3.29 3,171.77 MWD+IFR2+HDS+MS(4) 8,517.00 76.87 75.34 3,851.21 3,758.42 -2,109.35 6,289.52 5,978,714.95 555,871.47 4.90 -3,169.47 MWD+IFR2+HDS+MS (4) 8,647.00 75.44 74.98 3,858.39 3,765.60 -2,101.89 6,317.68 5,978,722.60 555,899.58 4.91 3,167.01 MWD+IFR2+HDS+MS(4) 8,577.00 74.18 74.66 3,866.25 3,773.46 -2,094.31 6,345.62 5,978,730.36 555,927.46 4.32 -3,164.40 MWD+IFR2+HDS+MS(4) 8,607.00 73.18 74.42 3,874.68 3,781.89 -2,086.64 6,373.37 5,978,738.22 555,955.16 3.42 3,161.65 MWD+IFR2+HDS+MS(4) 8,637.00 72.20 74.23 3,883.61 3,790.82 -2,076.90 6,400.95 5,978,746.14 555,982.68 3.32 3,158.83 MWD+IFR2+HDS+MS (4) 8,667.00 71.25 74.06 3,893.02 3,800.23 -2,071.11 6,426.35 5,978,754.10 556,010.03 3.21 -3,155.92 MWD+IFR2+HDS+MS(4) 8,697.00 70.15 74.03 3,902.93 3,810.14 -2,063.33 6,455.57 5,978,762.6 555037.20 3.67 -3,152.98 MWD+IFR2+HDS+MS(4) 8,727.00 68.99 74.07 3,913.40 3,820.61 -2,055.61 6,482.60 5,978,769.97 556,064.17 3.87 3,150.07 MWD+IFR2+HDS+MS(4) 6,757.00 68.40 74.12 3,924.30 3,831.51 -2,047.95 6,509.48 5,978,777.80 556,091.00 1.97 4,147.19 MWD+IFR2+HOS+MS(4) 8,787.00 68.42 74.29 3,935.34 3,842.55 -2,040.35 6,536.32 5,978,785.57 555117.79 0.53 3,144.38 MWD+IFR2+HDS+MS(4) 9H2P1018 7:06:27AM Page COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1 H-104 Project Kuparuk River Unit TVD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1H-104 actual @) 92.79usft (Doyon 142) Won: Rig: 1H-104 North Reference: True Weebore: 1H-104PB7 Survey Calculation Method: Minimum Curvature Design: 1H-104PB1 Database: OAKEDMP2 Survey 9/12x2018 7:06:27AM Page 9 COMPASS 5000. 14 Build 85 Yap Map vertical MD Inc Azl TVD TVDSS +N/.S +E14N Northing Easting DLS Section (waft) (r) (') Will (weft) Well) ("to (to (in (°1100') (ft) Survey Tool Name 8,817.00 68.36 74.56 3,946.39 3,853.60 -2,032.87 6,563.19 5,978,793.24 556,144.60 0.86 3,141.67 MWD+1FR2+HDS+MS(4) 8,847.00 69.02 74.84 3,957.29 3,864.50 -2,025.49 6,590.15 5,978,800.79 556,171.51 2.37 -3,139.09 MWD+IFR2+HDS+MS(4) 8,877.00 70.66 75.06 3,967.63 3,874.84 -2,018.18 6,617.34 5,978,808.28 556,198.65 5.51 3,136.61 MWD+IFR2+HDS+MS(4) 8,907.00 72.37 75.19 3,977.14 3,884.35 -2,010.87 6,644.84 5,978,815.76 556,226.10 5.71 .7,134.19 MWD+1FR2+HDS+MS(4) 8,937.0 73.90 75.13 3,985.85 3,893.06 -2,003.52 6,672.59 5,978,823.30 55.253.80 5.10 3,131.77 MWD+IFR2+HDS+MS(4) 8,967.00 75.43 75.04 3,993.78 3,900.99 -1,9%.08 6,700.55 5,978,830.93 556,281.70 5.11 3,129.29 MWD+IFR2+HDS+MS(4) 8,997.00 76.79 75.08 4,000.98 3,908.19 -1,988.57 6,728.69 5,978,838.62 556,309.78 4.54 3,126.78 MWD+IFR2+HDS+MS(4) 9,027.00 77.82 75.00 4,007.57 3,914.78 -1,981.01 6,756.% 5,978,846.37 556,338.01 3A4 -3,124.25 MWD+IFR2+HDS+MS(4) 9,057.0 78.77 74.83 4,013.66 3,920.87 -1,973.37 6,785.32 5,978,854.20 556,366.31 3.21 3,121.65 MWD+IFR2+HDS+MS(4) 9,087.00 79.71 74.67 4,019.26 3,926.47 -1,965.62 6,813.76 5,978,862.14 556,394.69 3.18 3,118.95 MWD+IFR2+HDS+MS(4) 9,117.00 79.92 74.51 4,024.57 3,931.78 -1,957.77 6,842.22 5,978,870.17 556,423.10 0.87 3,116.17 MWD+IFR2+HDS+MS(4) 9,147.00 79.71 74.36 4,029.87 3,937.08 -1,949.85 6,870.67 5,978,87B.28 556,451.49 0.86 -3,113.30 MWD+IFR2+HDS+MS(4) 9,177.0 79.74 74.25 4,035.22 3,942.43 -1,941.86 6,899.09 5,978,886.46 556,479.86 0.37 3,110.37 MWD+IFR2+HDS+MS(4) 9,207.00 79.69 74.14 4,040.58 3,947.79 -1,933.B2 6,927.49 5,978,894.68 556,508.20 0.40 3,107.39 MWD+IFR2+HDS+MS(4) 9,237.00 79.76 74.04 4,045.93 3,%3.14 -1,925.73 6,955.88 5,978,902.% 556,535.53 0.40 3,104.35 MWD+IFR2+HDS+MS(4) 9,267.0 79.65 74.00 4,051.29 3,958.50 -1,917.60 6,984.25 5,978,911.27 556,564.85 0.39 -3,101.27 MWD+IFR2+HDS+MS(4) 9,297.00 79.64 73.98 4,056.68 3,9153.89 -1,909.46 7,012.62 5,978,919.60 556,593.16 0.07 3,098.18 MWD+IFR2+HDS+MS(4) 9,327.00 79.70 73.95 4,062.06 3,969.27 -1,901.31 7,040.99 6,978,927.94 556,621.47 0.22 -3,095.08 MWD+IFR2+HDS+MS(4) 9,357.0 79.69 73.79 4,057.43 3,974.64 -1,893.11 7069.34 5,978,936.32 556,649.77 0.53 3,091.93 MWD+IFR2+HDS+M5(4) 9,387.00 79.93 73.52 4,072.74 3,979.95 -1,884.80 7,097.67 5,978,944.82 55.678.04 1.19 3,088.67 MWD+IFR2+HDS+MS(4) 9,417.00 81.23 73.26 4,077.65 3,984.86 -1,876.34 7,126.03 5,978,95347 556,706.34 4.42 3,085.26 MWD+IFR2+HDS+MS(4) 9,446.78 82.84 73.19 4,081.77 3,9B8.98 -1,867.83 7,154.27 5,978,962.16 558,734.52 5.41 3,081.78 MW0+IFR2+HDS+MS(4l 9,484.37 85.60 73.00 4,085.56 3,992.77 -1,856.96 7,190.05 5,978,973.27 556,770.22 7.36 3,077.28 MWD -INC ONLY (5) 9,579.45 88.57 71.42 4,090.39 3,997.60 -1,827.95 7,280.45 5,979,002.88 556,860.42 3.54 3,064.41 MWD+IFR2+HDS+MS(6) 9,609.00 90.20 70.68 4,090]1 3,997.92 -1,818.35 7,308.40 5,979,012.66 556,888.30 6.06 3,059.82 MWD+IFR2+HDS+MS(6) 9,639.00 91.22 69.88 4,090.34 3,997.55 4,808.23 7,336.64 5,979,022.96 55.916.47 4.32 3,054.75 MWD+IFR2+HDS+MS(6) 9,669.00 90.54 68.96 4,089.88 3,997.9 -1,797.69 7,364.72 5,979,033.69 556,944.48 3.81 3,049.24 MWD+IFR2+HDS+MS(6) 9,699.00 89.98 67.59 4,089.74 3,996.95 -1,786.58 7,392.59 5,979,044.98 556,972.27 4.93 3,043.15 MWD+IFR2+HDS+MS(6) 9,729.00 89.52 66.01 4,089.87 3,997.08 -1,774.76 7,420.16 5,979,056.98 556,999.76 5.49 3,036.30 MWD+IFR2+HDS+MS(6) 9,759.00 88.99 64.20 4,090.26 3,997.47 -1,762.14 7,447.37 5,979,069.78 557,026.88 6.29 3,028.59 MWD+IFR2+HDS+MS (6) 9,789.00 88.43 62.75 4,090.94 3,998.15 -1,748.74 7,474.20 5,979,083.35 557,053.62 5.18 3,020.06 MWD+IFR2+HDS+MS(6) 9,819.0 87.88 61.50 4,091.90 3,999.11 -1,734.72 7,500.71 5,979,097.55 557,080.03 4.55 3,010.85 MWD+IFR2+HDS+MS(6) 9,849.00 87.30 60.25 4,093.17 4,000.38 -1,720.14 7,526.89 5,979,112.31 557,106.12 4.59 3,001.03 MWD+IFR2+HDS+MS(6) 9,879.00 86.99 59.37 4,094.66 4,001.87 -1,705.07 7,552.79 5,979,127.54 557,131.91 3.11 -2.990.69 MWD+IFR2+HDS+MS(6) 9,909.00 87.20 58.% 4,096.18 4,003.39 -1,689.69 7,578.50 5,979,143.09 557,157.52 1.84 -2,980.01 MWD+IFR2+HDS+MS(6) 9,939.00 88.55 58.36 4,097.29 4,004.50 -1,674.07 7,604.09 5,979,158.87 557,183.00 4.80 -2,969.08 MWD+IFR2+HDS+MS(6) 9,969.00 89.78 57.61 4,097.73 4,004.94 -1,658.17 7,629.53 5,979,174.94 557,208.33 4.80 -2,957.83 MWD+IFR2+HDS+MS(6) 9,999.00 90.64 56.32 4,097.62 4,004.83 -1,641.82 7,654.68 5,979,191.46 557,233.37 5.17 -2,946.10 MWD+IFR2+HDS+MS (6) 10,029.00 90.80 55.02 4,097.24 4,004.45 -1,624.90 7,679.45 5,979,208.54 557,250.02 4.37 -2,933.74 MWD+IFR2+HDS+MS(6) 1.059.00 90.48 53.70 4,096.91 4,004.12 -1,67.42 7,703.83 5,979,226.18 557,282.28 4.53 -2,920.76 MWD+IFR2+HDS+MS(6) 9/12x2018 7:06:27AM Page 9 COMPASS 5000. 14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 1 H-104 Project Kuparuk River Unit TVD Reference: 1H-104 actual @ 92.79usft (Doyon 142) SNe: Kuparuk 1H Pad MD Reference: 1 H-104 actual @ 92.79usft (Doyon 142) WeN: Rig: 1H-104 North Reference: True WaMMM: 1H-104PB1 Survey Calculation Method: Minimum Curvature Destgn: 1H-104PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc AM TVD TVDSS +N1S +E1 -V1 Northing Easting DLS Section (usft) r) (1) (us(q (usft) (-it) (usft) (it) (ft) CM001 (it) Survey Tool Name 10,089.00 89.94 52.29 4,096.80 4,004.01 -1,589.37 7,727.78 5,979,244.39 557,306.12 503 -2,907.14 MWD+IFR2+HDS+MS(6) 10,119.00 89.25 50.96 4,097.01 4,004.22 -1,570.74 7,751.30 5,979,263.17 557,329.51 4.99 -2,892.88 MWDdFR2+HDS+MS (6) 10,149.00 88.49 49.79 4,097.60 4,004.81 -1,551.61 7,774.40 5,979,282.45 557,352.48 4.65 -2,878.05 MWD+IFR2+HDS+MS(6) 10,179.00 87.91 48.47 4,098.54 4,005.75 -1,531.99 7,797.08 5,979,302.21 557,375.02 4.80 -2,862.67 MWD+IFR2+HDS+MS(6) 10,209.00 87.43 47.30 4,099.76 4,006.97 -1,511.89 7,819.31 5,979,322.46 557,397.12 4.21 -2,846.73 MWD+IFR2+HDS+MS(6) 10,239.00 87.18 46.58 4,101.17 4,008.38 -1,491.43 7841.21 5,979,343.05 557,418.88 2.54 -2,830.39 MWD+IFR2+HDS+MS(6) 10,269.00 ST62 45.55 4,102.53 4,09.74 -1,470.64 7,862.79 5,979,364.00 557,440.32 3.73 -2,813.66 MWD+IFR2+HDS+MS(6) 10,29900 88.36 44.12 4,103.59 4,010.80 -1,449.38 7,883.93 5,979,385.39 557,461.32 5.36 -2,796.39 MWD+IFR2+HDS+MS(6) 10,329.00 89.68 41.97 4,104.10 4,011.31 -1,427.46 7,904.40 5,979,407.45 557,481.64 8.41 -2,778.36 MWD+IFR2+HDS+MS(6) 10,359.00 90.69 40.71 4,104.00 4,011.21 -1404.94 7,924.21 5,979,430.10 557,501.31 5.38 -2,759.62 MWD+1FR2+HDS+MS(6) 10,389.00 90.89 40.03 4,103.59 4,010.80 -1,382.08 7,943.64 5,979,453.08 557,520.58 2.36 -2,740.48 MWD+IFR2+HDS+MS (6) 10,419.00 91.59 39.35 4,102.94 4,010.15 -1,359.00 7,962.80 5,979,476.28 557,539.58 3.25 -2,721.08 MWD+IFR2+HDS+MS(6) 10,44900 92.06 38.97 4,101.99 4009.20 -1,335.75 7,981.73 5,979,499.65 557,558.36 2.01 -2,701.47 MWD+IFR2+HDS+MS(6) 10,479.00 91.98 38.95 4,100.93 4,008.14 -1,312.44 8,000.58 5,979,523.09 557,577.06 0.27 -2,681.79 MWD+IFR2+HDS+MS(6) 10,509.00 91.85 38.94 4,099.93 4,007.14 -1,289.12 8,019.43 5,979,546.53 557,595.75 0.43 -2,662.09 MWD+IFR2+HDS+MS(6) 10,539.00 91.15 39.19 4,099.14 4,006.35 -1,265.83 8,038.33 5,979,569.94 557,614.49 2.48 -2,642.45 MWD+IFR2+HDS+MS(6) 10,569.00 WAS 40.05 4,098.67 4,005.88 -1,242.73 8,057.46 5,979,593.17 557,633.46 3.32 -2,623.01 MWD+IFR2+HDS+MS(6) 10,599.00 90.60 40.92 4,098.34 4,005.55 -1,219.91 8,076.93 5,979,616.11 557,652.78 2.90 -2,603.93 MWD+IFR2+HDS+MS(6) 10,629.00 91.03 41.82 4,07.91 4,005.12 -1,197.40 8,096.76 5,979,638.75 557,672.46 3.32 -2,585.20 MWD+IFR2+HDS+MS(6) 10,659.00 90.88 42.83 4,097.41 4,004.62 -1,175.23 8,116.96 5,979,661.06 557,692.51 3.40 -2,566.87 MWD+IFR2+HDS+MS(6) 10,689.00 91.06 43.85 4,096.91 4,004.12 -1,153.41 8,137.54 5,979,683.00 557,712.95 3.45 -2,548.96 MWD+IFR2+HDS+MS(6) 10,719.00 91.81 44.73 4,096.16 4,003.37 -1,131.94 8,158.48 5,979,700.61 557,733.74 3.85 -2,531.45 MWD+IFR2+HDS+MS(6) 10,749.00 91.58 44.42 4,095.27 4,002.48 -1,110.58 8,179.53 5,979,726.11 557,754.65 1.29 -2,514.07 MWD+IFR2+HDS+MS(6) 10,779.00 91.55 43.88 4,094.45 4,001.66 -1,089.07 8,200.42 5,979,747.76 557,775.39 1.80 -2,496.51 MWD+IFR2+HDS+MS(6) 10,809.00 91.57 43.29 4,093.63 4,000.84 -1,067.34 8,221.09 5,979,769.62 557,795.92 1.97 -2,478.71 MWD+IFR2+HDS+MS(6) 10,839.00 92.54 41.87 4,092.56 3,999.77 -1,045.27 6,241.38 5,979,791.82 557,816.05 5.73 -2,060.49 MWD+1FR2+HDS+MS(6) 10,869.00 93.94 40.06 4,090.86 3,998.07 -1,022.65 8,261.01 5,979,814.56 557,835.54 7.62 -2,441.63 MWD+IFR2+HDS+MS (6) 10,899.00 95.36 37.66 4,088.43 3,995.64 599.37 8,279.77 5,979,837.97 557,854.14 9.27 -2,421.96 MWD+IFR2+HDS+h1S(6) 10,929.00 95.23 36.16 4,085.66 3,992.87 -975.49 8,297.71 5,979,861.97 557,871.92 5.00 -2,401.55 MWD+IFR2+HDS+MS(6) 10,95900 95.09 35.33 4,082.96 3,990.17 551.24 8,315.17 5,979,886.33 557,889.21 2.79 -2,380.70 MWD+IFR2+HDS+MS(6) 10,989.00 95.30 35.35 4,080.25 3,987.46 526.87 8,332.45 5,979,910.81 557,906.33 0.70 -2,359.70 MWD+IFR2+HDS+MS(6) 11,019.00 95.38 35.63 4,077.45 3,964.66 -902.55 8,349.79 5,979,935.24 557,923.51 0.97 -2,338.76 MWD+IFR2+HDS+MS(6) 11,049.00 95.34 35.75 4,074.65 3,981.86 578.29 8,367.22 5,979,959.62 557,940.77 0.42 -2,317.89 MWD+IFR2+HDS+MS(6) 11,079.00 95.37 35.87 4,071.85 3,979.06 -854.06 8,384.69 5,979,983.95 557,958.08 0.41 -2,297.07 MWD+IFR2+HDS+MS(6) 11,109.00 95.32 36.18 4,069.06 3,976.27 529.91 8,402.26 5,980,008.22 557,975.49 1.04 -2,276.34 MWD+IFR2+HDS+MS(6) 11,139.00 95.39 36.95 4,066.26 3,973.47 -805.92 8,420.05 5,98,032.33 657,993.12 2.57 -2,255.80 MWD+IFR2+HDS+MS(6) 11,166.71 95.79 37.58 4,063.56 3,970.77 -763.97 8,436.75 5,980,054.38 558,009.67 2.68 -2,237.08 MWD+IFR2+HDS+MS(6) 11,227.00 95.79 37.58 4,057.48 3,964.69 -736.43 6,473.33 5,980,102.16 558,045.94 0.00 -2,196.62 PROJECTED to TD 9/12/2018 7.06:27AM Page 10 COMPASS 5000.14 Build 85 Cement Detail Report 11-1-104 String: Conductor Cement Job: DRILLING ORIGINAL, 8/5/2018 09:00 Cement Details Description Conductor Cement Cementing StartDate 11/4/2016 06:00 Cementing End Date 11/4/2016 08:00 WellboreName IH -104 Comment Cement Stages Stage # 1 Description Conductor Cement Objective Top Depth (ftKB) 0.0 Bottom Depth (ft(B) 118.5 Full Return? Yes Vol Cement... 0.0 Top Plug? No Btm Plug? No O Pump Init (bbllm.. Q Pump Final (bbll... O Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psl) RecipT No Stroke (ft) 0.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill 1131/2 Out Diameter (in) Comment Cement Fluids 8 Additives Fluid Fluid Type Surface Cement Fluid Description Estimated Top (ftKB) 4.0 Est Bum (ftKB) 118.5 Amount (sacks) Class 1 G Volume Pump etl (bbl) 40.5 Yield (ft -/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 912412018 Cement Detail Report 11-1-104 String: Surface Casing Cement Job: DRILLING ORIGINAL, 8/5/2018 09:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 8/7/2018 19:30 8/7/2018 23:30 11-1-104 Comment Pump 5 bbls of CW100 & PT lines to 4000 psi, good. Pump 35 bbls of CW100 at 4.8 bpm, 120 psi. Pump 80 bbls of 10.5 ppg MPII at 4 bpm, 115 psi. Drop bottom plug. Pump 300.9 bola of 11.0 ppg Lead cement at 6 bpm, 175 psi. Observed bottom plug bump w/ 179 bbls away. Observed MPH at surface at 265 bbis away. Pump 67 bbls of 12.0 ppg Tail cement at 6 bpm, 270 psi. Drop top plug. Pump 10 bbls of fresh H2O at 5 bpm, 150 psi. Swap to rig & pump 165.1 Dols of 9.5 ppg spud mud to bump plug. Observe good 11.0 ppg cement back w/ 75 bbl mud pumped. Landed on hanger w/ 80 bbls of mud pumped. Pressure up to 784 psi & hold for 5 minutes. Check floats, good. CIP 23:22 his. Total of 109 bbls of 11.0 ppg lead cement to surface. Cement Stages Stage # <Stage Number?> Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 42.4 1,906.0 Yes 109.0 Yes Yes Q Pump Inft (bbl/m... O Pump Final (boll... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (pal) Recip? Stroke (H) Rotated? Pipe RPM (rpm) 4 5 6 280.0 780.1 Yes 10.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump 5 bbls of CW100 & PT lines to 4000 psi, good. Pump 35 bbls of CW100 at 4.8 bpm, 120 psi. Pump 80 bbls of 10.5 ppg MPH at 4 bpm, 115 psi. Drop bottom plug. Pump 300.9 bbls of 11.0 ppg Lead cement at 6 bpm, 175 psi. Observed bottom plug bump w/ 179 bbls away. Observed MPH at surface at 265 bbls away. Pump 67 bola of 12.0 ppg Tail cement at 6 bpm, 270 psi. Drop top plug. Pump 10 bbls of fresh H2O at 5 bpm, 150 psi. Swap to dg & pump 165.1 bbls of 9.5 ppg spud mud to bump plug. Observe good 11.0 ppg cement back w/ 75 bbl mud pumped. Landed on hanger w/ 80 bbls of mud pumped. Pressure up to 784 psi & hold for 5 minutes. Check floats, good. CIP 23:22 hrs. Total of 109 bbls of 11.0 ppg lead cement to surface. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 42.4 1,254.0 885 G 300.9 Yield (11/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr I (psi) 1.91 6.76 11.00 74.1 5.75 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bim (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,254.0 I 1,906.0 228 1 G 67.0 Yield (fNlsack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) Cmprstr I (psi) 1.65 5.60 1 12.00 85.5 4.00 Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 9124120181 Cement Detail Report mh - IH -104 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 8/5/2018 09:00 Cement Details Description Cementing Start Date Cementing Entl Dale Wellbore Name Intermediate Casing Cement 8/14/2018 74:00 8/14/2018 18:00 1 H-104 Comment PJSM and RU cement hose PT lines to 4,000 PSI. (PASSED). Reciprocate pipe from 9,503' MD - 9,488' MD. UP WT = 211K. OWN WT = 101K. PUmp 41.3 BBLS MP II. @ 3 BPM 312 PSI, 12% F/O. Drop BTM Plug pump 250 BBLS of 15.8# class G cement stage up pumps to 6 BPM with ICP 400 SI. FCP 270 PSI. 22% F/O. Drop top plug and chase with 10 BBLS H2O. followed with 9.2 PPG treated LSND @ 7 BPM icp 161 PSI, Obsereve OWN WT to 50K - 10' high. Attempt to free pipe with no success. UP WT = 228K, OWN WT = 98k. continue to pump 7 BPM with FCP 1,265 PSI. teduce rate to 3 BPM @ 4,025 Stks. ICP 1,175 PSI. FCP 1,320 PSI. Bump plug with 422 STKS. CIP @ 1730 his. Increase pressure to 1,853 PSI and hold for 5 min. Bleed off and check floats. Holding. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 4,775.0 9,514.0 Yes Yes Yes Cement Q Pump Ink (bbl/m... q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke IN) Rotated? Pipe RPM (rpm) 3 7 7 1,265.0 1,265.0 Yes 15.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment PJSM and RU cement hose PT lines to 4,000 PSI. (PASSED). Reciprocate pipe from 9,503' MD - 9,488' MD. UP WT = 211 K. DWN WT = 101 K. PUmp 41.3 BBLS MP II. @ 3 BPM 312 PSI, 12%F/0. Drop BTM Plug pump 250 BBLS of 15.8# class G cement stage up pumps to 6 BPM wfth ICP 400 SI. FCP 270 PSI. 22% F/O. Drop top plug and chase with 10 BBLS H2O. followed with 9.2 PPG treated -SND @ 7 BPM icp 161 PSI, Obsereve OWN WT to 50K - 10' high. Attempt to free pipe with no success. UP WT = 228K, DWN WT = 98k. continue to pump 7 BPM with FCP 1,265 PSI. teducerate to 3 BPM @ 4,025 Stks. ICP 1,175 PSI. FCP 1,320 PSI. Bump plug with 422 STKS. CIP @ 1730 hrs. Increase pressure to 1,853 PSI and hold for 5 min. Bleed off and check floats. Holding. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bum (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 3,675.0 4,775.0 41.3 Yield (ft -/sack) Mix H2O Ratio (Belles... Free Water (%) Density (Iblgal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 12.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) I Est Bum IRKS) Amount (sacks) Class Volume Pumped (bbl) Cement 4,775.0 19,515.0 1,401 G 250.0 Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.12 15.80 163.0 4.22 Additives Additive Type Concentration Cone Unit label Page Ill Report Printed: 912412018 218084 29840 Schlumberger -Private 218084 29 84 3 Schlumberger -Private w, Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Sunday, August 19, 2018 9:17 AM To: Scott A Brunswick Subject: Fwd: [EXTERNAL]RE: 1H-104 (PTD 218-084) BOPE Use Notification Aug 18 2018 Follow Up Flag: Follow up Flag Status: Completed Drill to TD. Test the first time you POOH. Thanx, Victoria On Aug 18, 2018, at 3:04 PM, Brunswick, Scott A <Scott.A.Brunswickt�conocophillips com> wrote: Confirmed, thank you. Are we OK to drill to TD once the well is killed, then test, or should we plan to POOH to test before drilling ahead? From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Sent: Saturday, August 18, 2018 3:02 PM To: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com>; Schwartz, Guy L (DOA) <guy.schwa rtz@alaska.gov>; Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Cc: Regg, James B (DOA) <jim.regg@alaska.eov> Subject: [EXTERNALJRE: 1H-104 (PTD 218-084) BOPE Use Notification Aug 18 2018 Importance: High Scott, Any BOPE components used for well control purposes must be function pressure tested before the next wellbore entry. Please refer to Guidance Bulletin No 06-01 on our website. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepoftalaska.cov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is a. Waiting on the water base kill weight fluid to be mixed at the mud plant: DPP 200 psi / CP 170 psi after 453 bbls circulated. Remedial actions will be to pump the 10.2 ppg kill weight WBM fluid to kill the well. If you have any questions or require further information, please contact Scott Brunswick (Scott.A.Brunswick@conocophillips.com) at 263-4249 or 227-8499. Sincerely, Scott Brunswick Drilling Engineer THE STATE °fALASKA GOVERNOR BILL WALKER G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H-104 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-084 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.claska.gov Surface Location: 5200.56' FNL, 772.31' FEL, SEC. 28, T12N, R10E, UM Bottomhole Location: 2030.46' FNL, 3899.78' FEL, SEC. 26, T12N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for the permit to drill 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, Hollis S. French S y Chair DATED this i day of August, 2018. RECEIVED STATE OF ALASKA AL -KA OIL AND GAS CONSERVATION COMM. ION JUL 2 J 2018 PERMIT TO DRILL 9n AAC 95 005 1 a. Type of Work: Drill ❑' - Lateral ❑ Redrill ❑ Reentry ❑ 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG Service - Disp ❑ Stratigraphic Test ❑ Development - Oil Service - Winj ❑ Single Zone ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone E • 1c. Spe0tVfor: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips 5. Bond: Blanket Q . Single Well ❑ Bond No. 59-52-180 11. Well Name and Number: KRU iH-104 . 3. Address: P.O. Boz 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 16084 TVD: 4030 12. Field/Pool(s): Kuparuk River Field West Salk Oil Pool - 4a. Location of Well (Governmental Section): Surface: 5200.56' FNL, 772.31' FEL, Sec 28, T 12N, R010E, UM Top of Productive Horizon: 2050.34' FNL, 143.74' FEL, Sec 34, T 12N, R01 OE, UM Total Depth: 2023.46 FNL, 3899.78' FEL, Sec 26, T 12N, R010E, UM 7. Property Designation: ADL025639 & ADL025638 8. DNR Approval Number: 80-261 & 931695000 13. Approximate Spud Date: 8/1/2018 9. Acres in Property: 2560 & 2560 14. Distance to Nearest Property: 2751'to ADL025637 41b. Location of Well (Slate Base Plane Coordinates - NAD 27): Surface: x- 549568.74 y- 5980782.43 . Zone- 4 10. KB Elevation above MSL (ft): 93.1' ' GL / BF Elevation above MSL (ft): 54.1' • 15. Distance to Nearest Well Open to Same Pool: 518' to 1 H-110 16. Deviated wells: Kickoff depth: 250 feet • Maximum Hole Angle: 92.96 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 1767 psi • Surface: 1364 psi - 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94# H-40 Welded 80 Surface Surface 118 118 Existing, cement to surface 13-1/2" 10-3/4" 45.5# L-80 Hyd 563 1864 Surface Surface 1918 • 1800 985 sx 11.0 Lead, 201 sx 12.0 Tail 9-7/8" 7-5/8" 29.7# L-80 Hyd 563 9414 Surface Surface 9468 • 4083 1169 sx 15.8 Class G 6-3/4" 4-1/2" 12.6# L-80 IBTM/TXP 6616 9468 4083 16084 . 4030 N/A: Un -cemented slotted liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑' ' 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch DrillingProgram Time v. Depth Plot 4 Seabed Report e Drilling Fluid Program e Shallow Hazard Analysis 20 AAC 25.050 requirementse 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be Kelsey Shumway deviated from without prior written approval. Contact Name: V S -111-9116 Authorized Name: G. Alvord Contact Email: kelsey.shumway@conocophillips.com Authorized Title: Alaska Drilling Manager Contact Phone: 1-907-265-1577 1Ie yt� Authorized Signature: V L • ALVOR D Date: '] Commission Use Only Permit to Drill ,Q / Number; 2IU-w API Number: '7 50-U�y-4'3�/v ��-�� Permit Approv I Date: See cover letter for other 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: ,[✓7 Other: L9 n ¢CSf JJ/�SSU/'G 3500 ,v 5 / SWs re 'd4: Yes ❑ Noy Mud log req'd: Yes❑ Noo (l /-' ,1,, 5 v`L s� e�y �s7 Yes Y NO E] Directional svy req'd: Yes YNo ❑ �9rviv/ar / Z Yt n fl ✓C" g p q/ ❑ No LI Inclination -only svy req'd: Yes❑ No Spacing exception req'd: Yes Post initial injection MIT req'd: Yes ❑ NOR' F'1 7- l APPROVED BY Approved by: i' COMMISSIONER THE COMMISSION Date: .�\�+/ Form 10-401 Revised 5/2017 This per it 15 vali o V` . A n f e t Submit Form and of approval per 20 AAC 25.005(g) Attachments in Duplicate Lel✓_ ./ . A\. �-- _ - u.. %A - _ - fG/% jam ./c��j / L. � "/(5 Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 265-1577 Email: kelsev.shumway(ftonocophillips.com July 18, 2018 Alaska Oil and Gas Conservation Commission 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, IH -104 Dear Commissioner: Application for Permit to Drill, Well 1H-104 Saved: 19 -Jul -18 ConocOPhilfip5 ConocoPhillips Alaska, Inc. hereby applies for a permit to drill a grass roots onshore producer, a tri -lateral horizontal well in the West Sak A2/A3, B and D sands. The expected spud date for this well is August 1, 2018. It is planned to use rig Doyon 142. A 13-1/2" surface hole will be drilled on diverter & 10-3/4" surface casing will be run to total depth and cemented to surface. The remaining intervals will utilize Doyon 142's 13-5/8" x 5000 psi BOP stack with required ram installations and tested on a 14 day cycle in accordance with COP and AOGCC policy. The intermediate hole section will drill a 9- 7/8" hole with 7-5/8" casing run to total depth & cemented in place. The first 1H-104 6-3/4" production lateral will be geo-steered in the West Sak A2.4nd A3'sands and lined with 4-1/2" slotted liner. The subsequent production laterals will again be drilled with 6-3/4" hole and lined with 4-1/2" slotted liner in the following order: West Sak D and B sands then a dedicated D sand lateral. A separate PTD application will be submitted for each lateral: 1H-104, 1H -104L1, and 11-1- 104L2 laterals. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Kelsey Shumway at 265-1577 (kelsey.shumwav ( ,conocophillips.com) or Chip Alvord at 265-6120. Sin erely, el ey S um %h'W� Sr. Drilling Engineer Application for Permit to Drill Document ' Kuparuk Well 1H-104 Well Name Requirements of 20 AAC 25.005 (fl The well for which this application is submitted will be designated as KRU 1H-104 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the properqand the properor s owners and showing (.Aphe coordinates of the proposed location of the well at the surface, at the top ofeach 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 jor 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 5200.56' FNL, 772.31' FEL, Sec 28, T 12N, ROI OE, UNI ' NGS Coordinates Northings: 5980782.43' Eastings: 549568.74' i CB Elevation 93.1'AMSL Pad Elevation 54.1' AMSL ' Location at Surface Casing 138.71' FNL, 298' FEL, Sec 33, T12N, R010E, UM NGS Coordinates Northings: 5980567.48' Eastings: 550044.93' Measured De th, RKB: 1918' TO Vertical De th, RKB: 1800' Total Vertical Depth, SS: 1 1707' Location at Intermediate Casing NGS Coordinates Northings: 5984011.97' Eastings: 556972.29' 1743.07' FNL, 4160.03' FEL, Sec 35, T12N, R010E, UM NGS Coordinates Northings: 5979011.08' Eastings: 556756.24' Measured De th, RKB: 9468' 1 Total Vertical De th, RKB: 4083' Total Vertical Depth, SS: 1 3990' Location at Total De th 2023.5 FNL, 3899.78' FEL, Sec 26 T 12N, R010E, UM NGS Coordinates Northings: 5984011.97' Eastings: 556972.29' Measured Depth, RKB: 16084' Totad Vertical De7th, RKB: 1 4030' Total Vertical Depth, SS: 1 3937' and (D) otherit,fornation required by 20 AAC 15.050(b): Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated. the applicatimt for a Permit to Drill (Foran 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 die proposed well: Please see Attachment: Directional Plan And (1) for all wells within 200 feet of tate proposed wellbore (A) list ilte names of die 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 nail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application Joh a Permit to Drill must be accompanied by each of the follmving items. except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035. 20 AAC 25.036. or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142 & within this PTD application. Due to lower reservoir pressure in the West Sak a fixed stack ram placement will be utilized to fulfill all barrier requirements during well construction operations, graphic attached. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompoined by each of the follmving items. except for an item already on file with the commission and identified in the application: (4) information on drilling hazards. including (A) the ouryinamn dmvnhole pressure that may be encountered, criteria used to determine it. and maximum, potential surface pressure based on a methane gradient: The maximum potential surface pressure (MPSP) while drilling 1H-104 is calculated using an estimated maximum reservoir pressure of 1767 psi (based on I H -05A pressure at a 4005.2' TVD reference datum), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak A2 sand at 4032' TVD: A2 Sand Estimated. BHP = 1,767 psi /F66: A2 Sand estimated depth = 4,032' TVD '40 37, Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 403 psi (4,032' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 1,364 psi (1,767 psi — 403 psi) (B) data on potential gas cones: The wellbore is not expected to penetrate any shallow gas zones. And (C) data concerning polential causes of hole problems such as abnormal/)geo-pressured strata, lost circulation cones. and cones that have a propensity, for differential sticking; See attached 1H-104 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill mast be accompanied by each of the fol/mring items. except for an item ab'eady 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 25.0300: A procedure is on file with the commission for performing FIT/LOT's. The FIT/LOT will be performed on the motherbore of the 1H-104 tri -lateral well (IH-104).'�ConocoPhillips requests a waiver on �— subsequent laterals FITILOT (1H -104L1 and 1H -104L2). Waiving the upper lateral FIT/LOT may be undertaken if the following criteria are met: 1. Primary cement job pumped as per design with no issues. 2. WellView cement report submitted to AOGCC for review of job before 2nd lateral is drilled (1H -104L1). 3. No abnormal pressure is discovered while drilling the motherbore well (lowest lateral). 4. Kill weight fluid is confirmed using a static flow check at the shoe post TD of the 1H-104 motherbore. If any of the above-mentioned criteria are not met, performing an FIT/LOT of the upper laterals will be undertaken. r Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for o Per to Drill must be accompanied by each of the following items. except for an item ah-eady on file wish the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030. and a description of any slotted liner. pre -perforated liner, or screen to be installed Casing and Cement Program Hole 2" 42'-' Casing 20" Weight 94# Grade 1+40 Coupling Welded Length 80 MD Surface TVD Surtace MD 118 TVD 118 (including stage data) Ex¢ting, cement to surface 13-1/2" 10-314" 45.5# L-80 Hyl 563 1884 Surface Surface 1918 1800 985 sx 11.0 Lead, 201 sx 12.0 Tail 97-5/8" Tail Cement 29.7# L-80 Hid 563 9414 Surface Surface 9468 4083 1169 5x 15.8 Gass G 6-314" 4-1/2" 12.8# L-80 IBTM'rXP 6616 9466 4083 16084 4030 WA: un-oemented Slotted liner Surface Cement: Surface to 1,918' MD • Capacities Lead 1.91 ft3/ sx of 11.0 ppg LiteCRETE OH 0.177045 Tail 1.65 ft3/sx of 12.0 DeepCRETE Permafrost (PF) depth 1715 ft 13-1/2" x 10-3/4" 0.064783 XS% Lead 275% 20"x 10-3/4" 0.24302 XS% Tail 50% 10-3/4" 0.096175 Tail Cement Length 500 ft 500 x 0.065 x 1.5 48.6 Shoe Track 80 ft 80 x 0.096 x 1 7.7 Open Hole 10 x 0.177 x 1.5 2.7 Total 59 bbl 331 ft3 201 sx Lead Top Tail Cement to Conductor 1299 ft 1299 x 0.065 x 3.75 315.6 bbl Conductor Length 80 ft 80 x 0.243 19.4 bbl Total: 335 bbl 1881 ft3 985 sx Intermediate Cement: Cement from 9468' to 4500' MD Capacities: Slurry: 15.8ppg Class G yielding 1.16ftA3/sk 9-7/8" x 7-5/8" 0.03825 XS%for open hole and annulus: 25% 9-7/8" OH 0.094731 7-5/8" ST 0.045916 Annulus Cement 4968 x 0.038 x 1.25 237.54 bbls Rathole Cement 2 x 0.095 x 1.25 0.24 bbls Shoe Track 80 x 0.046 x 1 3.67 bbls Total 241 MIS 1355 ft3 1169 sx Diverter System Information Requirements of 20 AAC 25.005(c)(9) An application jar a Permit to Drill nmst be accompanied by each of dre follmring items. except for an item already on f le with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 15.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(1); Please reference attachment for diverter schematic. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill meat be accompanied by each of dre folhnving items, except for an ilem alread i on file with the commission and identified in the application: (B) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25033,• Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Mud System Spud (WBM) LSND FloPro (WBM Density 8.8-9.5 9.0-9.4 9.2-9.5 PV ALAP ALAP ALAP YP 30-80 20-30 15-30 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A N/A Initial Gel 30-50 8-15 5-10 10 minute Gel 30-50 < 30 6-15 API Filtrate I NC <10 < 6 HTHP Fluid Loss at 120 F N/A N/A <10 H 9.0-10.0 9.0-10.0 9.0-9.5 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application jor a Permit to Drill nium be accompanied by each of the following items. except for an item already on file wish the commission and identified in the application. The proposed drilling program follows. Please refer to attachment for proposed well schematic. I. Move in / rig up Doyon Rig 142. Install 21-1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 13-1/2" hole to casing point as per directional plan. Survey & log with MWD, GWD, GR/RES. 3. Run and cement 10-3/4", 45.5#, L80, Hyd-563 casing to surface. Displace cement with mud & check floats upon bumping plug. Perform top job if required after notifying AOGCC. Evacuate top 2 feet of cement from annulus for sealant job (post rig). 4. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's to 3500 psi high and 250 psi low. Notify AOGCC 24 hrs before test. 5. PU 9-7/8" PDC bit and directional drilling assembly, with MWD, Gamma, Resistivity. RIH and clean out to 100' above shoe. Test surface casing to 3,000 psi for 30 minutes. 6. Drill out shoe track and 20' of new formation. Perform FIT to a minimum of 11.5 ppg, maximum of 13 ppg EMW LOT/FIT, record results. ✓ 7. Directionally drill to intermediate hole TD landing in the West Sak A2 sand package. 8. BROOH to surface shoe, circulate well clean then POOH on elevators. 9. Laydown intermediate BHA. 10. Run 7-5/8", 29.7 L80, Hydril 563 casing from surface to TD. 11. Pump cement job as per Schlumberger proposal. Top cement to be placed @+/- 4500' MD (250' TVD minimum above Ugnu C formation). 12. Install 7-5/8" packoff & test to 5000 psi. 13. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel to freeze protect. 14. PU 6-3/4" bit, and drilling assembly with MWD, Gamma, Resistivity, and Periscope. 15. RIH on 4" DP to top of float equipment. Clean out cement to top of float equipment & test casing to 3,500 psi for 30 minutes, testing against the annular to accommodate the West Sak fixed stack BOP configuration. 16. Drill out shoe track and 20' of new formation. Perform LOT to a minimum of 11.5 ppg EMW maximum FIT of 13.0 ppg, recording results. 17. Directionally drill 6-3/4" hole geo-steering through the West Sak A2 sand and A3 sand to TD per directional plan. 18. Circulate 1 BU after TD and BROOH to 7-5/8" shoe CBU to clean casing & POOH on elevators. 19. Lay down Production BHA. 20. PU and run 4-1/2", 12.6# slotted liner w/ ZXP liner hanger & packer. The top of liner will be placed inside of the 7-5/8" casing to allow for overlap and proper spacing for the whipstock assembly. 21. Set liner hanger & packer. 22. PT liner top packer to 2,500 psi for 10 minutes, chart results. 23. Flow check well for 30 minutes. 24. POOH with liner running tools and lay down. 25. Run & set Baker whipstock system, placing the KOP for 1 H -104L1 in the lower lobe of the West Sak D sand. 26. Mill 6-3/4" window until top mill across face & clean up window. 27. POOH with milling BHA. 28. PU 6-3/4" bit, motor, MWD, and magnets to perform a clean out run & land the well. (GR, Res) 29. RIH, orient through window and tag bottom. 30. End 1H-104 PTD & begin 1H -104L1 PTD. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the following items, except jar an iter, ah'eady on file with the connnission and identified it, the application: (14) a general description of ho, the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authoriralion tinder 10 AAC 15.030 far an annular disposal operation in the well.: Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class 11 disposal well at the 1 B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 BOP Ram Placemen[ Attachment 2 Well Schematic Attachment 3 Diverter Layout Diagram Attachment 4 Directional Plan Attachment 5 Drilling Hazards Summary h I2 F 27, July 03 2018 I F— 1 H-104wp26 I Permit K-1 5 1 \ WS_A3� — I 10 LT3 Perm- 7 - UG U UNa4- WS_A2--- %42' 3375 6750 10125 135002" x 6 3/4" Measured Depth 000 Plan: 54.1+39 @ 93.10usft (Doyon 142) O 0 0 103/4 no-__ ^ryt 41 N o 2000 4000 6000 ��P� 100;�'12000 ,;'^oho Ho 7-5/8" x 9-i '? neo x 6fi' Measured Depth SURVEY PROGRAM U ace OCT Ion Depth From Cepth To SunreylPlan Tool Pad Elevation: 54.10 30W 1400.00 On (Plan: 1H-104) GYD-GCSS 100000 1020.00 1H-104wp26(Plan: 1H-104) MWD 6106 140000 1920.00 1H-104wPn(Plan: 1H-104) MWD+IFR-AK-,U-SC 11810 118.10 20'•x42” 182000 3420.00 1H-104wp28 (PIem 1H-104) MWD 1800.001918.25 103/4" 192000 9465.00 1H-IWir,,6(Plan'. 1H-104) MWD+IFR-AK-CAZSC 4083.049468.44 75/8"%9-7/8" 0485.001036500 1H-104wp26(Plan: 1H-104) MWD 4030.008084.13 41/2"%63/4" 0465.0015084.13 1H-104wp26(Plan: 1H-104) MWU+IFR-AK-0PZ-SC V. Osara ,,.,wm.cwaam,e� nn,mwrozoa",ear ,a.,oe ln,mae",aaa ,»,w w,maaa,e ar lw,w a,moa"m,s Plan Summa 0 250 —4 0 330 ,; 30 140 — 640 &0 — 830 830 — 1020 — 1220 60 Ino — 1410 1410 — 1894 16o0 — 2200 2200 2800 2800 — 3400 A1020 90 3400 — 4094 0M 46W 1800 5200 1-11H 5200 5800 5800 6400 64M 7610 120 7810 — W20 8620 — 10030 10030 — 11240 11240 — 124W 210 150 124M 13M _ 13880 —' 14870 14870 — 16084 Magnetic Model & Date: BGGM201135-Aug-18 Magnetic North is 17.04° East of True North (Magnetic Declination) Magnetic Dip &Field Strength: 80.91` 57447nT Lithelogy Column Mnmaa snov as,.ern mmn :aur,. v"'.sno e.i>xm x=a is ue.m a„aa hu.orew„vm . l Base Perm sa.ow nmols.zna.,e,m E xo,e 3 By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surrounding wells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.) approve it as the basis for the final well plan and wellsite drawings. I also acknowledge +H�a -duos nntlfiP,H otherwise all tamets have a 100 feet lateral tolerance. Bui Erik Stark K-15 11 AUG C "'UG B "UG A na, - Na 1 H-104wp26 39.00 To 16084.13 Spider Easting (3000 usfUin) C-,8 1 H-104wp26 I Plan View While drilling production section stay within target poiVgon lateraHV of plan, unless notified otherwise. ry° 0 3Q H-104 LO TO9 063018 - 3000 oa 41/Z"zE3i4"- A 1 H-104 LO TO8 063018 1 H-104 LO T07 063018 P _ 2000 c 1 H-104 LO T06 063018 P o1000 1 H-104 LO T05 063018 P 0 -__�- ., 20"x 42" + ; 11H-104 LO T04 063018 P z_- 0 103/4"Ox 13 1/ �` ry 1 H-104 LO T03 063018 P 1 H-104 LO T02 063018 P -1000 00 1H-104 LO TOI 063018 dP 1 H-104 T02 B 063018 dP ' 7-5/8" x 9-7/8' ---- 1 H-104 TO4 Csg 063018 -2000- ---- _P --------- 1 H-104 T01 D 063018 P p 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 West( -)/East(+) (1000 usit/in) 1 H-104wp26 Section View 20" x 42" 0° 6501 1000 300 m 30° s� w1950 10 3/4" x 13 1/ ?000 n d s0° :?2600-0° - � °o eo 3250 7-5/8" x 9-7/8" °° ? A 80000 0 4 1/T x 6 314" 9 3900 9Q -3250 -26000 -1950 0 -1300 0650 0 650 F300 ° X1950 0 Vertical Section at 350.00° (650 usft/in) ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1 H-104 500292360600 Plan: 1 H-104 Plan: 1 H-104wp26 Standard Proposal Report 03 July, 2018 ConocoPhillips ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kupamk 1H Pad Well: Plan: 1H-104 Wellbore: Plan: 1H-104 Design: 1H-104wp26 Schlumberger Standard Proposal Report Local Co-ordinate Reference: Well Plan: 1H-104 TVD Reference: Plan. 54.1+39 @ 93.10usft (Doyon 142) MD Reference: Plan'. 54.1+39 @ 93.10usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kupamk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kupamk 1H Pad +El -W Site Position: (usft) Northing: From: Map Easting: Position Uncertainty: 0.00 usft Slot Radius: Well Plan: 1H-104 Well Position -NI-S 811.26 usft Northing: +E/ -W 376.91 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wegbore Plan: iH-104 — Magnetics Model Name Sample Date BGGM2018 8/15/2018 Design 1H-104wp26 Audit Notes: Latitude: Longitude: 0" Grid Convergence: Declination l°I 17.04 Version: Phase: PLAN Vertical Section: Depth From (ND) +NIS (usft) (usft) 39.00 0.00 Latitude: Longitude: Ground Level: Dip Angle l°I 80.91 Tie On Depth: 39.00 +El -W Direction (usft) (°) 0.00 350.00 0.37 ° 54.10 usft Field Strength (nT 57,447 J 7/10/2018 11:05:35AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Schlumberger Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: OAKEDMP2 ConocoPhillips (Alaska) Inc. -Kupt Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-104 Plait 11-1-104 1H-104wP26 Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan'. 1H-104 Plan'. 54.1+39 Q 93.1Oust (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Plan Survey Tool Program Date 7/10/2018 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1,400.00 1H-104wp26(Plan: 1H-104) GYD-GC-SS Gyrodata gyro single shots 2 1,400.00 1,920.00 1H-104wp26(Plan: 11-1-104) MWD MWD - Standard 3 1,400.00 1,920.00 1H-104wp26 (Plan: 7H-104) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 1,920.00 3,420.00 1H-104wp26(Plan: 111-104) MWD MWD - Standard 5 1,920.00 9,465.00 1 H-1 04wp26 (Plan: 1 H-104) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6 9,465.00 10,965.00 1H-104wp26(Plan: 1H-104) MWD MWD - Standard 7 9,465.00 16,084.13 1 H-104wp26 (Plan: 1 H-104) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/102018 11.05.35AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips(Alaska) Inc.-Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-104 Wellbore: Plan: 11-1-104 Design: 1H-104wp26 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Schlumberger Standard Proposal Report Well Plan: 1 H-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NIS +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°1100usft) (°/100usft) (°) Target 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 0.00 450.00 3.00 114.67 449.91 -2.18 4.76 1.50 1.50 0.00 114.67 650.00 8.00 114.67 648.92 -10.18 22.17 2.50 2.50 0.00 0.00 1,643.16 32.83 114.67 1,572.44 -153.65 334.52 2.50 2.50 0.00 0.00 1,762.16 32.83 114.67 1,672.44 -180.58 393.14 0.00 0.00 0.00 0.00 1,918.25 37.51 114.67 1,800.00 -218.09 474.83 3.00 3.00 0.00 0.00 1,938.25 37.51 114.67 1,815.86 -223.18 485.89 0.00 0.00 0.00 0.00 2,837.04 73.41 112.19 2,317.21 -509.51 1,155.47 4.00 3.99 -0.28 -4.05 7,177.27 73.41 112.19 3.556.45 -2,080.42 5,006.97 0.00 0.00 0.00 0.00 8,007.91 79.00 78.42 3,760.02 -2,150.89 5,797.18 4.00 0.67 -4.07 -84.75 8,107.91 79.00 76.42 3,779.10 -2,131.19 5,893.34 0.00 0.00 0.00 0.001H-104 T01 D 06301 8,535.79 79.18 78.43 3,860.10 -2,046.88 6,304.95 0.04 0.04 0.00 2.79 1 H-104 T02 B 06301£ 8,897.66 67.72 73.05 3,983.10 -1,962.07 6,640.54 3.47 -3.17 -1.49 -156.48 1H-104 T03 A306301 9,103.58 75.20 75.52 4,028.56 -1,909.32 6,828.38 4.00 3.63 1.20 17.84 9,133.35 75.20 75.52 4,036.16 -1,902.13 6,856.25 0.00 0.00 0.00 0.00 9,468.44 89.00 75.24 4,082.10 -1,818.58 7,176.55 4.00 4.12 -0.09 -1.191H-104 TO4 Csg 063( 9,488.44 89.00 75.24 4,082.45 -1,813.48 7,195.89 0.00 0.00 0.00 0.00 9,616.45 89.73 70.17 4,083.87 -1,775.44 7,318.06 4.00 0.57 -3.96 -81.87 9,714.01 89.73 70.17 4,084.34 -1,742.35 7,409.83 0.00 0.00 0.00 0.00 10,393.34 90.08 43.00 4,085.50 -1,371.74 7,971.58 4.00 0.05 -4.00 -89.29 1H-104 LO 70106301 10,406.50 90.09 42.47 4,085.48 -1,362.08 7,980.50 4.00 0.11 -4.00 -88.47 10,926.47 90.09 42.47 4,084.63 -978.56 8,331.62 0.00 0.00 0.00 0.00 10,970.43 91.80 42.90 4,083.90 -946.25 8,361.42 4.00 3.88 0.97 14.01 1 H-104 LO T02 06301 11,064.53 92.85 39.28 4,080.08 -875.40 8,423.21 4.00 1.11 -3.85 -73.80 11,320.91 92.85 39.28 4,067.36 -677.20 8,585.33 0.00 0.00 0.00 0.00 11,427.81 92.79 35.00 4,062.10 -592.10 8,649.78 4.00 -0.05 -4.00 -90.64 1H-104 LO 70306301 11,468.75 92.96 33.37 4,060.05 -558.28 8,672.75 4.00 0.42 -3.98 -83.92 11,631.12 92.96 33.37 4,051.65 -422.86 8,761.94 0.00 0.00 0.00 0.00 12,065.61 92.00 16.00 4,032.70 -29.96 8,942.50 4.00 -0.22 -4.00 -92.771H-104 LO T0406301 12,242.85 91.64 8.91 4,027.07 142.92 8,980.69 4.00 -0.21 -4.00 -92.83 12,720.17 91.64 8.91 4,013.45 614.27 9,054.63 0.00 0.00 0.00 0.00 12,844.05 91.00 4.00 4,010.60 737.30 9,068.56 4.00 -0.51 -3.97 -97.301H-104 LO T0506301 12,865.64 90.35 3.43 4,010.35 758.84 9,069.95 4.00 -3.00 -2.65 -138.56 13,166.22 90.35 3.43 4,008.49 1,058.88 9,087.93 0.00 0.00 0.00 0.00 13,552.03 90.00 348.00 4,007.30 1,442.45 9,059.18 4.00 -0.09 -4.00 -91.281H-104 LO 70606301 13,757.86 81.83 349.04 4,021.95 1,643.47 9,018.34 4.00 -3.97 0.50 172.82 13,793.10 81.83 349.04 4,026.95 1,677.71 9,011.71 0.00 0.00 0.00 0.00 14,135.59 90.00 338.00 4,051.40 2,004.46 8,914.86 4.00 2.38 -3.22 -53.931H-104 LO 70706301 14,830.43 90.44 310.21 4,048.67 2,561.84 6,511.46 4.00 0.06 -4.00 -89.05 14,885.92 90.44 310.21 4,048.25 2,597.66 8,469.08 0.00 0.00 0.00 0.00 14,898.12 90.00 310.00 4,048.20 2,605.52 8,459.75 4.00 -3.61 -1.72 -154.581H-104 LO 70806301 15,213.06 91.01 297.44 4,045.40 2,780.01 8,198.34 4.00 0.32 -3.99 -85.35 16,084.13 91.01 297.44 4,030.00 3,161.38 7,425.41 0.00 0.00 0.00 0.00 1 H-104 LO T09 06301 7/10/2018 11.05: 35AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Database: DLS, 114.67° TF, for 200' OAKEDMP2 0.75 114.67 Company: 2.25 ConocoPhillips(Alaska) Inc.-Kupl Project: 3.00 Kuparuk River Unit Start 2.5°1100' DLS, 0° TF, for 200' (usft) Site: 4.25 Kupawk 1H Pad 600.00 6.75 Well: 650.00 Plan: 1H-104 114.67 Adjust TF to Wellbore: 0.00 Pian: 1H-104 9.25 114.67 Design: 11.75 1H-104wp26 900.00 14.25 Planned Survey 1,000.00 16.75 114.67 Measured 19.25 114.67 Vertical 21.75 Depth Inclination Azimuth 24.25 Depth 1,400.00 (usft) (^) (°) 1,500.00 (usft) 114.87 39.00 0.00 0.00 39.00 32.83 100.00 0.00 0.00 100.00 1,700.00 118.10 0.00 0.00 118.10 114.67 20" x 42" 2.50 0.00 1,762.16 32.83 200.00 0.00 0.00 200.00 33.96 25000 0.00 0.00 250.00 KOP: Start 1.5°1100' DLS, 114.67° TF, for 200' 300.00 0.75 114.67 400.00 2.25 114.67 450.00 3.00 114.67 Start 2.5°1100' DLS, 0° TF, for 200' (usft) 500.00 4.25 114.67 600.00 6.75 114.67 650.00 8.00 114.67 Adjust TF to 0°, for 993.16' 0.00 700.00 9.25 114.67 800.00 11.75 114.67 900.00 14.25 114.67 1,000.00 16.75 114.67 1,100.00 19.25 114.67 1,200.00 21.75 114.67 1,300.00 24.25 114.67 1,400.00 26.75 114.67 1,500.00 29.25 114.87 1,600.00 31.75 114.67 1,643.16 32.83 114.67 Hold for 119.01' -41.30 2.50 1,700.00 32.83 114.67 1,724.87 32.83 114.67 Base Pfrost 2.50 0.00 1,762.16 32.83 114.67 Start 3°1100' DLS, 0° TF, for 166.09' 1,800.00 33.96 114.67 1,900.00 36.96 114.67 1,918.25 37.51 114.67 Hold for 20'- 10 314" x 13 1/2" 185.67 1,936.03 37.51 114.67 T3 1,361.51 -103.25 1,938.25 37.51 114.67 Start 4°1100' DLS, A.06' TF, for 898.79' 2,000.00 39.98 114.40 2,100.00 43.97 114.01 2,200.00 47.96 113.68 2,266.31 50.61 113.48 KIS 0.00 1,572.44 2,300.00 51.95 113.39 2,400.00 55.95 113.12 2,500.00 59.94 112.88 2,600.00 63.94 112.66 2,700.00 67.93 112.45 2,800.00 71.93 112.26 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Schlumberger Standard Proposal Report Well Plan: 1H-104 Plan. 54.1+39 @ 93.1Oust (Doyon 142) Plan: 54.1+39 Q 93.10usft (Doyon 142) True Minimum Curvature 300.00 -0.14 Vertical Dogleg Build Tum +N/ -S +E/ -W Section Rate Rate Rate (usft) (usft) (usft) (°/100usft) (°1100us@) (°/100usft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 -0.14 0.30 -0.19 1.50 1.50 0.00 399.96 -1.23 2.68 -1.68 1.50 1.50 0.00 449.91 -2.18 4.76 -2.98 1.50 1.50 0.00 499.81 -3.50 7.63 -4.78 2.50 2.50 0.00 599.34 -7.50 16.34 -10.23 2.50 2.50 0.00 648.92 -10.18 22.17 -13.88 2.50 2.50 0.00 698.36 -13.31 28.98 -18.14 2.50 2.50 0.00 796.68 -20.92 45.54 -28.51 2.50 2,50 0.00 894.11 -30.31 65.98 -41.30 2.50 2.50 0.00 990.46 -41.46 90.27 -56.51 2.50 2.50 0.00 1,085.56 -54.36 118.35 -74.08 2.50 2.50 0.00 1,179.22 -68.97 150.17 -94.00 2.50 2.50 0.00 1,271.26 -85.28 185.67 -116.23 2.50 2.50 0.00 1,361.51 -103.25 224.79 -140.72 2.50 2.50 0.00 1,449.80 -122.84 267.45 -167.42 2.50 2.50 0.00 1,535.96 -144.03 313.57 -196.29 2.50 2.50 0.00 1,572.44 -153.65 334.52 -209.40 2.50 2.50 0.00 1,620.20 -166.51 362,52 -226.93 0.00 0.00 0.00 1,641.10 -172.14 374,77 -234.60 0.00 0.00 0.00 1,672.44 -180.58 393.14 -246.10 0.00 0.00 0.00 1,704.03 -189.27 412.07 -257.95 3.00 3.00 0.00 1,785.47 -213.48 464.79 -290.95 3.00 3.00 0.00 1,800.00 -218.09 474.83 -297.23 3.00 3.00 0.00 1,814.10 -222.61 484.66 -303.39 0.00 0.00 0.00 1,815.86 -223.18 485.89 -304.16 0.00 0.00 0.00 1,864.02 -239.22 521.04 -326.06 4.00 3.99 -0.44 1,938.35 -266.63 582,03 -363.64 4.00 3.99 -0.39 2,007.85 -295.68 647.77 403.67 4.00 3.99 -0.33 2,051.10 -315.78 693.83 431.47 4.00 3.99 -0.30 2,072.17 -326.23 717.95 -445.95 4.00 3.99 -0.28 2,131.01 -358.14 792.22 490.27 4.00 3,99 -0.26 2,184.07 -391.25 870.22 -536.42 4.00 3.99 -0.24 2,231.10 -425.40 951.58 -584.17 4.00 4.00 -0.22 2,271.87 460.41 1,035.88 -633.30 4.00 4.00 -0.21 2,306.17 -496,13 1,122.73 -683.56 4.00 4.00 -0.20 7/102018 11:05:35AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk I Pad Well: Plan: 1H-104 Wellbore: Plait 1H-104 Design: 1H-104wp26 Planned Survey Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Schlumberger Standard Proposal Report Well Plan: 1 H-104 Plan 54.1+39 @ 93.10usft (Doyon 142) Plan 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +NIS +EI•W Section Rate Rate Rate (usft) (^) (') (usft) (usft) (usft) (usft) (°I100usft) ('I100usft) ('1100usft) Hold for 4340.23' 2,900.00 73.41 112.19 2,335.18 -532.29 1,211.34 -734.55 0.00 0.00 0.00 3,000.00 73.41 112.19 2,363.74 -568.49 1,300.08 -785.61 0.00 0.00 0.00 3,100.00 73.41 112.19 2,392.29 -604.68 1,388.81 -836.66 0.00 0.00 0.00 3,200.00 73.41 112.19 2,420.84 -640.88 1,477.55 -887.72 0.00 0.00 0.00 3,300.00 73.41 112.19 2,449.39 -677.07 1,566.29 -938.77 0.00 0.00 0.00 3,400.00 73.41 112.19 2,477.95 -713.27 1,655.03 -989.82 0.00 0.00 0.00 3,500.00 73.41 112.19 2,506.50 -749.46 1,743.77 -1,040.88 0.00 0.00 0.00 3,600.00 73.41 112.19 2,535.05 -785.65 1,832.51 -1,091.93 0.00 0.00 0.00 3,700.00 73.41 112.19 2,563.60 -821.85 1,921.25 -1,142.98 0.00 0.00 0.00 3,800.00 73.41 112.19 2,592.16 -858.04 2,009.99 -1,194.04 0.00 0.00 0.00 3,900.00 73.41 112.19 2,620.71 -894.24 2,098.73 -1,245.09 0.00 0.00 0.00 4,000.00 73.41 112.19 2,649.26 -930.43 2,187.47 -1,296.15 0.00 0.00 0.00 4,100.00 73.41 112.19 2,677.81 -966.63 2,276.21 -1,347.20 0.00 0.00 0.00 4,200.00 73.41 112.19 2,706.37 -1,002.82 2,364.95 -1,398.25 0.00 0.00 0.00 4,300.00 73.41 112.19 2,734.92 -1,039.01 2,453.69 -1,449.31 0.00 0.00 0.00 4,400.00 73.41 112.19 2,763.47 -1,075.21 2,542.43 -1,500.36 0.00 0.00 0.00 4,500.00 73.41 112.19 2,792.02 -1,111.40 2,631.17 -1,551.42 0.00 0.00 0.00 4,600.00 73.41 112.19 2,820.58 -1,147.60 2,719.91 -1,602.47 0.00 0.00 0.00 4,700.00 73.41 112.19 2,849.13 -1,183.79 2,808.65 -1,653.52 0.00 0.00 0.00 4,800.00 73.41 112.19 2,877.68 -1,219.99 2,897.39 -1,704.58 0.00 0.00 0.00 4,900.00 73.41 112.19 2,906.23 -1,256.18 2,986.13 -1,755.63 0.00 0.00 0.00 5,000.00 73.41 112.19 2,934.79 -1,292.37 3,074.87 -1,806.69 0.00 0.00 0.00 5,100.00 73.41 112.19 2,963.34 -1,328.57 3,163.61 •1,857.74 0.00 0.00 0.00 5,200.00 73.41 112.19 2,991.89 -1,364.76 3,252.35 -1,908.79 0.00 0.00 0.00 5,300.00 73.41 112.19 3,020.44 -1,400.96 3,341.09 -1,959.85 0.00 0.00 0.00 5,400.00 73.41 112.19 3,049.00 -1,437.15 3,429.83 -2,010.90 0.00 0.00 0.00 5,414.37 73.41 112.19 3,053.10 -1,442.35 3,442.58 -2,018.24 0.00 0.00 0.00 UG_C 5,500.00 73.41 112.19 3,077.55 -1,473.35 3,518.57 -2,061.96 0.00 0.00 0.00 5,600.00 73.41 112.19 3,106.10 -1,509.54 3,607.31 -2,113.01 0.00 0.00 0.00 5,700.00 73.41 112.19 3,134.65 -1,545.73 3,696.05 -2,164.06 0.00 0.00 0.00 5,800.00 73.41 112.19 3,163.21 -1,581.93 3,784.79 -2,215.12 0.00 0.00 0.00 5,900.00 73.41 112.19 3,191.76 -1,618.12 3,873.53 -2,266.17 0.00 0.00 0.00 6,000.00 73.41 112.19 3,220.31 -1,654.32 3,962.26 -2,317.22 0.00 0.00 0.00 6,100.00 73.41 112.19 3,248.86 -1,690.51 4,051.00 -2,368.28 0.00 0.00 0.00 6,200.00 73.41 112.19 3,277.42 -1,726.71 4,139.74 -2,419.33 0.00 0.00 0.00 6,300.00 73.41 112.19 3,305.97 -1,762.90 4,228.48 -2,470.39 0.00 0.00 0.00 6,400.00 73.41 112.19 3,334.52 -1,799.09 4,317.22 -2,521.44 0.00 0.00 0.00 6,489.58 73.41 112.19 3,360.10 -1,831.52 4,396.72 -2,567.18 0.00 0.00 0.00 UG_B 6,500.00 73.41 112.19 3,363.07 -1,835.29 4,405.96 -2,572.49 0.00 0.00 0.00 6,600.00 73.41 112.19 3,391.63 -1,871.48 4,494.70 -2,623.55 0.00 0.00 0.00 6,700.00 73.41 112.19 3,420.18 -1,907.68 4,583.44 -2,674.60 0.00 0.00 0.00 6,800.00 73.41 112.19 3,448.73 -1,943.87 4,672.18 -2,725.66 0.00 0.00 0.00 6,832.81 73.41 112.19 3,458.10 -1,955.75 4,701.30 -2,742.41 0.00 0.00 0.00 UG_A 6,900.00 73.41 112.19 3,477.28 -1,980.07 4,760.92 -2,776.71 0.00 0.00 0.00 7,000.00 73.41 112.19 3,505.84 -2,016.26 4,849.66 -2,827.76 0.00 0.00 0.00 7,100.00 73.41 112.19 3,534.39 -2,052.46 4,938.40 -2,878.82 0.00 0.00 0.00 7,169.03 73.41 112.19 3,554.10 -2,077.44 4,999.66 -2,914.06 0.00 0.00 0.00 Na 7,177.27 73.41 112.19 3556.45 -2,080.42 5,006.97 -2,918.27 0.00 0.00 0.00 7/102018 11:05:35AM Page 6 COMPASS 5000.14 Build 85 ConoeoPhillips Schlumberger Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: OAKEDMP2 ConocoPhiilips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1 H Pad Plan: 1H-104 Plan: 1H-104 1H-104wp26 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan: 1H-104 Plan: 54.1+39 (M 93.10usft (Doyon 142) Plan: 54.1+39 Q 93.1 Ousit (Doyon 142) True Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg guild Tum Depth inclination Azimuth Depth +N/4 +E/ -W Section Rate Rate Rate (usft) (') (1 (usft) (usft) (usft) (usft) (-/100usft) ('/100usft) (°1100usft) Start4'/100' DLS, -84,75' TF, for 830.63' 7,200.00 73.50 111.24 3,562.93 -2,088.48 5,027.21 -2,929.72 4.00 0.38 -4.15 7,300.00 73.92 107.10 3,590.99 -2,120.00 5,117.85 -2,976.49 4.00 0.43 -4.14 7,400.00 74.42 102.98 3,618.28 -2,144.95 5,210.74 -3,017.20 4.00 0.50 -4.12 7,500.00 75.01 98.87 3,644.65 -2,163.22 5,305.43 -3,051.64 4.00 0.58 -4.10 7,600.00 75.66 94.79 3,669.98 -2,174.73 5,401.46 -3,079.64 4.00 0.65 -4.08 7,700.00 76.38 90.74 3,694.14 -2,179.41 5,498.37 -3,101.08 4.00 0.72 -4.05 7,800.00 77.17 86.71 3,717.03 -2,177.24 5,595.67 -3,115.84 4.00 0.79 -4.03 7,900.00 78.02 82.71 3,738.52 -2,168.23 5,692.90 -3,123.85 4.00 0.85 -4.00 8,000.00 78.93 78.73 3,758.51 -2,152.43 5,789.57 -3,125.08 4.00 0.91 -3.98 8,007.91 79.00 78.42 3,760.02 -2,150.89 5,797.18 -3,124.89 4.00 0.93 -3.96 Hold for 100' 8,100.00 79.00 78.42 3,777.59 -2,132.75 5,885.74 -3,122.39 0.00 0.00 OAO 8,107.91 79.00 78.42 3,779.10 -2,131.19 5,893.34 -3,122.18 0.00 0.00 0.00 Start 0.04.1100' DLS, 2.79' TF, for 427.88' 8,128.88 79.01 78.42 3,783.10 -2,127.06 5,913.51 -3,121.61 0.04 0.04 0.00 WS_D 8,200.00 79.04 78.42 3,796.64 -2,113.04 5,981.91 -3,119.69 0.04 0.04 0.00 8,300.00 79.08 78.42 3,815.62 -2,093.34 6,078.10 -3,116.99 0.04 0.04 0.00 8,350.07 79.10 78.42 3,825.10 -2,083.47 6,126.26 -3,115.63 0.04 0.04 0.00 WS -C 8,400.00 79.12 78.43 3,834.53 -2,073.63 6,174.30 -3,114.29 0.04 0.04 0.00 8,461.35 79.15 78.43 3,846.10 -2,061.55 6,233.32 -3,112.63 0.04 0.04 0.00 WS_e 8,500.00 79.16 78.43 3,853.37 -2,053.93 6,270.51 -3,111.59 0.04 0.04 0.00 8,535.79 79.18 78.43 3,860.10 -2,046.88 6,304.95 -3,110.63 0.04 0.04 0.00 Start 3.47'/100' DLS, -156.48' TF, for 361.87' 8,600.00 77.13 77.52 3,873.28 -2,033.79 6,366.41 -3,108.41 3.47 -3.18 -1.42 8,650.05 75.54 76.80 3,885.10 -2,022.98 6,413.82 -3,105.99 3.47 -3.18 -1.44 WS_A4 8,700.00 73.96 76.07 3,898.24 -2,011.67 6,460.67 -3,102.99 3.47 -3.17 -1.46 8,800.00 70.79 74.57 3,928.51 -1,987.53 6,552.85 -3,095.22 3.47 -3.16 -1.50 8,831.41 69.80 74.08 3,939.10 -1,979.54 6,581.32 -3,092.30 3.47 -3.16 -1.54 WS A3 8,897.66 67.72 73.05 3,963.10 -1,962.07 6,640.54 -3,085.38 3.47 -3.15 -1.57 Start4'/100' DLS, 17.84' TF, for 205.92' 8,900.00 67.81 73.08 3,963.99 -1,961.44 6,642.61 -3,085.12 4.00 3.81 1.32 9,000.00 71.62 74.37 3,998.65 -1,935.17 6,732.64 -3,074.88 4.00 3.81 1.29 9,100.00 75.07 75.49 4,027.31 -1,910.27 6,825.13 -3,066.42 3.62 3.46 1.12 9,103.58 75.20 75.52 4,028.56 -1,909.32 6,828.38 -3,066.05 3.62 3.46 1.10 Hold for 29.77' 9,117.45 75.20 75.52 4,032.10 -1,905.97 6,641.36 -3,065.00 0.00 0.00 0.00 WS A2 9,133.35 75.20 75.52 4,036.16 -1,902.13 6,856.25 -3,063.80 0.00 0.00 0.00 Start 4'/100' DLS, -1.19' TF, for 335.09' 9,200.00 77.86 75.47 4,051.69 -1,885.90 6,918.99 -3,058.72 4.00 4.00 409 9,300.00 81.86 75.38 4,069.28 -1,861.13 7,014.25 -3,050.87 4.00 4.00 -0.08 9,400.00 85.86 75.30 4,079.97 -1,835.98 7,110.42 -3,042.80 4.00 4.00 -0.08 9,468.44 89.00 75.24 4,083.04 -1,818.60 7,176.54 -3,037.16 4.59 4.58 -0.09 Hold for 20'- 7-518" x 9.7/8" 9,488.44 89A0 75.24 4,082.45 -1,813.48 7,195.89 -3,035.48 0.00 0.00 0.00 Start 41100' DLS, -81.87' TF, for 128.01' 7/10,2018 11:05:35AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupawk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-104 Wellbore: Plan: 1H-104 Design: iH-104wp26 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Schlumberger Standard Proposal Report Well Plan. 1 H-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 7/102018 11:05.35AM Page 8 COMPASS 5000.14 Build 85 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N1S +E1.W Section Rate Rate Rate (usft) (°) V) (usft) (usft) (usft) (usft) V1100usft) (`I100usft) (°1100usft) 9,500.00 89.07 74.78 4,082.64 -1,810.49 7,207.05 -3,034.48 4.00 0.57 -3.96 9,600.00 89.63 70.82 4,083.78 -1,780.93 7,302.55 -3,021.95 4.00 0.57 -3.96 9,616.45 89.73 70.17 4,083.87 -1,775.44 7,318.06 -3,019.24 4.00 0.57 -3.96 Hold for 97.56' 9,700.00 89.73 70.17 4,084.27 -1,747.10 7,396.65 -3,004.97 0.00 0.00 0.00 9,714.01 89.73 70.17 4,084.34 -1,742.35 7,409.83 -3,002.58 0.00 0.00 0.00 Start 4°1100' DLS, -89.29" TF, for 679.33' 9,800.00 89.77 66.73 4,084.71 -1,710.77 7,489.80 -2,985.37 4.00 0.05 -4.00 9,900.00 89.82 62.73 4,085.07 -1,668.09 7,580.21 -2,959.04 4.00 0.05 -4.00 10,000.00 89.87 58.73 4,085.34 -1,619.22 7,667.43 -2,926.05 4.00 0.05 4.00 10,100.00 89.93 54.73 4,085.51 -1,564.37 7,751.02 -2,886.56 4.00 0.05 4.00 10,200.00 69.98 50.73 4,085.60 -1,503.83 7,830.59 -2,840.75 4.00 0.05 4.00 10,300.00 90.03 46.73 4,085.59 -1,437.89 7,905.74 -2,788.86 4.00 0.05 4.00 10,393.34 90.08 43.00 4,085.50 -1,371.74 7,971.58 -2,735.15 4.00 0.05 4.00 Adjust TF to 58.47°, for 13.16' 10,400.00 90.09 42.73 4,085.49 -1,366.86 7,976.11 -2,731.13 4.00 0.11 4.00 10,406.50 90.09 42.47 4,085.48 -1,362.08 7,980.50 -2,727.19 4.00 0.11 4.00 Hold for 519.98' 10,500.00 90.09 42.47 4,085.33 -1,293.12 8,043.64 -2,670.23 0.00 0.00 0.00 10,600.00 90.09 42.47 4,085.16 -1,219.36 8,111.17 -2,609.32 0.00 0.00 0.00 10,700.00 90.09 42.47 4,085.00 -1,145.60 8,178.69 -2,548.41 0.00 0.00 0.00 10,800.00 90.09 42.47 4,084.83 -1,071.84 8,246.22 -2,487.50 0.00 0.00 0.00 10,900.00 90.09 42.47 4,084.67 -998.08 8,313.74 -2,426.59 0.00 0.00 0.00 10,926.47 90.09 42.47 4,084.63 -978.56 8,331.62 -2,410.46 0.00 0.00 0.00 Start 4°1100' DLS, 14.01° TF, for 43.96' 10,970.43 91.80 42.90 4,083.90 -946.25 8,361.42 -2,383.82 4.00 3.88 0.97 Adjust TF to -73.8', for 94.11' 11,000.00 92.13 41.76 4,082.89 -924.40 8,381.32 -2,365.76 4.00 1.11 -3.84 11,064.53 92.85 39.28 4,080.08 -875.40 8,423.21 -2,324.78 4.00 1.11 -3.85 Hold for 256.38' 11,100.00 92.85 39.28 4,078.32 -847.98 8,445.63 -2,301.67 0.00 0.00 0.00 11,200.00 92.85 39.28 4,073.36 -770.67 8,508.87 -2,236.51 0.00 0.00 0.00 11,300.00 92.85 39.28 4,068.40 -693.36 8,572.10 -2,171.36 0.00 0.00 0.00 11,320.91 92.85 39.28 4,067.36 -677.20 8,585.33 -2,157.74 0.00 0.00 0.00 Start 4.1100' DLS, -90.64' TF, for 106.9' 11,400.00 92.81 36.11 4,063.46 -614.70 8,633.62 -2,104.58 4.00 -0.05 4.00 11,427.81 92.79 35.00 4,062.10 -592.10 8,649.78 -2,085.13 4.00 -0.06 4.01 Adjust TF to -83.92°, for 40.94' 11,468.75 92.96 33.37 4,060.05 -558.28 8,672.75 -2,055.81 4.00 0.42 -3.98 Hold for 162.37' 11,500.00 92.96 33.37 4,058.43 -532.22 8,689.91 -2,033.12 0.00 0.00 0.00 11,600.00 92.96 33.37 4,053.26 -448.82 8,744.85 -1,960.52 0.00 0.00 0.00 11,631.12 92.96 33.37 4,051.65 -422.86 8,761.94 -1,937.93 0.00 0.00 0.00 Start 4°1100' DLS, 52.77° TF, for 434.49' 11,700.00 92.83 30.61 4,048.18 -364.52 8,798.38 -1,886.81 4.00 -0.20 4.00 11,800.00 92.62 26.62 4,043.43 -276.85 8,846.21 -1,808.78 4.00 -0.21 4.00 11,900.00 92.39 22.62 4,039.05 -186.05 8,887.82 -1,726.57 4.00 -0.22 4.00 12,000.00 92.16 18.62 4,035.08 -92.55 8,923.00 -1,640.60 4.00 -0.23 4.00 12,065.61 92.00 16.00 4,032.70 -29.96 8,942.50 -1,582.35 4.00 -0.24 4.00 Adjust TF to 52.83°, for 177.26' 12,100.00 91.93 14.63 4,031.52 3.19 6,951.58 -1,551.28 4.00 -0.20 4.00 12,200.00 91.73 10.63 4,028.33 100.71 8,973.42 -1,459.04 4.00 -0.21 4.00 12,242.85 91.64 8.91 4,027.07 142.92 8,980.69 -1,418.74 4.00 -0.21 4.00 7/102018 11:05.35AM Page 8 COMPASS 5000.14 Build 85 Schlumberger ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 1H-104 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Plan. 54.1+39 @ 93.10usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Site: Kupawk 1 H Pad North Reference: True Well: Plan: 1H-104 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-104 Vertical Design, 1H-104wo26 Tum Depth Inclination Azimuth 7/102018 11:05:35AM Page 9 COMPASS 5000.14 Build 85 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth -NIS +E/ -W Section Rate Rate Rate (usft) (^) (') (usft) (usft) (usft) (usft) ('M00usft) ('/100usft) ('1100usft) Hold for 477.31' 12,300.00 91.64 891 4,025.44 199.35 8,989.54 -1,364.70 0.00 0.00 0.00 12,400.00 91.64 8.91 4,022.59 298.10 9,005.04 -1,270.13 0.00 0.00 0.00 12,500.00 91.64 8.91 4,019.73 396.86 9,020.53 -1,175.57 0.00 0.00 0.00 12,600.00 91.64 8.91 4,016.88 495.61 9,036.02 -1,081.01 0.00 0.00 0.00 12,700.00 91.64 8.91 4,014.03 594.36 9,051.51 -986.45 0.00 0.00 0.00 12,720.17 91.64 8.91 4,013.45 614.27 9,054.63 -967.38 0.00 0.00 0.00 Start 4°1100' DLS, •97.3° TF, for 123.89' 12,800.00 91.23 5.75 4,011.46 693.42 9,064.81 -891.20 4.00 -0.51 -3.97 12,844.05 91.00 4.00 4,010.60 737.30 9,068.56 -848.63 4.00 -0.51 3.97 Adjust TF to -138.56', for 21.58' 12,865.64 90.35 3.43 4,010.35 758.84 9,069.95 -827.67 4.00 -3.00 -2.65 Hold for 300.58' 12,900.00 90.35 3.43 4,010.13 793.14 9,072.01 -794.25 0.00 0.00 0.00 13,000.00 90.35 3.43 4,009.52 892.96 9,077.99 -696.98 0.00 0.00 0.00 13,100.00 90.35 3.43 4,008.90 992.78 9,083.97 599.72 0.00 0.00 0.00 13,166.22 90.35 3.43 4,008.49 1,058.88 9,087.93 -535.31 0.00 0.00 0.00 Start 4°1100' DLS, -91.28' TF, for 385.81' 13,200.00 90.32 2.08 4,008.30 1,092.62 9,089.55 -502.36 4.00 -0.09 -4.00 13,300.00 90.23 358.08 4,007.81 1,192.60 9,089.69 -403.93 4.00 -0.09 -4.00 13,400.00 90.14 354.08 4,007.49 1,292.34 9,082.85 -304.51 4.00 -0.09 -4.00 13,500.00 90.05 350.08 4,007.32 1,391.37 9,069.08 -204.60 4.00 -0.09 4.00 13,552.03 90.00 348.00 4,007.30 1,442.45 9,059.18 -152.58 4.00 -0.09 4.00 Adjust TF to 172.82', for 205.83' 13,600.00 88.10 348.24 4,008.10 1,489.38 9,049.31 -104.64 4.00 -3.97 0.50 13,700.00 84.13 348.74 4,014.88 1,587.12 9,029.41 4.93 4.00 -3.97 0.50 13,757.86 81.83 349.04 4,021.95 1,643.47 9,018.34 52.48 4.00 -3.97 0.51 Hold for 35.24' 13,793.10 81.83 349.04 4,026.95 1,677.71 9,011.71 87.36 0.00 0.00 0.00 Start 4'1100' DLS, -63.93' TF, for 342.49' 13,800.00 81.99 348.81 4,027.92 1,684.42 9,010.40 94.19 4.00 2.36 -3.26 13,900.00 84.36 345.56 4,039.80 1,781.22 8,988.37 193.34 4.00 2.37 -3.25 14,000.00 86.75 342.34 4,047.55 1,877.01 8,960.82 292.47 4.00 2.39 -3.22 14,100.00 89.15 339.14 4,051.13 1,971.34 8,927.86 391.08 4.00 2.40 -3.20 14,135.59 90.00 338.00 4,051.40 2,004.46 8,914.86 425.96 4.00 2.40 -3.20 Adjust TF to 59.05', for 694.84' 14,200.00 90.04 335.42 4,051.38 2,063.62 8,889.39 488.64 4.00 0.07 4.00 14,300.00 90.11 331.42 4,051.24 2,153.04 8,844.67 584.47 4.00 0.07 4.00 14,400.00 90.17 327.43 4,051.00 2,239.12 8,793.81 678.07 4.00 0.07 4.00 14,500.00 90.24 323.43 4,050.64 2,321.44 8,737.07 768.99 4.00 0.06 4.00 14,600.00 90.30 319.43 4,050.17 2,399.60 8,674.73 856.79 4.00 0.06 4.00 14,700.00 90.36 315.43 4,049.59 2,473.22 8,607.09 941.04 4.00 0.06 4.00 14,800.00 90.42 311.43 4,048.90 2,541.95 8,534.49 1,021.34 4.00 0.06 4.00 14,830.43 90.44 310.21 4,048.67 2,561.84 8,511.46 1,044.92 4.00 0.06 4.00 Hold for 56.49' 14,885.92 90.44 310.21 4,048.25 2,597.66 8,469.08 1,087.56 0.00 0.00 0.00 Start 4'1100' DLS, -164.68' TF, for 12.2- 14,896.12 90.00 310.00 4,048.20 2,605.52 8,459.75 1,096.92 4.00 -3.61 -1.72 Adjust TF to 55.35', for 314.94' 14,900.00 90.01 309.93 4,048.20 2,606.73 8,458.31 1,098.36 4.00 0.32 -3.99 15,000.00 90.33 305.94 4,047.91 2,668.19 8,379.45 1,172.58 4.00 0.32 -3.99 15,100.00 90.65 301.95 4,047.05 2,724.02 8,296.51 1,241.96 4.00 0.32 -3.99 15,200.00 90.97 297.96 4,045.63 2,773.94 8,209.90 1,306.16 4.00 0.32 -3.99 7/102018 11:05:35AM Page 9 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-104 Wellbore: Plan: 11-1-104 Design: 1H-104wp26 Planned Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Schlumberger Standard Proposal Report Well Plan: 1H-104 Plan. 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft)' (°) (°) (usft) (usft) (usft) (usft) ('1100usft) (°/100usft) (`1100usft) 15,213.06 91.01 297.44 4,045.40 2,780.01 8,198.34 1,314.15 4.00 0.32 -3.99 Hold for 871.07' 15,300.00 91.01 297.44 4,043.87 2,820.07 8,121.19 1,366.99 0.00 0.00 0.00 15,400.00 91.01 297.44 4,042.10 2,866.15 8,032.46 1,427.78 0.00 0.00 0.00 15,500.00 91.01 297.44 4,040.33 2,912.22 7,943.73 1,488.57 0.00 0.00 0.00 15,600.00 91.01 297.44 4,038.56 2,958.30 7,854.99 1,549.35 0.00 0.00 0.00 15,700.00 91.01 297.44 4,036.79 3,004.38 7,766.26 1,610.14 0.00 0.00 0.00 15,800.00 91.01 297.44 4,035.02 3,050.46 7,677.53 1,670.93 0.00 0.00 0.00 15,900.00 91.01 297.44 4,033.26 3,096.54 7,588.79 1,731.72 0.00 0.00 0.00 16,000.00 91.01 297.44 4,031.49 3,142.62 7,500.06 1,792.50 0.00 0.00 0.00 16,084.13 91.01 297.44 4,030.00 • 3,181.38 7,425.41 1,843.64 0.00 0.00 0.00 TD: 16084.13' MD, 4030' TVD -4112" x 6 314" 7/10/2018 11:05:35AM Page 10 COMPASS 5000.14 Build 86 ConocoPhillips Database: 0AKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project Kupamk River Unit Site: Kuparuk 1 H Pad Well: Plan: 1H-104 Wellbore: Plan- 1H-104 Design: 1H-104wp26 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Schlumberger Standard Proposal Report Well Plan'. 1H-104 Plan'. 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Design Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W -Shape (') (') (usft) (usft) (usft) 1 H-104 T01 D 063018 R 0.00 0.00 3,779.10 -2,131.19 5,893.34 - plan hits target center - Circle (radius 100.00) 11-1-104 T02 B 063018 R 0.00 0.00 3,860.10 -2,046.88 6,304.95 - plan hits target center - Circle (radius 100.00) 1H-104 T03 A3 063018 1 0.00 0.00 3,963.10 -1,962.07 6,640.54 - plan hits target center - Circle (radius 100.00) 1H-104 LO T06 063018 1 0.00 0.00 4,007.30 1,442.45 9,059.18 - plan hits target center - Circle (radius 100.00) 1 H-104 LO T05 063018 1 0.00 0.00 4,010.60 737.30 9,068.56 - plan hits target center - Circle (radius 100.00) 1H-104 LO T09 063018 1 0.00 0.00 4,030.00 3,181.38 7,425.41 - plan hits target center - Circle (radius 1,320.00) 1H-104 1-0 T09 063018 1 0.00 0.00 4,030.00 3,181.38 7,425.41 - plan hits target center - Circle (radius 100.00) 1 H-104 LO T04 063018 1 0.00 0.00 4,032.70 -29.96 8,942.50 - plan hits target center - Circle (radius 100.00) 1 H-104 LO T04 063018 1 0.00 0.00 4,032.70 -29.96 8,942.50 - plan hits target center - Circle (radius 1,320.00) 1 H-104 LO T08 063018 1 0.00 0.00 4,048.20 2,605.52 8,459.75 - plan hits target center - Circle (radius 100.00) 1 H-104 LO T07 063018 1 0.00 0.00 4,051.40 2,004.46 8,914.86 - plan hits target center - Circle (radius 100.00) 1H-104 LO T07 063018 1 0.00 0.00 4,051.40 2,004.46 8,914.86 - plan hits target center - Circle (radius 1,320.00) 1 H-104 LO T03 063018 1 0.00 0.00 4,062.10 -592.10 8,649.78 - plan hits target center - Circle (radius 100.00) 1H-104 T04 Csg 06301E 0.00 0.00 4,082.10 -1,818.58 7,176.55 - plan misses target center by 0.94usft at 9468.49usft MD (4083.04 TVD, -1818.59 N, 7176.58 E) - Circle (radius 1,320.00) 1H-104 T04 Csg 06301 E 0.00 0.00 4,082.10 -1,818.58 7,176.55 - plan misses target center by 0.94usft at 9468.49usft MD (4083.04 TVD, -1818.59 N, 7176.58 E) - Circle (radius 100.00) 1 H-104 LO T02 063018 1 0.00 0.00 4,083.90 -946.25 8,361.42 - plan hits target center - Circle (radius 100.00) 1 H-104 LO T02 063018 1 0.00 0.00 4,083.90 -946.25 8,361.42 - plan hits target center - Circle radius 1,320.00) 7/10/2018 11:05:354M Page 11 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConowPhillips(Alaska) Inc.-Kupl Project: Kupamk River Unit Site: Kupamk I Pad Well: Plan: 1H-104 Wellbore: Plan: 111-104 1 H 104 26 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Schlumberger Standard Proposal Report Well Plan. 1H-104 Plait 54.1+39 @ 93.10usft (Dayan 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature Design. - �'P 1 H-104 LO T01 0630181 0.00 0.00 4,085.50 -1,371.74 7,971.58 5,979,215.00 1,697,580.00 70° 21' 15.230 N 149'32'8.849 W - plan hits target center - Circle (radius 100.00) Casing Points Vertical Depth Depth Measured Vertical (usft) Casing Hole Depth Depth 1,936.03 Diameter Diameter (usft) (usftl Name () ( ) 118.10 118.10 20"x42" 20 42 1,918.25 1,800.00 10 3/4" x 13 1/2" 10-3/4 13-1/2 9,468.44 4,083.04 7-5/8" x 9-7/8" 7-5/8 9-7/8 16,084.13 4,030.00 41/2"x63/4" 4-1/2 6-3/4 r Formations Measured Vertical Depth Depth (usft) (usft) 1,724.87 1,641.10 Base Pfrost 1,936.03 1,814.10 T3 2,266.31 2,051.10 K15 5,414.37 3,053.10 UG_C 6,489.58 3,360.10 UG_B 6,832.81 3,458.10 UG_A 7,169.03 3,554.10 Na 8,128.88 3,783.10 WS_D 8,350.07 3,825.10 WS_C 8,461.35 3,846.10 WS_B 8,650.05 3,885.10 WS—A4 8,831.41 3,939.10 WS—A3 9,117.45 4,032.10 WS—A2 Dip Dip Direction Name Lithology (1 (") 7110/2018 11:05:35AM Page 12 COMPASS 5000.14 Build 85 Schlumberger ConocoPh i I I i ps Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan1H-104 Company: Conoco Phillips (Alaska) Inc. -Kup1 TVD Reference: Plan'. 54.1+39 Q 93.10usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 54.1+39 Q 93.10usft (Doyon 142) Site: Kuparuk 1 H Pad North Reference: True Well: Plan: 1H-104 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1H-104 0.00 KOP: Start 1.5°/100' DLS, 114.67° TF, for 200' Design: 1H-104wp26 -2.18 4.76 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NIS +EI -W (usft) (usft) (usft) (usft) Comment 250.00 250.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 114.67° TF, for 200' 450.00 449.91 -2.18 4.76 Start 2.5°/100' DLS, 0° TF, for 200' 650.00 648.92 -10.18 22.17 Adjust TF to 0°, for 993.16' 1,643.16 1,572.44 -153.65 334.52 Hold for 119.01' 1,762.16 1,672.44 -180.58 393.14 Start 3"/100' DLS, 0° TF, for 156.09- 1,918.25 1,800.00 -218.09 474.83 Hold for 20' 1,938.25 1,815.86 -223.18 485.89 Start 4'1100' DLS,-4.05-TF, for 898.79' 2,837.04 2,317.21 -509.51 1,155.47 Hold for 4340.23' 7,177.27 3,556.45 -2,080.42 5,006.97 Start 4'1100' OILS, -84.75°TF, for 830.63' 8,007.91 3,760.02 -2,150.89 5,797.18 Hold for 100' 8,107.91 3,779.10 -2,131.19 5,893.34 Start 0.04°/100'DLS, 2.79- TF, for 427.88' 8,535.79 3,860.10 -2,046.88 6,304.95 Start 3.47°1100' DLS, -156.48° TF, for 361.87' 8,897.66 3,963.10 -1,962.07 6,640.54 Start 4'/100' DLS, 17.84° TF, for 205.92' 9,103.58 4,028.56 -1,909.32 6,828.38 Hold for 29.77' 9,133.35 4,036.16 -1,902.13 6,856.25 Start 4"/100'DLS,-1.19-TF, for 335.09' 9,468.44 4,082.10 -1,818.58 7,176.55 Hold for 20' 9,488.44 4,082.45 -1,813.48 7,195.89 Start 4'/100' DLS, -81.87' TF, for 128.01' 9,616.45 4,083.87 -1,775.44 7,318.06 Hold for 97.56' 9,714.01 4,064.34 -1,742.35 7,409.83 Start 4'1100' OILS, -89.29°TF, for 679.33' 10,393.34 4,085.50 -1,371.74 7,971.58 Adjust TF to 58.47', for 13.15' 10,406.50 4,085.48 -1,362.08 7,980.50 Hold for 519.98' 10,926.47 4,084.63 -978.56 8,331.62 Start 4'/100'DLS, 14.01"TF, for 43.96- 10,970.43 4,083.90 -946.25 8,361.42 Adjust TF to -73.8°, for 94.11' 11,064.53 4,080.08 -875.40 8,423.21 Hold for 256.38' 11,320.91 4,067.36 -677.20 8,585.33 Start 4'1100' DLS, -90.64' TF, for 106.9- 11,427.81 4,062.10 -592.10 8,649.78 Adjust TF to -83.92°, for 40.94' 11,468.75 4,060.05 -558.28 6,672.75 Hold for 162.37' 11,631.12 4,051.65 -422.86 8,761.94 Start 4'/100'OILS, -92.77°TF, for 434.49' 12,065.61 4,032.70 -29.96 8,942.50 Adjust TF to -92.83", for 177.25' 12,242.85 4,027.07 142.92 8,980.69 Hold for 477.31' 12,720.17 4,013.45 614.27 9,054.63 Start 4°/100' DLS, -97.3° TF, for 123.89' 12,844.05 4,010.60 737.30 9,068.56 Adjust TF to -138.56*, for 21.58' 12,865.64 4,010.35 758.84 9,069.95 Hold for 300.58' 13,166.22 4,008.49 1,058.88 9,087.93 Start 4°/100'OILS, -91.28°TF, for 385.81' 13,552.03 4,007.30 1,442.45 9,059.18 Adjust TF to 172.82°, for 205.83' 13,757.86 4,021.95 1,643.47 9,018.34 Hold for 35.24' 13,793.10 4,026.95 1,677.71 9,011.71 Start 4°/100' DLS, -53.93° TF, for 342.49' 14,135.59 4,051.40 2,004.46 8,914.86 Adjust TF to -89.05', for 694.84' 14,830.43 4,048.67 2,561.84 8,511.46 Hold for 55.49 14,885.92 4,048.25 2,597.66 8,469.08 Start 41100' DLS, -154.58° TF, for 12.2' 14,898.12 4,048.20 2,605.52 8,459.75 Adjust TF to -85.35', for 314.94' 15,213.06 4,045.40 2,780.01 8,198.34 Hold for 871.07' 16,084.13 4,030.00 3,181.38 7,425.41 TD: 16084.13' MD, 4030' TVD 7/10/2018 11:05.35AM Page 13 COMPASS 5000.14 Build 85 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Plan: 111-1-104 Plan: 1 H-104 500292360600 1 H-104wp26 ConocoPhillips Clearance Summary Anticollision Report 03 July, 2018 Tay. cylinder North Proalmny scan on current survey Data INorth Reference) Reference Design: Bupamk 1H Pad -Plan: 1H -104 -Plain 111-104-1H-104wp36 Well coordinates. Datum Height: Plan: 54.1+39@ 93.10usR loayon 1421 Scan Range: 0.00 to 16004.13 usR. Measured Depth. Scan Radius is 1,904.51 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIED. All wellptiths vnthin 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips ConocoPhillips Anticollision Report for Plan: 1H-104 -1 H-104wp26 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) 211.23 1,8a8.30 164.28 ReferenceDesign: Kuparuk lH Pad -Plan: 1H404 -Plan: 11,1404-11-1-104vry26 4,499 Clearance Factor Pass - Scan Range: 0.00 to 16,084.13 usft. Measured Depth. 1,844.63 211.23 1,844.63 Scan Radius is 1,804,51 usft. Clearance Factorcutafl is Unlimited. Max Ellipse Separation is Unlimited 1.925.00 4.501 Measured Minimum @Measured Ellipse @Measured Clearance Summary Basad on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design just) (usft) (ust) (Us") usft Kuparuk 1H Pad 1 H45- iH-05-11-05 1 H45 -1H-105-11-105 11-101 -1H-101 - 111-101 1H-101 -1 11-101 -1H-101 1H -101 -i11 -101L1 -1H-1011_1 111401-111-101Li-1H-10111 iH-101-11-1-1011-2-111-1011-2 11 -101 -1H -1011-2-1H-1011-2 11-1-101 -1H-1011-3-1H-10113 111-101 -1H-1011-3-1H-10113 111-101 -1H-1011.4-1H-101L4 11-1-101-1141011-4-lWl O1L4 1H-102 -111-102- IH -102 1WI02-11-1-102-11-102 IH -102 -1H -102L1 -1H -102L1 1H -102 -1H -1021_1 -1H -102L1 1H -102 -1H -1021.2 -1H -102L2 1H -102 -1H -102L2 -1H-1021-2 111-102 -1H-102L3 -1H-1021-3 1H-102-11-1-10213-1HA021-3 1H-102-1 HA 02L4-iH-1021_4 1H -102 -1H -1021_4-1H-102 L4 iH-103 -1H-103 -1H-103 1H-103 -1H-103 -1H-103 1H -103 -1H -1031-1-1H-1031_1 1H-103-114103LI-1H-103L1 1H -103-1141031-2-1H-10312 1H -103 -1H -1031_2-1H-1031_2 1,846.30 211.23 1,8a8.30 164.28 1,925.00 4,499 Clearance Factor Pass - Major Risk 1,844.63 211.23 1,844.63 164.30 1.925.00 4.501 Clearance Factor Pass - Major Risk 125.01 180.24 125.01 178.00 125.00 80.209 Centre Distance Pass - Major Risk 225.00 181.11 225.00 177.17 225.00 45.895 Clearance Factor Pass - Major Risk 125.01 180.24 125.01 178.00 125.00 80.209 Centre Distance Pass - Major Risk 225.00 181.11 225.00 177.17 225.00 45.895 Clearance Factor Pass - Major Risk 125.01 180.24 125.01 176.00 125.00 00.209 Cenbe Distance Pass - Major Risk 225.00 101.11 225.00 177.17 225.00 45.895 Clearance Factor Pass - Major Risk 125.01 180.24 125.01 178.00 125.00 80.209 Centre Distance Pass - Major Risk 228.00 181.11 225.00 1]7.17 225.00 45.895 Clearance Factor Pass - Major Risk 125.01 180.24 125.01 178.00 12500 80.209 Centre Distance Pass - Major Risk 225.00 181.11 225.00 177.17 225.0) 45.895 Clearance Factor Pass - Major Risk 100.48 120.13 100.48 117.05 100.00 38.927 Centre Distance Pass - Major Risk 5,864.68 227.11 5,884.68 110.63 6.125.00 1.950 Clearance Factor Pass - Major Risk 100.48 120.13 100.48 117.05 100.00 38,927 Centre Distance Pass - Major Risk 5,854.68 227.11 5.864.88 110.63 6,125.00 1.950 Clearance Factor Pass - Major Risk 100.48 120.13 1WA8 117.05 100.00 38.927 Centre Distance Pass - Major Risk 5,864.68 227.11 5,884.88 110.63 6,125.00 1.950 Clearance Factor Pass - Major Risk 100.48 120.13 100.48 117.05 100.00 38.927 Centre Distance Pass - Major Risk 5.864.68 227.11 5,864.68 110.63 6,125.00 1.950 Clearance Fador Pass - Major Risk 100.48 120.13 100.48 117.05 100.00 38.927 Centre Distance Pass - Major Risk 5,864.68 227.11 5,864.68 110.63 6,125.00 1.950 Clearance Factor Pass - Major Risk 50.07 60.05 50.07 57.30 50.00 21.797 Centre Distance Pass - Major Risk 300.46 61.24 300.46 55.20 300.00 10.128 Clearance Factor Pass - Major Risk 50.07 60.05 50.07 57.30 50.00 21.797 Centre Distance Paas - Major Risk 300.46 61.24 300.46 55.20 30000 10.128 Clearance Factor Pass - Major Risk 5007 60.05 50.07 57.30 50.00 21.797 Centre Distance Pass - Major Risk 300.46 61.24 300.46 55.20 300.00 10.128 Clearance Factor Pass -Major Risk 0 &* Ma - 11:19 Page 2016 COMPASS ConocoPhillips ConocoPhillips (Alaska) Inc. -11I Kuparuk River Unit Anticollision Report for Plan: 1 H-104- I H-104wp26 Tran. Cylinder Nonk Proximity Stan on Comm Survey Data Worth Reference) ReferenceDeslgn: KupamklHPad-PMn:1H-104-M.n:lH404-1H-104"26 Scan Range: 0.00 to 16,084.13 usft. Measured Deptk. Sean Radius is 1,804.51 usft. Clearance Factor cutoff is Unlimited Max Ellipse Separation Is Unlimited Measured Minimum ®Measured Ellipse QMeasumd CWrence Summary Based an gatherers Depth Distance Depth separation Depth Faster Minimum Separation Warring Comparison Well Name -Wellbore Name -Design (usft) )usft) (usft) jua11) usft 1 HA 03-1 K103L3-iH-103L3 50.07 60.05 50.07 57.30 50.00 21397 Centre Distance Pass - Major Risk 1H -103-1H-1031 1rfHl03L3 300.46 61.24 300.46 55.20 300.00 10.128 Clearance Fadar Pass - Major Risk 1H -103 -1H -10314-1H-10314 50.07 60.05 50.07 57.30 50.00 21.797 Centre Distance Pass - Major Risk IH -103 -1H -1031.4-1H-10314 301 61.24 300.46 55.20 300.00 10.128 Clearance Factor Pass - Major Risk IH -100 -1H -100-1H-108 576.01 29.25 576.01 19.65 575.00 3.048 Centre Distance Pass - Major Risk 1H -100 -1H -108-1H-108 675.77 30.06 675.77 18.74 675.00 2.655 Clearance Faaor Pass - Major Risk 1H -100 -IH -108-1H-108 576.01 29.25 576.01 19.65 575.00 3.046 Centre Distance Pass - Major Risk 1H -108 -1H -108-1H-108 61 30.06 675.77 18.74 675.00 2.655 Clearance Factor Pass - Major Risk 1H -100 -1H -108A -1H -109A 576.01 29.25 576.01 19.65 575.00 3.046 Centre Distance Pass - Major Risk 1H -100 -1H -108A -1H -108A 675.77 30.06 675.77 10.74 675.00 2.655 Clearance Factor Pass - Major Risk 1H -100 -1H -108A -1H -108A 576.01 29.25 576.01 19.65 575.00 3046 Centre Distance Pass - Major Risk 1H-100-1 1+108A- 11-1-108A 675.77 30.08 675.77 10.74 675.00 2.655 Clearance Factor Pass - Major Risk 1H -t00 -Plan: 1H -108B -1H-1080 u,04 576.01 29.25 576.01 19.65 575.00 3.046 Centre Distance Pass - Major Risk 11 -1 -108 -Plan: 1H-1a8B-1H-1088w04 67537 30.08 67537 18.74 675.00 2.655 Clearance Factor Pass - Major Risk 1H -108 -Plan: l H40813 -1H-1088 ,04 576.01 29.25 576.01 19.65 575.00 3.046 Centre Distance Pass - Major Risk 11 -1 -108 -Plan: 1&10813-1H-108Bwp04 675.77 30.06 675.77 18.74 675.00 2.655 Clearance Factor Pass - Major Risk 1 HA 09 -IH -109-1H-109 548.71 29.32 540]1 18.19 550.00 2.635 Centre Distance Pass - Major Risk 1H -109 -1H -109-1H-109 722.14 30.39 722.14 16.77 725.00 2.231 Clearance Factor Pass - Major Risk 1H -110 -1H -110-1H-110 597.29 50.17 597.29 47.96 600.00 5]00 Centre Distance Pass - Major Risk 1H -110 -1H -110-1H-110 896.31 50.90 696.31 46.93 700.00 4.919 Clearance Factor Pass - Major Risk IH -111 -1H -111-1H-111 250.37 89.13 250.37 84.76 250.00 20.400 Centre Distance Pass - Major Risk 1H -111-1H-111-11-111 349.24 8937 349.24 83.85 350.00 15.171 Clearance Factor Pass - Major Risk IH -113 -1H -113-1H-113 495.15 149.26 495.15 14o.80 500.00 17.840 Centre Distance Pass - Major Risk IH -113 -1H -113-1H-113 592.49 149.74 592.49 139.73 600.00 14.959 Clearance Factor Pass - Major Risk IH -114 -1H -114-1H-114 50.16 179.94 50.16 177.59 50.00 76.518 Centre Distance Pass - Major Risk 1H -114-1H-1141 H-114 299.05 101.66 299.05 176.44 300.00 34.801 Clearance Factor Pass - Major Risk 1H -116 -1H -116-1H-116 322.78 238.70 322.78 232.24 325.00 36.952 Centre Distance Pass - Major Risk 1H -116 -1H -116-1H-116 444.19 239.97 444.19 231.11 45D.00 21094 Clearance Factor Pass - Major Risk 1H -12 -IH -12-11-12 2,29843 374.84 2.298.43 312.58 2,350.00 6.037 Centre Distance Pass - Major Risk 1H -12-1H-12-11-12 2.316.67 374.78 2,316.67 31238 2,375.00 5.997 Clearance Factor Pass - Major Risk 03 July, 2018 - 11:19 Pags 9 oI6 COMPASS ConocoPhillips ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Anticollision Report for Plan: 1 H-104- I H-104wp26 3.763.69 Tra,, Cylinder North Proximity Sun on Current Survey Data (North Reference) 3,763.69 113.91 Reference Design: KupvuklHPad-Plan:iH404-PIan:1H-104-1H-104wp26 2.062 Clearance Factor Pass - Scan Range: 0.00 to 16,084.13 sea. Measured Depth. 1 Wl3-1WI3-1HFI 3 Scan Radius is 1,804.51 usti. Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited 221.01 3,785.42 Measured Minimum @Measumd Ellipse jaMeasured Clearance Summary Based on Slh Name Depth Distance Depth separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (until hivin (tan) (unti) usR 18-13-VIA3-1H-13 3.763.69 221A3 3,763.69 113.91 $550.00 2.062 Clearance Factor Pass - Major Risk 1 Wl3-1WI3-1HFI 3 3.786.42 221.01 3,785.42 114.17 3,575.00 2.069 Centre Dislance Pass - Major Risk 11-1401(UGNU)-11-1401-1H401 1,292.44 156.64 1,292.44 124.41 1,425.00 4.861 Centre Distance Pass - Major Risk 1H401(UGNU)-11-1401-1H401 1,W765 157.05 1,307.65 123.70 1,450.00 4.710 Clearance Factor Pass - Major Risk Plan: 11 -1 -115 -Plan: 1H-115-iH-115w,22 250.00 209.83 250.00 205.37 250.00 46.953 Centre nuance Pass - Major Risk Plan r 11 -1 -115 -Plan: 1H-115-iH-115w,22 371.77 210.79 371.77 204.35 375.00 32.733 Clearance Factor Pass - Major Risk Survey, tool program From To SurveylPNn Survey Tool (usn) (usn) 39.00 1,400.00 1HA04wp26 GYMS 1,400.00 1,920.00 1H-104,,26 MWD 1,400.00 1,920.00 11-1-104„26 MWD+IFR-AK-CAZSC 1.920.00 3,420.00 1H-104„26 MWD 1,920.00 9,465.00 1H-104scp26 MWD+IFR-AK-CAZSC 9,465.00 10,9115.00 1H -104,p26 MWD 9465.00 16,084.13 11-1-104,,28 MWD+IFR-AK-CAZSC Ellipse error terns are correlated across survey tool We n points. Calculated ellipses Incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Beessen cannon is the straight line distance been wdlium centres. Clearance Factor= Distance Between Profiles I (Distance BeNreen Phonies- Ellipse Separation). All station moldinales mm calculated using the Minimum CmvaWre method. N Jing 2013 - 11:19 Pape 4 of6 COMPASS fl m JNy U3 YOtB 1 H-104wp26 Ladder View a N n mM K S V O2O O �Q 300 d 'I I i I , �ZOOa I 1 'I o I °x'100 c a� U 0 0 2500 5000 7500 10000 12500 15000 17500 Measured Depth SURVEY PROGRAM CASING DETAIL Depth Fro®epth To Survey/Plan Tool TVD MD Name 39.00400.00 1H-104wp26(Plan:1H©'OkGC-SS 118.10118.10 20"x42" 1400.00920.00 1H-104wp26 (Plan: 1HM9ip 1800.1W8.25 10 3/4" 1400.00920.00 1H-104wp26 (Plan: 1HMVQ+IFR-AK-CAZ-SC 4083.9468.447-5/8" x 9-7/8" 1920.00420.00 1 H-104wp26 (Plan: 1 HMUIq 4030.®084.134 1/2" x 6 3/4" 1920.09465.00 1H-104wp26 (Plan: 1HM7Q+IFR-AK-CAZ-SC 9465.00965.00 1H-104wp26 (Plan: 1HMWP 9465.06084.13 1H-104wp26 (Plan: 1HMVAd +IFR-AK-CAZ-SC M J M J M J ^ T p Q O M O 2 N \1 O m O O c060— m n I � d U y c w o �I. ac) 0 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth h NNW I 1 H-104wp26 TC View SURVEY PROGRAM MD Inc Azi TVD Dleg TFace Target Annotation epth FrolBepth To Tool 39.00 50.00 0.00 0.00 0.00 0.00 39.00 250.00 0.00 0.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 114.67° TF, for 39.001400.00 GYD-GC-SS 50.00 3.00 114.67 449.91 1.50 114.67 Start 2.5°/100' DLS, 0° TF, for 200- 00'1400,001920.00 1400,001920.00MWD 50.00 8.00 114.67 648.92 2.50 0.00 Adjust TF to 0-, for 993.16' 1400.001920.00 MWD+IFR-AK-CAZ-SC 43.16 62.16 32.83 32.83 114.67 114.67 1572.44 1672.44 2.50 0.00 0.00 0.00 Hold for 119.01' Start 3°/100' DLS, 0° TF, for 156.09' 1920.003420.00 MWD 18.25 37.51 114.67 1800.00 3.00 0.00 Hold for 20' 1920,0 465.00 MWD+IFR-AK-CAZ-SC 38.25 37.51 114.67 1815.86 0.00 0.00 Start 4°/100'DLS,-4.05°TF, for 898.79' 37.04 73.41 112.19 2317.21 4.00 -4.05 Hold for 4340.23' 9465.0LD965.00 MWD 77.27 73.41 112.19 3556.45 0.00 0.00 Start 4*1109 DLS,-84.75' TF, for 830.63' 9465.003084.13 MWD+IFR-AK-CAZ-SC 07.90 79.00 78.42 78.42 3760.02 3779.10 4.00 0.00 -84.75 0.00 1 H-104 T01 D 063016 RP Hold for 100' Start 0.04°/100' DLS, 2.79° TF, for 427.88' 07.90 35.79 79.00 79.18 78.43 3860.10 0.04 2.79 1 H-104 T02 B 063018 RP Start 3.47°/100' DLS, -156.48° TF, for 361 97.66 67.72 73.05 3963.10 3.47 -156.48 1 H-104 T03 A3 063018 RP Start 4°/100' DLS, 17.84° TF, for 205.92' 03.58 75.20 75.52 4028.56 4.00 17.84 Hold for 29.77' 33.35 75.20 75.52 4036.16 0.00 0.00 Start 4°/100' DLS, -1.19° TF, for 335.09' 68.44 89.00 75.24 4082.10 4.00 -1.19 1 H-104 T04 Csg 063018 RP Hold for 20' 8844 89.00 75.24 4082.45 0.00 0.00 Start 4°/100' DLS, -81.87° TF, for 128.01' 16.45 89.73 70.17 4083.87 4.00 -81.87 Hold for 97.56' 14.01 93.34 89.73 90.08 70.17 43.00 4084.34 4085.50 0.00 4.00 0.00 -89.29 1 H-104 LO T01 063018 RP Start 4°/100' DLS, -89.29° TF, for 679.33' Adjust TF to -88.47°, for 13.15' CASING ETAI L 06.49 26.47 70.43 90.09 90.09 91.80 42.47 42.47 42.90 4085.48 4084.63 4083.90 4.00 0.00 4.00 -88.47 0.00 14.01 1H-104 LO 702063018 RP Hold for 519.98' Start 4°/100' DLS, 14.01° TF, for 43.96 Adjust TF to-73.8°, for 94.11' TVD MD Name 64.53 92.85 39.28 4080.08 4.00 -73.80 Hold for 256.38' 115.10 118.10 20" X 42" 20.91 92.85 39.28 4067.36 0.00 0.00 Start 4°/100' DLS, -90.64° TF, for 106.9' 1800.001918.25 10 3/4" 27.81 92.79 35.00 4062.10 4.00 -90.64 1H-104 LO T03063018 RP Adjust TF to-83.92°, for 40.94' 68.75 92.96 33.37 4060.05 4.00 -83.92 Hold for 162.37' 4083.049468.44 7-5/$" X 9-7/$ 31.12 92.96 33.37 4051.65 0.00 0.00 Start 4°/100' DLS, -92.77° TF, for 434.49' 4030.006084.13 41/2"x63/4" 65.61 92.00 16.00 4032.70 4.00 -92.77 1H-104 LO T04063018 RP Adjust TF to-92.83°, for 177.25' 42.85 91.64 8.91 4027.07 4.00 -92.83 Hold for 477.31' 20.17 91.64 8.91 4013.45 0.00 0.00 Start 4°/100' DLS, -97.3° TF, for 123.89' 44.05 91.00 4.00 4010.60 4.00 -97.30 1H-1G4 LO T05 063018 RP Adjust TF to -138.56°, for 21.58' 65.64 90.35 3.43 4010.35 4.00 -138.56 Hold for 300.58' 66.22 90.35 3.43 4008.49 0.00 0.00 Start 4°/100' DLS, -91.28° TF, for 385.81' 52.03 90.00 348.00 4007.30 4.00 -91.28 1 H-104 LO TOB 063018 RP Adjust TF to 172.82°, for 205.83' 57.86 81.83 349.04 4021.95 4.00 172.82 Hold for 35.24' 939�.SSB8.88 3400 4026.95 0.00 0'-98.44 Start 4°/100'DLS, -53.93°TF, for 342.49' 14830.43 90.44 01021 4048.67 4.00 -89.05 Hold for 55. 9' 14885.92 4048.25 0.00 0.00 Start 4°/100' OLS, -154.58' TF, for 12.2' ih 0 4.00 A54.58 1FF104LOT08063018RP Adjust TF to 85.35', for 314.94' 1H-111 �� 'i; 1'I',,I .00 -85.W Hol1 for 871 O I ,I •, I,! 5W HAA LOT09063018 RP TD: 16084A MD, 4030'TVD 330 i H-109 IH-113 r� 39 250 IH-110 250 -440 440 -640 300 ' � 60 640-830 . 830 - 1020 1020- 1220 1220 - 1410 1410 1600 11H. 1600 - 2200 2200 2$00 2800 - 3400 270 90 3400 - 4000 1 H-108A 4000 - 4600 4600 - 5200 1H-�Q 5200 - 5800 H-1 F 5800 - 6400 1 H-1086 / 6400 - 7610 -" 7610 - 8820 240' 120 8820 - 10030 10030 - 11240 11240 - 12450 12450 13660 1H-103L 1 ,• ,R 13660 _- 14870 14870 - 16084 H-103L1 21 150 1H-103L 180 1 H-104wp26 39.00 To 16084.13 AC Wells Only 1H -102L3 500 1H -108B wp04 AC Flipbook 1145. gory m w+e 1 H-104wp26 39.00 To 1000.00 AC Flipbook SURVEY PROGRAM 39 250 pth FronDepth To Tool 111 39.001400.00 GYD-GC-SS 1H 250-440 1400.00 1920.00 MWD 0 1H-110 1400.001920.00 MWD+IFR-AK-C `, 440-640 1920.00 3420 00 MWD ,Y� g0 1920.00 9465.00 MWD+IFR-AK-C 330 30 640 -830 9465.000965.00 MWD 9465.006084.13 MWD -IFR -AK -CX 830-1020 1H-109 :=a. 1020 1220-1410 1220 CASING DETAILS TVD MD Name 118.10 118.10 20" x 42^ 300 60 - 1800.001918.2510 314^ x 13 1/2" 1410 1600 4083.049468.44 7-58" x 9-718" 4030.005084.13 4112° x 6 314" I.'... 1600 2200 -2200 2800 .DTF.. ]9.00 000 0.00 3"' 0 2 000 00 460. W 1+4.67 11467 65000 11467 0.002800 1643.+6 11467 ON 00 - 3400 62 16 000 191825 11467 000 iei ni 1122.ae 11' 1 H-108 3400 - 4000 717727 n21e 0.00 600290 7042 -eus 270 1 H-108 ' g0 810790 78 42 0.00 8535.79 7843 279 4000 - 4600 8897 85 7305 -158.48 9I 9]].36 75.52 10.00 1H-108 ` 4600-5200 946644 7524 -1.19 4 7524 000 961441 7017 4187 W1645 70:11 400 1H-108 -1085200 - 5800 10300 4300 -0913 +04oa49 4247 -08.47 +0926.47 424700018 43 1097043 42.90 1401 wp0 5800 6400 1'970 3928 -73M 1132091 3920 003' 1142781 3100 -9o.0 6400 - 7610 11480.75 3337 d3 B2 1183t12 3337 0.00 12065.61 1800 9271 1H -108B wp 240 120 1224285 891 A283 7610 8820 1v2017 0.91 0w +2611405 400 9730 1268584 343 -13056 131 68.22 343 0. 00 8820 - 1003 13352 03 348 W 41.28 1375] 06 349 04 172.82 13793.10 34904 000 14136.59 33800 6393 10030 1124 148M 43 31021 -8905 148M 92 310.21 000 14896.12 310.00 -154.56 11240 - 1245 160844:13 29 44 -fio. 210 150 '- 12450 1366 lap �� 1H -103L _ 13660 1487 1H -103L H -103L1 1H -103L 14870 1608 1 H-104wp26 900.00 To 2000.00 AC Flipbook SURVEY PROGRAM 39 250 pth FronDepth To Tool 39.001400.00 GYD-GC-SS t H-110 250 440 1400.001920.00 MWD 1400.001920.00 MWD+IFR-AK-C 440-640 1920.003420.00 MWD 1920.009465.00 MWD+IFR-AK-C 330 �� 30 640-830 9465.000965.00 MWD 9465.006084.13 MWD+IFR-AK-C 1H•tos 830- 1020 1020 1220 -1220 -1410 CASING DETAILS' TVD MD Name 118.10 118.10 20• x 42• 300 60 1800.001918.2510 3/4" x 13 1/2" 1410-1600 4083.049468.44 75/8" x 9-7/8" 4030.005084.13 4 1/2" x 6 3/4" 3 1600 2200 - 2200 2800 MD KI TFem 3800 0.00 000 2Woo 467 oW 470 W 11447 7477 6643 114.667 000 1743.166 11a667 0.oWW 2800-3400 1]82.17114667 OM 191825 114 67 0 W 190825 1126. 40' 3400 -4000 717]27112.19 000 700780 78.x2 84.75270 810790 7842 0.00 4000 -4600 90 089]:766 78.43 5 -15667466 t H-108 9103.668 75 W 7.84 913335 75.52 000 4600-5200 9466844 75.24 -1.19 7017 1H-10 N16445 -8187 971401 7017 0,00 5200 - 5800 1039334 43 o' -8929 to4W.49 4247 -88.47 1H-108 ' 30 100266.47 42.47 o.W 1097043 42901 5800 -6400 11084.53 3828 73.80 1132.91 3928 DA 142781 35.00 -90664 1H-108 �' 6400 - 7610 11468.75 3337 43.92 1163112 33.37 o. H408Wwp 120 1208561 16.00 -gin 1224285 881 -9293 7610 - 8820 1270,17 791 0.03 12844.05 a00 9730 H-1086 wp0 1277564 343-13850 1317822 343 0.00 60 8820 V V 1003 1357203 3d8.W Al2. 13757.86 34804 172.72 1379310 34904 0.00 3133.59 338.00 -5393 10030 - 1124 14030.43 31021 -0905 14885.92 310.21 00 148M 12 310 Do -1-65 11240 - 1245 1 WU 13 20744 oW 21Q 50 12450 1366 13660 ---14870 1H -103L 1H -103L 14870-1608 H -103L1 1H -103L2 1 H-104wp2E 1)00.00 To 16085.00 AC Flipbook SURVEY PROGRAM - 39 25O pM FrorrDepth To Tool 39 001400.00 GYD-GC-SS 250-440 14W00 92000 MWD 0 1400 001920.00 MWD-IFR-AK-Cg440 640 1920 003420.00 MWD 1920.009465.00 MWD+IFR-AK-C 330 30 640-830 9465.000965.00 MWD 9465006084.13 MWD -IFR -AK -CX 830-1020 60 1020-1220 1220-1410 CASING DETAILS TVD MD Name 118.10 118.10 20" x 42" 60 1800.001918.2510 3/4" x 13 1/2" 1410- 1600 4083.00.9468.44 75/8" x 9-7/S /300 4030.005084.13 41/2"x6314" 30 1600-2200 2200 2800 MO P T 900 000 0F.. 99 250.0 °.°0 O W 45099 11467 110 W 850 031146] 0.00 1643.16 114.8] 000 2800 - 3400 1]6216 114.67 OW 101825 114.67 0W 103025 11487 000 2137 11219 -401 3400 - 4000 71]227V 78m 0.90 810i:eo 566442 -100 270 90 6535.18 78.43 2:]9 4000-4600 68" ]305-156.48 0103.58 7552 17M 813].35 75.52 0.0046`00 - 5200 94"44 ]524 -1.19 94M 44 7524 000 0 45 ]0.1] dt0] 147491 ]0 7 0.00 J30 5200-5800 1093.34 43.00 4928 1a96.4s 4247 46.47 '240 1026.47 4247 099 1070.43 42.99 14 01 )120 5600 -6400 11064.53 3928 -7380 1132061 3928 0 °0 114276' 3300 -9084 6400 - 7610 11468 75 33.37 430 1163512 3337 O.W 1206561 1600 -9283 1224285 8 91 -8203 7610 - 8820 12]29.1] 8.81 OW 1284405 LW -0.30 1286584 343 -138.5660 1316132 3.43 009 60 8820 1003 135520 341.°0 9138 t37P. 34004 172.02 13]03.10 34904 000 1413558 330.0 -SJ.03 10030 -1124 1483043 31021 -8995 1488592 310.21 000 '4ee6.12 "°°o.1s4.56 11240- 1245 1EO8413 297" 4000 210 150 s0 12450 1366 180 13660 1487 14870 1608 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1 H-104 500292360600 Plan: 11-1-104 Plan: 1 H-104wp26 Error Ellipse Survey Report 03 July, 2018 Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kupamk River Unit Site: Kuparuk I Pad Well: Plan: IH -104 Wellbore: Plan: IH -104 Design: iH-104wp26 Schlumberger Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1 H-104 Plan. 54.1+39 @ 93.1Gust (Doyon 142) Plan: 54.1+39 @ 93, 10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 1 H Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.37 ° Well Plan: IH -104 Well Position -NIS Northing: Latitude: (usft) +E/ -W Easting: Longitude: Position Uncertainty 1,400.00 1H-104wp26(Plan: 11-1-104) 0.00 usft Wellhead Elevation: Ground Level: 54.10 usft Wellbore Plan. 11-1-104 Magnetics Model Name Sample Date Declination Dip Angie Field Strength (nn BGGM2018 8/15/2018 17.04 80.91 57,447 Design 1H-104wp26 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 350.00 Survey Tool Program Date 7/3/2018 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.00 1,400.00 1H-104wp26(Plan: 11-1-104) GVD-GC-SS Gyrodata gyro single shots 1,400.00 1,920.00 1H-104wp26(Plan. 1 H-104) MWD MWD - Standard 1,400.00 1,920.00 1H-104wp26(Plan:1H-104) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1,920.00 3,420.00 1H-104wp26(Plan: 1 H-104) MWD MWD -Standard 1,920.00 9,465.00 1 H-104wp26 (Plan: 1 H-104) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 9,465.00 10,965.00 1H-104wp26(Plan: 1 H-104) MWD MWD -Standard 9,465.00 16,084.13 1 H-104wp26 (Plan: 1 H-104) MWD+IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC 7/3/2018 1122'OOAM Page 2 COMPASS 5000.14 Build 85 Schlumberger Error Ellipse Report Company: ConocoPhillips(Alaska) Inc.-Kupi Local Coordinate Reference: Project: Kupawk River Unit TVD Reference: Site: Kuparuk 1H Pad MD Reference: Well: Plan: 1H-104 North Reference: Wellbore: Plan: 1H-104 Survey Calculation Method: Design: 1 H-104wp26 Output errors are at 1H-104) MWD+IFR-AK-CAZ-SC Database: Plan Survey Tool Program Date 7/312018 li Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1400.001H-104wp26(Plan: 11-1-104) GYD-GC-SS Gyrodata gyro single shots 2 1,400.00 1,920.00 1H-104wp26(Plan: 1H-104) MWD MWD - Standard 3 1,400.00 1,920.00 1 H-1 04wp26 (Plan: 1 H404) MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 1,920.00 3,420.00 1 H-1 04wp26 (Plan: 1 H-104) MWD IndlnaXon Avmulh VnN.1 MWD - Standard 5 1,920.00 9,465.001H-104WP26(Plan: 1H-104) MWD+IFR-AK-CAZ-SC semlmalor Srmiminir MWD -IFR AK CAZ SCC 6 9,465.00 10,965.001H-104Wp26(Plan: 1H-104) MWD MWD - Standard 7 9,465.00 16,084.131H-104wp26(Plan: 11-1-104) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Well Plan: 1 H-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station MeesuuX IndlnaXon Avmulh VnN.1 Highslde Laura) Vemical Me9nhuaa semlmalor Srmiminir Depa, Man; Emr Bias Emor Bias E. Bias if Bias Emir Emor Ntmuth Tool (usm 1°I rl (esft) (ush) (-ft) Nm loan) luso) lusft) (usft) (use) (usft) VI 3900 0.00 Car 39.00 0.00 0.00 0.00 0.00 0.00 0.00 000 0.00 000 0.00 UNDEFINED 10000 0.00 0.00 100.00 0.04 0.00 0.04 000 1.15 0.00 000 0.04 0.04 0.00 GYD-GPSS(1. 1) 118.10 a(K) 0.00 118.10 0.19 0.00 0.19 0.00 1.15 0.00 0.00 0.19 0.19 0.00 GYD-GC-SS (1. 1) 200.00 0.00 0.00 200.00 0.19 0.00 0.19 0.00 1.15 0.00 0.00 0.19 0.19 0.00 GYD-GC-G6(1. 11 250.00 0.00 0.00 250.00 0.26 0.00 0.26 0.00 1.15 0.00 0.00 0.20 0.26 0.00 GYD-GGSS(1, 1) 300.00 0.75 114.67 300.00 0.31 0.00 0.31 0.00 1.15 0.01 0.01 0.31 0.31 45.00 GYD CUSS (1, 1) 40000 2.25 114.67 399.98 0.40 000 0.40 0.00 115 0.01 0.01 0.40 0.40 45.00 GYD-GGSS(1, 1) 450.00 3.00 114.67 449.91 0.45 0.00 045 0.00 1.15 0.02 0.02 0.46 0.45 25.02 GYPGOSS (1, 1) 500.00 4.25 114.67 499.81 0.51 0.00 0.51 000 1.15 0.02 0.02 0.51 0.51 25.14 GY0-GC49S(1, 1) 60000 6.75 114.67 599.34 0.64 am 0.64 0.00 1.15 0.03 0.03 0.65 0.64 26.10 GY GGSS (1, 1) 650.00 8.00 11487 648.92 0.70 0.00 0.71 0.00 1.15 0.04 001 0.72 0.71 26.17 GYD.GC-SS(1. 1) 700.00 9.25 114.67 69636 0.77 0.00 0.79 0.00 1.15 0.05 0.05 0.79 0.79 2935 GYD-GCUSS(1, 1) 800.00 11.75 114.67 796.68 0.91 -0.01 095 0.00 1.14 0.07 0.07 0.95 0.94 113.33 GYDGGSS(1. 1) 900.00 14.25 114.67 894.11 1.06 -0.01 1.13 0.00 1.14 0.09 009 1.13 1.09 113.94 GYD CUSS (1. 1) 1,000.00 16.75 114.67 990+46 1.21 .0.01 1,33 0.00 1.14 0.11 0.11 1.33 1.25 114.16 GY0.G SS (1, 1) 1.100.00 19.25 114.87 1,085.56 1.37 -0.02 1.55 0.00 1.14 0.13 0.13 1.55 142 114.27 GYD-GC 8(1,1) 1,200.00 21.75 114.67 1,179.22 1.53 -0.03 1.79 0.00 1.14 0.16 0.16 1.79 1.59 11434 GYD4aOSS(1, 1) 1,300.00 24.25 114.67 1,271.26 1.70 4.03 2.05 0.00 1.15 0.18 0.19 205 1.76 114.39 GYD-GC-SS(1. 1) 1400.00 26.75 114.67 1,361.51 1.87 4.01 2.34 0.00 1.17 0.21 0.22 2.34 1.94 114.43 GYD-GC-S5(1. 1) 1,500.00 29.25 114.67 1449.80 1.95 .0.05 2.52 0.07 117 0.24 0.26 2.52 2.04 114.50 MWD(1. 2) 1,600.00 31.75 11467 1,535.96 1.95 -0.06 2.79 0.22 1.16 0.27 036 2.79 2,07 114.79 MIND (1. 2) 1%3.16 32.83 114.67 1,57244 1.95 .0.07 2.99 0.29 1.16 0.29 042 2.99 2.10 11490 NAVE, (1, 2) 1,700.00 32.83 114.67 1,620.20 1.99 -0.07 3.31 0.38 1.17 0.30 0.50 3.31 2.12 115.00 MIND (1, 2) 1.734.39 32.83 114.67 1,649.10 2.03 4.07 3.71 0.49 1.19 0.32 0.60 3.71 2.15 115108 MWD (1, 2) 713=1811:22.00AM Page 3 COMPASS Wool. 14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupt Project: Kuparuk River Unit Site: Kuparuk 1 H Pad Well: Plan: 1H-104 Wellbore: Plan: 1H-104 Design: 1H-104wp26 Schlumberger Error Ellipse Report Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1 H-104 Plan: 54.1+39 @ 93,1 Wall (Doyon 142) Plan: 54.1+39 @ 93.1 Wall (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination Atl.Nh W1tical Hig"Ide Lereral Venlcal MagnBude sem'v Wr 6em1+n1Rar Oepm Mph a. Blas E.r Biu E.r Bias ora,. Emr E., AximuM Tod Iasn) 11) 11) (-Vu (dea) (urn) (Usn) (.en) (Usa) (.eft) 0e14 Juan) Juan) C) 1,762.16 32.83 114.67 1,672.44 2.03 4.07 3)1 0.49 1.19 032 0.80 371 2.15 115.06 MWD (1. 2) 1,800.00 31% 114.67 1,704.03 2.04 -0.116 3.98 0,55 1.20 094 0.66 390 2.17 115.09 MM (1, 2) 1,90060 36.98 114.67 1785.47 2.11 4.10 460 0.74 1.24 0.37 0.85 4.00 2,25 115.13 MWD(1, 2) 1,918.25 37,51 114.67 1,800.00 2.12 4.10 4.90 0.78 1.24 Us Us 4.98 2.27 115,13 MM (2. 3) 1,938.25 37.51 114.67 1,015,86 1.97 -0.10 3.13 0.02 1.15 Us 0.42 3.13 2.18 116.53 MM (2. 3) 1,943,60 37.73 114.65 1,820.10 1,94 -0.12 3.34 0.16 1.15 0.40 0,0 3.31 2.19 116.10 MM (2. 3) 2,000,00 Use 114.40 1,864.02 1 94 -0.12 3.34 0.16 1.15 0.40 0.47 3.31 2.19 116.18 MWD (2, 3) 2,100.00 43,97 114.01 1,938.35 1.92 -0.15 3.96 OA2 1.15 0,44 0.64 3.96 2.23 115.57 MM (2, 3) 2,20060 47.96 113.68 2,007.85 1.67 -0.19 4.86 0.71 1 1S 0.47 0.89 4.87 2.29 115.08 MWD (2, 3) 2.215,40 48.50 113.63 2,010.10 1,99 -0.22 5.98 1.05 1.26 0.50 1.19 5.98 2.36 11471 MWD (2, 3) 2,300.00 51.95 11139 2.072.17 1.99 .0.22 5.98 1.05 1.26 0.50 1.19 5.98 2.36 114.71 MM (2, 3) 2,400.00 55.95 113.12 2,131.01 2.09 -0.26 7.25 1.43 139 0.52 1.55 7.25 2.44 114.41 MM (2, 3) 2,500,00 59.94 112.88 2,184.07 2.22 -0.31 8+63 1.84 1.57 0.55 1.95 0.83 2.53 114.16 MVM (2. 3) 2,600.00 63.94 112.66 2.231.10 2.39 4.35 10.09 2.29 1.70 0.57 2.30 10,09 2.62 113.95 MWD (2. 3) 2,700,00 67.93 112.45 2,271.07 2.58 4.39 1162 2.76 2.04 ew 2.85 11.62 2.70 11375 MWD(2. 3) 2,800.00 71,93 112.26 2.308,17 2.79 4.44 13.19 3.27 2.32 0,80 3.35 13.19 2.70 113,58 MM (2, 3) 2.837.04 73.61 112.19 2,317.21 2,87 4A5 13.77 3.0 2.43 0.60 3.54 1170 2,80 113.51 MM (2, 3) 2.900.00 73.41 112.19 2,335.18 3.07 -0.45 14.70 3.00 2.62 0,61 3.87 14.79 2.84 113,42 MM (2.3) 3,000.00 73.41 112.19 2,363.74 3,40 -0.45 16.39 4.32 2.95 0.82 4.40 16.40 2.90 113.29 MWD (2, 3) 3,100,00 73.41 112,19 2,392.29 3.73 -0.45 18.02 4.85 327 0.63 4.92 18.02 2.97 113.19 MM (2, 3) 3,200.00 73.41 112.19 2.420,84 4.07 -0A5 19.65 5,38 3.60 0.65 5.45 19.65 3.03 113.10 MWD(2, 3) 3,300.00 73.41 112.19 2,449.39 4.40 -0.45 21.28 5.90 393 0.66 587 21.29 3.10 113.03 MM(2,3) 3.400.00 73.41 112.19 2,07.95 4.74 -0.45 22,92 6.43 4.26 0.67 6.50 22.93 3.17 112.97 MWD (2, 3) 3,500.00 73.41 112.19 2.500.50 2.80 -0.44 9.05 0.01 2.46 0.60 1.02 9.85 2.65 113.92 MWD+1FR-AK-CAZ-SC(1,3) 3,600.W 73.41 112.19 2.535.05 2.96 4.44 10.41 0.01 2.62 0.70 1.05 10A2 2.68 11385 MW IFR -AK -CR -&C (3.3) 3,703.00 73AI 112.19 2,563.80 3.12 -0.44 10.98 0.01 2.78 0.71 1.11 1098 2.70 11338 MM IFR-AK-CAZ-W(3,3) 3,8W.00 73.41 112.19 2.592+16 120 -0.44 11.55 0.01 2.94 012 1.15 11.56 273 113.71 MWDMFR-AK-CP-SC(3,3) 3.900.00 73.41 112.19 2,620.71 3.44 -0.44 12.13 0.01 3.10 0.74 1,19 12.13 2.76 113.88 MW -IFR-PH-CAZ-SC(3.3) 4,03060 73.41 112.19 2.849.28 3.61 -0A4 12.70 0,01 3.26 0.75 1.24 1271 2.79 113.61 MWDNFR-AK-CAZSC(3, 3) 4.100.00 73.41 112.19 2,67] 81 3.77 .0.44 13.28 0.01 3.42 0.77 1.29 13.29 282 113.56 MWD+1FR4K-CAZ-sC (3, 3) 4200.00 73.41 112.19 2.706.37 3.94 -0.44 1186 0.01 359 0.78 1.33 13.87 2.85 113.52 MVVD+1FR-AK-CAZ-SC (3, 3) 4,300.00 73AI 112.19 2,734.92 4,11 -0.44 14.64 0.01 3.75 0.80 1.38 14.45 2.80 11149 MM-1FR-AK-0AZ-SC(3,3) 440.00 73.41 112.19 2.763.47 4.27 4.44 15.03 0.01 3.91 0.81 1.43 15.03 2.92 113.45 MWDHFR-AK-CA-SC(3.3) 4,500.00 73.41 112.19 2.792.02 4.44 -0.44 15.61 061 4.08 0.03 1.40 15,62 2.95 11342 MW IFR -AK -CA -SC (3.3) 4,600.00 73+41 112.19 2,820,58 461 -OA4 16.20 0.01 4.24 0.84 1.53 16.20 2.98 11340 MI JFR-AK-CA-W(3.3) 4.70090 73,41 112.19 2,849.13 4.78 -0.44 16.78 0.01 4.41 0.86 1.58 16.79 3.02 113.37 MwDHFR-AK-CAZ-6C(3,3) 4,800.00 73.41 142.19 2,877.68 4.95 -0.44 17.37 0.01 4.57 0.87 1.64 17.37 3.05 113.35 MWDNFR-AK-OA2-SC(3,3) 4,082.02 73.41 112.19 2,901.10 5.12 -0.44 17,96 0.01 4,74 0.89 1.69 17.96 3109 113,32 MVM+1FR-AK-CAZ-SC(3,3) 4,900.00 73.41 112.19 2,906.23 5.12 -0.44 17.96 0,01 4.74 0.89 1.69 17.96 3.09 11332 MW0t1FR-AK-CAZSC(3,3) 5,000.00 73,41 112.19 2.934.79 5.29 4.44 18.55 0.01 4.91 0.90 1.75 18.55 3.12 113.30 MWD+1FR-AK-0A2-SC(3,3) 51103,00 7341 112.19 2,963.34 5.46 4.44 19.14 0.01 5.07 0.92 1.80 19.14 3.16 113.28 MWD+IFR-AK-CAZ-SC(3,3) 5.200.00 7341 112.19 2,991,89 5.63 -044 19.73 0.01 5.24 0.94 1.86 19,73 3.20 113.27 MWWIFR-AK-CA-&C (3,3) 5,300.00 73.41 112.19 3,020.44 5.80 -0.44 20.32 0.01 5.40 0.95 1.92 20.82 3,24 113.25 MW IFR -AK -CR -SC (3.3) 5,400.00 73.41 112.19 3.049.00 5.98 -0.44 20.91 0.01 5.57 0.97 1.97 20.91 3.27 113.23 MM +1FR-AK-CAZ-W(3.3) 5,500.00 73.41 112.19 3.077.55 6.15 -0.44 21.50 0.01 5.74 0.99 267 21.50 3.31 113.22 MWDNFR-W-CA2-SC(3,3) 5,600.00 73.41 112.19 3,108.10 6.32 -0.44 22.09 061 5.90 1.01 2.09 22,09 3.35 113,20 MMNFR-AK-CAZSC(3,3) 5,890.06 73.41 112.19 3,13410 6.49 4.44 22.68 061 8.07 1.02 2.15 22.69 3.39 113.19 MVM+1FR-AK-CAZSC(3,3) 5.700.00 73,41 112.19 3,134.65 6.49 -0.44 22.68 0.01 8,07 1.02 2.15 22.69 3.39 113.19 MM+1FR-AK-CA SO (3,3) 5,800.67 73.41 112.19 3,163,21 6.67 4,44 23.28 061 6.24 1.04 2.21 23,28 3.43 113.18 MWD+1FR-AK-CAZSC(3,3) 5.900.00 7341 112.19 3,19136 8.84 -0774 23.87 0.01 6.41 1.06 2.28 23.87 347 11117 MW IFR -AK -CA -SC (3, 3) 6,000.00 73.41 112.19 3,220.31 7.01 -0.44 24.46 0.01 6.57 1.08 2.34 24+46 3.51 113,15 MMNFR-AK-CAZ-SC(3,3) 6,051.79 73.41 112.19 3,235.10 7.18 -0.44 25.05 0.01 6.74 1.10 2.40 25.06 3,55 113.14 MWDdFR-AK-CP-SC (3.3) 6,100.00 73.41 112.19 3,248.86 7.18 -0.44 25.05 0.01 6.J4 1.10 2.40 25.08 3.55 11314 MM+IFR-M-CAZ-SC(3,3) 6.200.00 73.41 112.19 3.2.4.42 7.36 -0.44 25.65 0,01 6.91 1.11 2.47 25.65 3.59 113.13 MWDNFR-AK-OA2-SC(3,3) 7!.1/2018 11:22:OOAM Page 4 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupi Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-104 Wellbore: Plan: 1H-104 Design: IH-104wp26 Schlumberger Error Ellipse Report Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method' Output errors are at Database: Well Plan: 1 H-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station Messurea Inclushen Aa9muth venlcal Hi9hh,se L .l vereeal Ma9nim6e Semima)or 3emiminh, Depth Depth En., alas Error alas E. Blas of alas Enor Eno, Azimuth That (uah) (% PI (usm hush) lien) lush) )teal )heft, (heft) lues) (ushl hien) M 6,30000 7341 112.19 3,305.97 2.53 -0.44 26.24 0.01 7.07 1.13 2.53 28.25 3.64 113.12 MWD+IFR-AK-CAZ-SC(3, 3) 6.400.00 73.41 112.19 3,334.52 7.70 -0.84 26.84 0.01 7.24 1.15 2.60 26.84 3188 113.12 MWD+11FR-AK-CAZ-SC(3, 3) 6,402.02 73.41 112,19 3,335.10 7.88 .0.44 27.43 0.01 741 1.17 2.67 27,43 3.72 113.11 1JWD+1FR-AK-CAZ-SC(3. 3) 6500.00 73.41 112.19 3,363.07 7.88 -0.44 27.43 0.01 7.41 1.17 2.67 2743 3.72 113.11 MWD+1FR-AK-CAZ-W(9. 3) 6,600.00 7341 112.19 3.391.63 8.05 -044 28.02 0.01 7.58 1.19 2.73 28.03 3.76 113.10 MWD+1FR-AK-CAZ-SC(3, 3) 6,700,00 7341 112.19 3420.18 8.23 .0.44 28.62 0,01 7.74 1.21 2.80 28,82 381 11309 MM+IFR-AK-CAZ-SC(3.3) 8000.00 73.41 112.19 3,448.73 8.40 -044 29.21 0.01 7.91 1.23 207 2912 3.85 11308 MM+IFR-AK-CAZ-SC(3,3) 6,900,00 73.41 112.19 3,4T/ 28 8.57 -044 29.81 001 8.08 1.25 2,94 29.81 3,80 113.08 1AWD+1FR-AK-CAZ-SC (3, 3) 7,000.00 73.41 112.19 3,505,84 8.75 .0.44 30.40 001 8.25 1.27 3.01 3041 3.94 11307 MWD+1FR-AK-CAZ-SC(3, 3) 7,100.00 73AI 112.19 3,530.39 8.92 -0.44 31.00 0,01 8.41 1.29 3.09 31.00 3.98 113,06 MWD+IFR-AKCA-SC (3,3) 7,177,27 73AI 112.19 3.55645 aw .0.44 31.46 0.01 8.54 1.31 3.14 31.46 4.02 11306 MWD+IFR-AK-CAZ-SC(3, 3) 7,200.00 73.50 11124 3,552.93 9.11 -0.44 31.57 0.06 0.50 1.31 3.16 31.59 4.03 113.05 MWD+1FR-AK-CAZ-SC(3,3) 7,278.79 73,82 107.98 3,585.10 9,38 4.47 31.94 0.27 8.75 1.33 3.23 32.11 4.07 11300 MWD+IFR-AK-CAZ-SC(3,3) 7,300.00 7392 107.10 3,58089 9.38 4.47 31.94 0.27 8.75 1.33 3,23 32.11 4,07 11300 MWD+IFR-AKAAZ-SC(3, 3) 7,40000 7042 102.98 3,618.28 9.68 4.51 32.15 0.48 8.91 1,35 3.30 32.63 4.11 112.89 MWD+IFR-AK-CAZ-SC(3, 3) 7.494.02 74.97 99.12 3,643.10 9.98 4L55 32.19 0.70 908 1.37 3,37 33.13 4.15 112.71 MW IFR -AK -CA -SC (3,3) 7.500.00 75.01 98,87 3,644.65 9.98 -0.55 32.19 0.70 9.00 1,37 3.37 33.13 4.15 112.71 1AWD+1FR-AK-0AZSC(3,3) 7,588.41 75.58 95.27 3,667.10 10.29 -0.60 32.06 0.91 925 1.39 3.44 33.62 4.20 112.48 MvV+IFR-AR-CAZSC(3,3) 7,600.00 75.86 9439 3,669.911 10.29 .0.80 32.06 0.91 925 169 344 33.62 4.20 112.40 MWD+1FR-AK-CAZSC(3,3) 7,700.00 76.38 90,74 3894.14 10.57 -0.86 31.77 1.12 942 141 351 MAO 4.24 112.20 MVM-IFR-AKC C(3,3) 7,747.15 78]5 88.84 3.705.10 10.84 -0.73 31.33 1.84 9.59 1.43 3.58 34.55 4.28 111.87 MWD+IFR-AK-CAZ-SC(3.3) 7,80000 77.17 86.71 3,70.03 10.84 .0.73 31.33 1,34 9.59 143 3.58 Usk 4.28 111.87 MM+IFR-AK-CAZ-SC(3.3) 7,900.00 78.02 82.71 3,738.52 11.07 -0.79 30,73 1.54 9.76 1.44 3.64 84.99 4.33 111.51 MWD+1FR-AK-CAZ-SC(3,3) 7,957.00 78,53 80.44 3,75810 11.26 -0.87 29.98 135 9.93 1.46 3.70 35.39 4,40 111.11 MWD+1FR-AK-CAZ-SC(3,3) 8.000,00 78.93 78.73 3.758.51 11.26 4.87 29.98 1,75 9.93 1.46 3.70 35,39 4.40 111.11 MWD+IFR-AK-CAZ-SC(3. 3) 8,007.91 7900 78.42 3,760.02 11.27 4.87 29.92 1.76 9.94 1.46 3.71 3542 LAD 111.08 MW IFR -AK -CA -SC (3.3) 0.100.00 79.00 78.42 3,777.59 11.43 -0,87 30.38 1.76 10.10 147 3.76 35.82 4.45 110.67 MW IFR-AK-CAZ-SC(3,3) 8,107.91 79.00 7842 3,779.10 11.44 -0.87 30.42 1.76 10.11 147 337 35.85 4.46 110,64 VP IFR-AK-CAZ-SC(3, 3) 8,200.00 79.04 78.42 3,798.64 11.59 -0.88 30.92 1.76 10,27 1.48 3,82 36.27 4.50 110.21 MVA+1FR-AK-CAZSC (3,3) 0,300,00 79.08 70.42 3,615.62 11.75 -0.88 31.47 1.76 10.45 1,50 3.88 36.74 4.56 10.76 MVA+1FR-AK-CAZSC(3,3) 8,400AG 79.12 78.43 3,834.53 11.91 -0.88 32.02 1.76 10.62 1.51 3.94 37.21 4.61 109.32 MWD+1FR-AK-CAZ-SC(3,3) 8,500,00 79.16 7843 3.853.37 12.07 -0.88 32.57 1.76 10.79 1,52 4.01 37.68 4.67 108.88 MWD+1FR-AK-CAZ-SC(3,3) 8509.16 79,16 7843 3,055.10 12.13 -0.88 32,76 1.76 10.85 1.53 4.03 37.85 4.69 108.73 MM+IFR-AK-CAZSC(3,3) 8,535.79 79.18 78.43 3.060.10 12.13 -0.88 32,76 136 1085 1.53 4.03 37.85 4.69 108.73 MWD+IFR-AK-CAZ-SC(83) 8.600.00 7713 4.52 3,873,28 12.58 .0.76 32.81 182 10.96 164 4.07 38.15 4+72 108.46 1AWD-11FR-AK-CAZ-SC(3,3) 8,700.00 73.96 76.07 3,898.24 13.34 -0.58 3243 1.90 11.13 1.55 4.14 38.59 4.75 108,06 MPA+IFR-AKLA2-$C(3,3) 8.800.00 70.79 74.57 3,928.51 14.19 -0.39 32.80 1.99 11.30 1.58 4.21 39.03 4,80 107.65 MWD+1FR-AK-CAZ-SC (3, 3) 8.897,65 67.72 7.05 3,963.10 15.10 -021 32.73 248 11.46 1.62 429 3944 4.87 107,26 1AV0D+1FR-AK-CAZ-SC(3.3) 8,900.00 67.81 73.08 3.963.99 15.09 -021 32.75 2.08 11,48 1.62 4,30 39.45 4.85 107.25 MWD+IFR-ML-SC (3,3) 9,00000 7162 74.37 3.998.65 14.36 -045 33.79 2.00 11.62 1.65 438 39.92 4.91 10.81 %=+1FR-AK-CAZSC(3,3) 9,100.00 75.07 75.49 4,027.31 13.82 -0.68 34.76 1.93 11.79 1.67 4.46 40.41 4.97 10,39 MWD+1FR-AK-CAZSC(3,3) 9,103.58 75.20 75.52 4,028.58 13.80 -068 34.80 1.82 11.79 167 446 40.42 4.97 10.37 MWD+1FR-AH-CAZ-SC(3,3) 9,133.35 75.20 75.52 4,036.16 13.85 -0.68 34.96 1,92 11.84 1.68 448 40.57 4.99 10.25 MWD+1FR-AK-CAZ-SC(3,3) 9,200.00 77.86 75.47 4,051.69 13.53 -0.87 35,30 1.93 11.96 1.69 4.53 40.88 5.03 105.99 MWD+IFR-AK-0AZ-SC(3,3) 9,30.00 8L88 75.38 4,009.28 13.11 -1.15 35.81 1.93 12.13 1.71 4.59 41.34 5.10 105.61 1jWD+1FR-AK-CAZ-S3(3,3) 9,400.00 85.86 75.30 4.079.97 1235 -1.43 3830 1.94 12.30 1.71 4.85 41.79 5.16 105,24 MW IFR-AK-CAZ-&C(3, 31 8488.44 89.00 75.24 4,083.04 12.46 -1.65 35.69 2.11 12.36 172 4.76 42.18 523 105.02 MM (3.4) 9,48844 89.00 75.24 4,082.45 1246 -1.65 36.83 2.21 12.38 1.72 4.01 42.28 5.25 104.92 MWD J3,4) 9,50.00 09.07 74.78 4,082.64 12.46 -1.65 36.74 2.30 12,36 1.72 4.84 42.35 5.28 104.86 MM (3,4) 9,80.00 89,63 70.82 4,083.78 12.41 -1,09 35.95 304 12.37 1.72 5.14 42.95 5.45 104.31 MWD (3,4) 9,616.45 89.73 70.17 4,083,87 1240 -1.70 35.81 3.16 12.38 1.72 5,19 43.05 5.49 104.21 MM (3, 4) 9,700.0 89.73 70.17 4,004.27 12.42 -1.70 36.47 3.54 1240 1,72 546 43.57 5.74 103.68 MM (3, 4) 9,714.01 89.73 70.17 4,084.34 12.43 -1.70 38,59 3.61 12.40 1.72 5.51 43.66 5.79 103.58 MWD (3. 4) 8800.00 89.4 65.7 4,084.71 12.45 -1.70 35.04 4,22 12.43 in 5.81 44.22 6.12 102.99 MM (3.4) 7MO1811:22:OOAM Page 5 COMPASS 5000.14 Build 85 Company: ConowPhillips(Alaska) Inc.-Kupt Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 11-1-104 Wellbore: Plan: 1H-104 Design: 1H-104wp26 Position uncertainty and bias at survey station Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output enrols are at Database: Well Plan: 1H-104 Plan: 54.1+39 ® 93.1 Oust (Doyon 142) Plan: 54.1+39 93.1 Oust (Doyon 142) True Minimum Curvature 100 sigma OAKEDMP2 M..0 IndMiduan A..Nh Win.] J1,M,& lateral VeTCid MagNmtle Semima)Or Bemlminar Depm Depth Error Bias Error 8W E.r Blas 0eiu Error Emr Animul8 Tod (uaft) 11) (1) (ueft) (usa) (usft) (um) (use) (UMu (ueft) lusn) (-ft) (-am (1) 9900.00 8962 62.73 4,08507 12.49 -1,71 34.66 4.88 1248 1,72 6.16 44.87 6.60 10222 MM (3, 4) 10,000.00 89.87 58.73 4.085.34 12.54 -1,71 33.83 5.50 12.53 1.72 6.52 45.51 7.16 101.37 MWD(3, 4) 10,1W.00 89.93 54]3 4,005.51 12.60 -1.71 32.70 6.00 12.80 1.72 6.06 46.14 7.80 100.45 MWD(3, 4) 10,200.00 89.90 5033 4,085.60 12.68 -1.72 31.49 858 1267 1.72 7.18 46.75 8.51 99.46 MWD(84) 10,300.00 9003 46.73 4,085.59 12,76 -132 30.23 703 12.76 1.72 7.48 0.36 9.26 98.42 MM (3, 4) 10,393.34 90.08 43.00 4,085.00 12.94 -132 29.01 7.39 12.85 132 7.M 47.86 10,00 97.41 MM (3, 4) 10,400.00 90.09 4233 4,085.49 12.85 -1,72 28.93 7.41 1286 132 7.74 47.90 10.05 97.34 MIND (9, 4) %4W.50 90.09 42.47 4,085A8 12.85 -1.72 28.84 7.44 12.86 1.72 7,76 47.93 10.10 97.27 MM (3, 4) 10.500.00 90.09 42.47 4,085.33 42.95 -1.72 29.91 7.67 12,96 1,72 7.99 48.46 10.79 96.26 MWD(3, 4) 10,6W.00 90.09 42.47 4.085.16 13.07 -1,72 3104 7.91 13.08 1.72 9.24 4899 11.46 95.19 MM (3, 4) 10,700.00 90.09 42.47 4,085.00 13.19 -1.72 32.21 8.16 13.20 1.72 0.48 49.57 12.15 94.11 MW)(3, 4) 10,800100 90.09 42.47 4084.83 13.33 -1,72 33.40 841 13,33 1,72 0.73 50.10 12.86 93.02 MWD(3, 4) 10,900.00 90.09 42.47 4 084.67 13.47 -1,72 31.52 sea 13.48 1,72 8.98 50.82 13.55 91.91 MM (3, 4) 10,926.47 Woe 42.47 4,084.63 13.51 -1,72 34.94 8,72 13.52 132 9.04 50.99 13.75 91.61 MIND (3, 4) 10.970.43 Stec 42.90 4,083.90 12.53 -1.81 23.99 3.88 12.68 132 5.21 44.14 731 101.38 MM -IFR -AK -CA -SC (4, 4) 11,00000 92.13 41.76 4,082.89 12.53 -1.83 23.39 3.94 1267 132 5.22 44.18 7,79 101.28 MWD+1FR-AK-CA -SC (4, 4) 11,081,53 92.85 39.28 4,080.00 12.55 -1.85 22.07 4.06 12.70 1,71 5.24 44.26 7.98 101.07 MM -IFR -AK -CA -SG (4, 4) 11,100.00 92.85 39.28 4.078.32 12.57 -1.85 22.19 4.06 12.71 131 5.25 44.30 8.09 100.95 MM -IFR -AK -0A -$C (4, 4) 11.200.00 92.85 39.28 4.073.36 1261 -1.85 22.53 4.06 12.76 1.71 5.27 44.42 8.39 100.63 MV )+IFR -AK -CA -SC (4, 4) 11.300.00 92.85 39.28 4,W0.40 12.85 -1.05 22.88 4.06 12.80 1,71 5.30 44.53 830 100.30 MWD+1FR-AKCA-SC(4, 4) 11,320.91 WAS 39.28 4,007.36 12.66 -1.85 22.96 4.06 12.81 1.71 5.30 44.56 8.77 100.23 MVrD+IFR41<-CA-S (4, 4) 11.400.00 9261 36.11 4,063.46 12.72 -1,81 21.28 4.22 12.85 1,71 5.32 44.65 9.00 99.96 MWD+IFR-AK-CA-B (4, 4) 114VAH 92.79 35.00 4.062.10 12.73 -1.81 20.66 4.27 12.88 1,71 5.33 44.68 9.08 99.87 MWD+IFR-AK-CA2-SC(4, 4) 11,4M.75 92.96 33.37 4,080.05 12,76 -1.84 19.82 4.35 12.80 131 5.34 44.73 9.20 99.73 MVA)+IFR-AKCA -S (4, 4) 11.50.00 9296 33.37 4,058.43 12.78 -1.84 19.94 4.35 12.90 1,70 5.34 44.76 9.30 99.62 MWD -IFR -AK -CA -$C (4. 4) 11,600.00 92.96 3337 4,053.28 12.0 -1.84 20.32 4.35 12.95 130 5.38 44.85 9.63 99.27 MVA+IFR-AK4AZSC(4, 4) 11,631.12 92.96 33.37 4,051.65 12.85 -1.84 20.44 4.35 12.97 1,70 5.37 44.89 9.74 99.16 MVI) -IFR -AK -CA -B (4, 4) 11,700.00 92.83 30.61 4018.18 12.90 -112 19.02 4.0 13.01 1,70 5.36 44.96 9.95 90.92 MWD+IFR-AK-CA2-SC(4, 4) 11,800.00 92.62 28.62 4,043.43 12.97 -1.80 17.01 4.63 13.08 130 5.40 45.05 10.24 98.57 MM+IFR-AKCA-SC(4,4) 11,900.00 92.39 22.62 4.039.05 13.04 .1.77 15.17 4.78 13.12 1,70 5.42 45.12 10.54 98.22 MVA+IFR-MC-SC (4.4) 12,000.00 92.16 18.62 4,035.08 13.11 -135 13.59 4.90 13.18 1.69 513 45.18 10.85 97.87 1JWD+1FR-AKCA-SC(4,4) 12,065.61 92.00 16.00 4,032.70 13.15 -1.74 12,76 4.97 13.23 1.69 5.44 45.20 11.06 97.64 MM+IFR-AK-CA -SC (4.4) 12,100.00 91.93 14.63 4,031.52 13.18 4.74 12.42 5.00 1125 1.69 5.45 45.22 11.17 97.52 MWD+IFR-AKCALSC(4,4) 12,20000 91.73 10.63 4,028.33 13.25 -1.72 11.79 5.09 13.31 1.69 5.46 4524 11.50 97.18 MM -IFR -AK -CA -SC (4,4) 12,242.85 9164 8.91 4,027.07 13.28 .1.72 1133 5.12 1234 1.69 5.45 45.24 14.64 97.03 MWD+1FR-AK-CA-SC(4,4) 12,300.00 91.6`1 8.91 4.025.44 13.32 -1,72 11.92 5.12 13.38 Ise 5.46 45.25 11.81 WA4 MWD+IFR-AK-CA -SG (4,4) 12.400.00 91.61 8.91 4022.59 1339 -1.72 12.24 5.12 13.45 Ise 5.47 45.26 12.10 96.50 MWD+IFR-AK-CA -SC (4.4) 12.500.00 91.61 8.91 4,01933 13.47 -132 12.57 5.12 13.52 1.69 5.48 45.27 12.40 96.17 MWD+IFR-AK-CAZ C (4.4) 12,600.00 91.64 8.91 4.018.88 1154 -1.72 12.0 5.12 13.60 1.69 5.49 45.29 12,72 95.83 MW IFR -AK -CA SC (4,4) 12,700.00 91.64 8.91 4,014.03 13.62 -132 13.30 5.12 1367 lea 5.50 45.30 13.05 95.48 MW IFR-AK-CAZSC(4.4) 12,720.17 91.64 861 4,013.45 13.63 -1,72 13.38 5.12 13.69 1.68 5.50 45.30 13.11 95.41 MWD+IFR-AK-CALSC(4,4) 12.800.00 94.23 535 4,011.46 13.70 -1.70 13.37 5.17 13.75 1.68 5.51 45.31 13.37 95.14 MW IFR-AK-CA-SC(4,4) 12.44.05 91.00 4.00 4,010.80 13.74 -1.70 13.52 5.19 13.78 Ise 5.51 45.31 1150 94.99 MVA+IFR-AK-CA-SC(4,4) 12,065.84 90.35 3.43 4,010.35 13.78 -1.69 13.59 5.20 13.00 1.68 5.51 45.31 13.51 94.92 MWD+1FR-AK6CA-S0(4,4) 12.900.00 90.35 3.43 4,010.13 13.81 -1.69 13.89 5.20 13.83 1.86 5.51 45.31 13.62 94.81 MM -IFR -AK -CA -B (4, 4) 13,000.00 90.35 3.43 4,00952 13.89 -1.69 13.97 5,20 13.91 168 5.52 45.30 13.95 96.48 MM+IFR-AK-CA -S (4,4) 13,100.00 90.35 3.43 4,008.90 13.97 -1.69 14.30 5.20 13.99 1.68 5.53 45.30 14.29 94.14 MVA+IFR-AK-CA2.8C(4, 4) 13,16622 90.35 3.43 4,008.49 14.03 -1.69 14.53 5.20 14.05 1.68 5.53 45.30 14.53 93.91 MWD+IFRAK-CR-a (4,4) 13.200.00 90.32 2.08 4,008.30 14.06 -1.69 14.69 5.22 14.08 1.68 5.53 45.30 14.61 93.00 MM -IFR -AK -CA -SC (4,4) 13,300.00 90.23 358.00 4,007.81 14.15 -1.88 15.48 5.26 14.17 1.68 5.54 45.28 14.95 91,16 MPA+IFR-AKCR-SC(4,4) 13,400.00 90.14 354.08 4,007.49 14.25 -1.68 16.07 5.28 14.25 1.68 5.54 45.25 15.28 93.13 MWD+IFR-AKCA -S (4,4) 13,500.00 Sea 350.08 4,007.32 14.31 4.88 18.17 5.28 14.34 1.60 5.54 45.21 15.57 92.02 MM+IFR-AK-CA-W(4,4) 13,552.03 Sow 348.00 4.007.30 14.39 -1.68 19.04 527 14.39 1.68 5,54 45.18 15.74 92.67 MW0+1FR-AK-CA-SC(4,4) 13,800.00 88.10 %8.24 4,008.10 14.58 -1.89 18.94 5.27 14.44 1.68 5.54 45.16 15.79 92.54 MWD+IFR-AK-CA-SC(4. 4) 7Id7201811:22:00AM Page 6 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kupamk 1H Pad Well: Plan: 11-1-104 Wellbore: Plan: 1H-104 Design: 1H-104wp28 Position uncertainty and bias at survey station Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1H-104 Plan: 54.1+39 @ 93.1 Ousft (Doyon 142) Plan: 54.1+39 @ 93.1 Ousft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 MeaaureC InclinMioo A8mN0 vmtital HgMide Uw.1 VMical MagNNUe Semi+nalor Semiminor Depth oepth E. Bias Error Blas E. Blaa areias Error Error A imdh Tad (-dn (1 11 (uau) (UM (uaHl (ush) Ndn (uen) (usn) (usft) (ustt) (osn) r) 13700.00 84.13 398]4 4.014.80 15.36 -1.70 18.60 527 14.53 1.69 554 45.12 15.74 92.31 M=+IFR-AK-CP SC(4, 4) 13,757.86 81.83 349.04 4.021,95 18.03 .1.69 18.42 5.27 14.58 1.69 5.54 45.10 15,72 92.17 MW IFR -MC -SC (4,4) 13,793.10 91.63 349.04 4,026.95 16.06 -1.69 18.42 5.27 14,62 1.119 5,54 45.08 15.77 92.08 MWD+IFR-MK- -SC (4,4) 13,800.00 81.99 348.81 4.027.92 16.02 -130 18.52 5.27 14.82 130 5.54 45.08 15.79 92.06 MWD+IFR-AKC C(4,4) 13,900.00 84.36 345.56 4.039,00 15+45 -1.73 19.97 5.20 14.72 1.70 5.54 45.02 16.17 91,77 MND+IFR-AK.CA -SL (4, 4) 14,000,00 86]5 34234 4,00.55 15.09 -134 2149 5.23 14.82 1.71 5.53 44.94 16.55 91.50 MWD+IFR-AK-C -SG (4, 4) 14,100.00 89.15 339.14 4,051.13 14.95 -132 23.05 5.19 14.91 131 5.53 44.86 16.93 91.25 MWD+IFR-AK.CA -SC (4, 4) 14.135.59 Won 338,00 4,051.40 14.95 -131 23.61 5.18 14.95 1.71 5.52 44.83 17.07 91.17 MVA+IFR-AK-C-SC (4,4) 14.200,00 90,04 335,42 4,051.38 15.01 -1.71 24.85 5.13 15.02 1.71 5.52 4477 17.29 91.03 MM -IFR -AK -CA -SC (4.4) 14,300.00 90.11 331.42 4,051.24 15.12 -171 26.78 5.04 15.12 1.71 5.51 44.67 17.59 90.84 MVA+1FR-AK-C .SC (4,4) 14.400.00 90.17 327,43 4,051.00 15.22 -131 28.65 4.94 15.22 131 5.49 4457 17.80 90.68 MVA+IFR-AK-CA-SC(4,4) 14,500.00 90,24 323.43 4,050.64 15.33 -130 30.49 4.81 15.33 171 5.47 44,45 18.16 90.55 MWD+IFR-AK-CA-SC(4,4) 14,600.00 90.30 319.43 4,050.17 15.44 -170 32.25 4,66 15.43 1.71 5.45 44.33 1842 90.40 MM.IFR-AK-CA-SC(4, 4) 14,700.00 90.35 315.43 4,049.59 15.55 430 33.92 4.49 15.54 1.71 5.43 4621 18.65 90,39 MM -IFR -AK -CA -SC (4,4) 14800.00 90.42 311.43 4,048.90 15.65 -1.69 35.47 4.31 15.65 131 5.41 44.08 18.88 90.37 MPANFR-AK-CA-SC(4.4) 14,830.43 90.44 310.21 4,048.87 15.69 -1.69 35.92 425 15.69 1.71 5.40 44.04 18,94 90.38 MWD+1FR-AK-CA2-SC(4,4) 14,80592 90.44 310.21 4,048.25 15.76 -1.69 35.09 4.25 15.75 1.71 5.38 43.97 19.05 90.35 MWD+1FR-AK-CAASC(4.4) 14890.12 90.00 310.00 4.04820 15.76 -1.71 35,97 4.24 15.76 1.71 5.38 43.95 19.07 90.35 MVA+1FR-AK-CA -SC (4.4) 14,900.00 90.01 309.93 4848.20 15]8 431 35.99 4.24 15.76 131 5.38 43.95 19,07 90.35 MWD+IFR-AK-CQSC.(4,4) 15.000.00 90.33 305.94 4,047.91 15.00 -1.69 37.37 4.03 15,87 1,71 5,35 43.83 19.27 90.38 MWD+1FR-AK-CA -SC (4,4) 15,10.0 90.65 301.95 4,0470 16.01 .1.67 38.62 3.81 15.99 1.71 5.32 43.70 19.44 90.44 MWD+IFR-AKCAZSC(4,4) 15800.00 0.97 297.96 4,045.63 16.14 -1.65 39.71 3.57 16.10 1.71 589 43.58 19.60 90.52 MWD+1FR-AK-CA -SG (4,4) 15.213.08 91.01 297.44 4,045.40 16.16 -1.65 39.84 3.54 111,12 1,71 5.28 43.56 19.61 90.53 MW0+1FR-W-CASC(4,4) 15,300.00 91.01 297.44 4.043.87 16.26 4.65 3939 3.54 16.22 1.71 5.25 43.46 19.73 90.62 MW IFR.AK-CA -SC (4+ 4) 15.400.0 91.01 297.44 4,042.10 1097 -1.65 39.73 3.54 16.33 1.71 5,22 43.34 19.85 0.71 MWD+IFR-AK-CA-SC(4,4) 15,500.0 91.01 297.44 4.040.33 16.49 4,66 39.66 3.54 10.05 1.71 5.19 43.23 19.98 0.83 MWD+IFR-AKCA -SC (4,4) 15,6110.0 91.01 297.44 4,038.58 16.61 -1.65 39.63 3.54 16.57 1.71 5.15 43.13 20.12 0,95 MWD+IFR.AKCAZSC(4, 4) 15,70,110 91.01 297.44 4,03639 16.73 4.05 39.60 3.54 18,89 130 5,12 4304 20.25 91.09 MWWIFR-AK-C -SC (4, 4) 15,80.0 91.01 297.44 4,03502 16.85 .1.65 39.57 3.54 16.81 130 5.09 42.95 20.39 91,24 MWD+IFR.AK-C -SC (4,4) 15.9110.0 91.01 297.44 4.033.26 16.97 4.65 39.55 3.54 16.93 1.70 5.05 4288 20.52 91.40 MWD+IFR-AKCA-SC(4,4) 16,00.0 91.01 297,44 4.031.49 17.0 -1.65 39.54 3.54 17.0 130 5.03 42.79 20.66 91,58 MWWIFR-AKCP-SC (4,4) 10,084.13 91.01 297.44 4,030.00 17.20 -1.65 39.54 3.54 17.16 130 5.00 42.73 20.78 91.74 MWD+IFR-AKCA -SC (1,4) 7WO18 11:22:OOAM Page 7 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-104 Wellbore: Plan: 1H-104 Design: 1H-104wp26 Design Targets Vertical Target Name Depth -hitimiss target Dip Angle Dip Dir. TVD -Shape (") (") (usft) 1H -104T01 D 063018 R 0.00 0.00 3,779.10 - plan hits target center 20"x42" - Circle (radius 100.00) 1,800.00 1 H-104 T02 B 063018 R 0.00 0.00 3,860.10 - plan hits target center 7-5/8" x 9-7/8" - Circle (radius 100.00) 4,030.00 1 H-104 T03 A3 063018 I 0.00 0.00 3,963.10 - plan hits target center - Circle (radius 100.00) 1 H-104 LO T06 063018 1 0.00 0.00 4,007.30 - plan hits target center - Circle (radius 100.00) 1 H-104 LO T05 063018 1 0.00 0.00 4,010.60 - plan hits target center - Circle (radius 100.00) 1 H-104 LO T09 063018 1 0.00 0.00 4,030.00 - plan hits target center - Circle (radius 100.00) 1 H-104 LO T04 063018 1 0.00 0.00 4,032.70 - plan hits target center - Circle (radius 100.00) 1 H-104 LO T08 063018 1 0.00 0.00 4,048.20 - plan hits target center - Circle (radius 100.00) 1 H-104 LO T07 063018 1 0.00 0.00 4,051.40 - plan hits target center - Circle (radius 100.00) 1 H-104 LO T03 063018 1 0.00 0.00 4,062.10 - plan hits target center - Circle (radius 100.00) 1 H-104 T04 Csg 06301 E 0.00 0.00 4,082.10 - plan misses target center by 0.94usft at 9468.49usft MD 1 H-104 LO T02 063018 1 0.00 0.00 4,083.90 - plan hits target center - Circle (radius 100.00) 1 H-104 LO T01 063018 1 0.00 0.00 4,085.50 - plan hits target center -Circle (radius 100.00) Casing Points Measured Vertical 10-314 Depth Depth 9-7/8 (usft) (usft) 118.10 118.10 20"x42" 1,918.25 1,800.00 10 3/4" 9,468.44 4,083.04 7-5/8" x 9-7/8" 16,084.13 4,030.00 4 1 /2' x 6 3/4" Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Name Well Plan: 111-104 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Casing Hole Diameter Diameter 20 42 10-314 13-1/2 7-5/8 9-7/8 4-1/2 6-3/4 7aP2018 11:22:OOAM Page 8 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupt Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 114-104 Wellbore: Plan: 11-1-104 Design: 1H-104wp26 FFormations Measured Depth (usft) 734.39 1,943.60 2,215.40 4,882.02 5,698.06 6,051.79 6,402.02 7,278.79 7,494.02 7,588.41 7,747.15 7,957.00 8,509.18 Vertical Depth (usft) 1,649.10 Base Perm 1,820.10 T-3 2,018.10 K-15 2,901.10 UG_C 3,134.10 UG_B 3,235.10 UG_A 3,335.10 Na 3,585.10 WS_D 3,643.10 WS_C 3,667.10 WS_B 3,705.10 WS—A4 3,750.10 WS—A3 3,855.10 WS A2 Schlumberger Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Name Lithology Well Plan: 11-1-104 Plan: 54.1+39 @ 93.1 Ousft (Doyon 142) Plan: 54.1+39 Q 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Dip Dip Direction (1) (1 0.00 0.00 0.00 0.00 0.00 0.00 703/2018 11:22:OOAM Page 9 COMPASS 5000.14 Build 85 Company: ConocoPhillips(Alaska) Inc.-Kupt Project: Kuparuk River Unit Site: Kupamk 1H Pad Well: Plan: 11-1-104 Wellborn: Plan: 1H-104 Design: 1H-104wp26 Plan Annotations Schlumberger Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 1H-104 Plan: 54.1+39 93.10usft (Doyon 142) Plan: 54.1+39 93.10usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEOMP2 Measured vertical Local Coordinates Depth Depth +N/ -S +E/ -W ''. (usft) (usft) (usft) (usft) Comment 250.00 250.00 0.00 0.00 KOP. Start 1.5/100' OLS, 114.67° TF, for 200' 450.00 449.91 -2.18 4.76 Start 2.5"/100' DLS, 0' TF, for 200' 650.00 648.92 -10.18 22.17 Adjust TF to 0', for 993.16' 1,643.16 1,572.44 -153.65 334.52 Hold for 119.01' 1,762.16 1,672.44 -180.58 393.14 Start 3'/100' DLS, 0° TF, for 156.09' 1,918.25 1,800.00 -218.09 474.83 Hold for 20' 1,938.25 1,815.86 -223.18 485.89 Start 4°/100'DLS, -4.05'TF, for 898.79' 2,837.04 2,317.21 -509.51 1,155.47 Hold far 4340.23' 7,177.27 3,556.45 -2,080.42 5,006.97 Start 4-1100'OILS, -84.75°TF, for 830.63' 8,007.91 3,760.02 -2,150.89 5,797.18 Hold for 100' 8,107.91 3,779.10 -2,131.19 5,893.34 Start 0.04"/100' DLS, 2.79° TF, for 427.88' 8,535.79 3,860.10 -2,046.88 6,304.95 Start 3.47°/100' DLS, -156.48° TF, for 361.87' 8,897.66 3,963.10 -1,962.07 6,640.54 Start 4"/100' DLS, 17.84° TF, for 205.92' 9,103.58 4,028.56 -1,909.32 6,828.38 Hold for 29.77' 9,133.35 4,036.16 -1,902.13 6,856.25 Start 4'/100' DLS, -1.19° TF, for 335.09' 9,468.44 4,082.10 -1,818.58 7,176.55 Hold for 20' 9,488.44 4,082.45 -1,813.48 7,195.89 Start 4°/100' DLS, -81.87° TF, for 128.01' 9,616.45 4,083.87 -1,775.44 7,318.06 Hold for 97.56' 9,714.01 4,084.34 -1,742.35 7,409.83 Start 4°/100' DLS, -89.29° TF, for 679.33' 10,393.34 4,085.50 -1,371.74 7,971.58 Adjust TF to -88.47°, for 13.15' 10,406.50 4,085.48 -1,362.08 7,980.50 Hold for 519.98' 10,926.47 4,084.63 -978.56 8,331.62 Start 4'/100' DLS, 14.01° TF, for 43.96' 10,970.43 4,083.90 -946.25 8,361.42 Adjust TF to -73.8°, for 94.11' 11,064.53 4,060.08 -875.40 8,423.21 Hold for 256.38' 11,320.91 4,067.36 -677.20 8,585.33 Start 4'/100' DLS, -90.64° TF, for 106.9' 11,427.81 4,062.10 -592.10 8,649.78 Adjust TF to -83.92", for 40.94' 11,468.75 4,060.05 -558.28 8,672.75 Hold for 162.37' 11,631.12 4,051.65 -422.86 8,761.94 Start 4'1100' OILS, -92.77°TIF, for 434.49' 12,065.61 4,032.70 -29.96 8,942.50 Adjust TF to -92.83', for 177.25' 12,242.85 4,027.07 142.92 8,980.69 Hold for 477.31' 12,720.17 4,013.45 614.27 91054.63 Start 4-/100' DLS, -97.3° TF, for 123.89' 12,844.05 4,010.60 737.30 9,068.56 Adjust TF to -138.56*, for 21.58' 12,865.64 4,010.35 758.84 9,069.95 Hold for 300.58' 13,166.22 4,008.49 1,058.88 9,087.93 Start 4-/100'OILS, -91.28°TF, for 385.81' 13,552.03 4,007.30 1,442.45 9,059.18 Adjust TF to 172.82', for 205.83' 13,757.86 4,021.95 1,643.47 9,018.34 Hold for 35.24' 13,793.10 4,026.95 1,677.71 9,011.71 Start 4°/100' DLS, -53.93" TF, for 342.49' 14,135.59 4,051.40 2,004.46 8,914.86 Adjust TF to -89.05', for 694.84' 14,830.43 4,048.67 2,561.84 8,511.46 Hold for 55.49' 14,885.92 4,048.25 2,597.66 8,469.08 Start 4°/100' DLS, -154.58' TF, for 12.2' 14,898.12 4,048.20 2,605.52 8,459.75 Adjust TF to -85.35', for 314.94' 15,213.06 4,045.40 2,780.01 8,198.34 Hold for 871.07' 16,084.13 4,030.00 3,181.38 7,425.41 TD: 16084.13' MD, 4030' TVD Checked By: Approved By: Date: 7/3@018 11:22.00AAM Page 10 COMPASS 5000.14 Build 85 Pool Report 1210. July 072018 1 1 H-104wp26 Quarter Mile View -2000 0 2000 4000 6000 8000 10000 12000 14000 West( -)/East(+) (2000 usft/in) 12:14, July 012018 1 H-104wp26 Quarter Mile View 1H402L2 imaw weam mesw 3000 +y -114... �0 O LO 500 0 0 z r 0 3 O U) -1500 1500 3000 J 4500 6000 7500 9000 10500 12000 13500 West( -)/East(+) (1500 usft/in) . . .......... .... . FA im w.mi�_ iwiaz� � �_ ... /�`+ . � �: ... .........sees 1H-104wp26 Surface Location M CPAICoordinate Converter o-�-_ From: – .--- Datum: NAD 83 Region: falaska 11 r Latitude/Longitude IDecimalDegrees C UTM Zone: F_ r South r State Plane Zone: F___-3 Units: us -ft C' Legal Description (NAD27 only) -- Starting Coordinates: X: 11689600.36 Y: 5980534.24 1 H-104wp26 Surface Q CPA[ Coordinate Converfier-_r Datum: NAD83 Region: alaska C Latitude/Longitude IDecimalDegrees C' UTM Zone: r South G State Plane Zone: qUnits: us -ft C' Legal Description (NAD27 only) To:– – Datum: INAD27_j Region: alaska r Latitude/Longitude IDecimalDegrees C UTM Zone: True r South C•- State Plane Zone: q Units: us -ft C Legal Description (NAD27 only) Ending Coordinates: X: 549568.736474514 Y: 5980782.43086254 Transform Quit Help -To: Datum: NAD27 Region: alaska C" Latitude/Longitude IDecimalDegrees, C UTM Zone: True r South G State Plane Zone: F-:-:1 Units: us -ft C' Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X: 11690076.56 X: f 550044.927833547 Y: 5980319.29 Y: r5980567.47692271 .Transform Quit Help 1H-104wp26 Intermediate Casing a CPAI Coordinate Converter -From: ------ To: - Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska . r Latitude/Longitude Decimal Degrees -�r LatitudelLongitude Decimal Degrees f UTM Zone: r South Y- UTM Zone: True F South C•' State Plane Zone: q Units: us -ft . C• State Plane Zone: q Units: us -ft r Legal Description INAD27 only) r Legal Description (NAD27 only) �- Starting Coordinates: x-. F169678799 Ending Coordinates: -, X: 556756.244480063 Y: 15978762.96 i Y: 5979011.07703969 i .Transform ) Quit Help 1H-104wp26 Top of Production Horizon M CPAI Coordinate Converter Datum: NAD83 Region: alaska i Latitude/Longitude IDecimaiDegrees r UTM Zone: r South C• State Plane Zone:�� Units: us -ft r Legal Description (NAD27 only) Starting Coordinates: X 11695527.14 Y: 15978446.26 -To: Datum: NAD27 . Region: alaska r Latitude/Longitude Decimal Degrees (- UTM Zone:True r South C State Plane Zone:q � Units: us -ft r Legal Description (NAD27 only) Ending Coordinates: X: 555495.411490119 Y: 15978694.3883668 Transform Quit Help 1 H-104wp26 TD a. CPAI Coordinate Converter: From: i Datum:NAD83 Region: alaska i C Latitude/Longitude IDecimalDegrees T UTM Zone: r— r South �G State Plane Zone: I' Units: us ft C' Legal Description (NAD27 only) L — Starting Coordinates: — X: 1697004 Y: 5983764 To: Datum: NAD27 D Region: alaska i Latitude/Longitude IDecimal Degrees t' UTM Zone: True r South i G State Plane Zone:F :1 Units: us -ft r Legal Description (NAD27 only) i Ending Coordinates: X: 556972.288517861 Y: F5984011.97374115 J .......................................................... Transform_. ) Quit Help 1H-104wn26 Surface Location t, CPA] Coordinate From: — Datum:NAD83 Region: —D Ialaska r Latitude/Longitude IDecimalDegrees r UTM Zone: r South R State Plane Zone: 4 Units: us -It r Legal Description (NAD27 only) Datum: NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees r UTM Zone: True r South r State Plane Zone: 14 j Units: us -ft r Legal Description (NAD27 only) Starting Coordinates,.--- - --- Legal Description - x 1689600.36 Townshi Range:�� P: 012 N 010 1` -J Y:5980534.24 Meridian: U . Section:28 FNL 5200.5597 FEL - 772.31441 i..._.....__._Transform................: Quit Help 1H-104wp26 Surface Casing From: — - To: Datum: NAD83 Region: alaska r Latitude/Longitude IDecimalDegrees —� r UTM Zone: F_ F South f• State Plane Zone:q Units: us -ft r Legal Descaiption (NAD27 only) Starting Coordinates: XC 1690076.56 Y: 5980319.29 Datum:NAD27 Region: alaska r Latitude/Longitude IDecimalDegfees r UTM Zone: True r South r State Plane Zone: F . Units: us -ft r- Legal Description (NAD27 only) - Legal Township: 01P ry Range:010 E Meridian: U Section: 33 FNL - 138.71385 FEL 297.99407 ........ _........ ...... _....... .... .... ._...._ Transform Quit Help I 1H-104wD26 Intermediate Casing I M CPA -1 Coordinate Converter - rrum. Datum: NAD83 Region: alaska r Latitude/Longitude IDecimal Degrees r' UTM Zone: I— r South fi State Plane Zone:q Units: us -ft r Legal Description (NAD27 onlyl Starting Coordinates: X: 1696787.99 Y: 5978762.98 Datum: NAD27 Region: alaska C Latitude/Longitude IDecimalDegfees r UTM Zone: True r South C' State Plane Zone: --':q Units: us -ft r- Legal Description [NAD27 only) Township: 012 [W:,:] Range: 010 E Meridian:U - Section: 35 FNL1743.0691 ----1FEL , 4160.0312 j Transform Quit Help 1 H-104wD26 Top of Production Horizon CPAs Coordinate Converter From: — Datum: NAD83 . Region: alaska r' Latitude/Longitude IDecimalDegrees r UTM Zone: r— r- South 6 State Plane Zone: q Units: us -ft r' Legal Description (NAD27 only) r- Starting Coordinates: X: 11695527.14 Y: 15978446.26 To: Datum: NAD27 3 Region: alaska r Latitude/Longitude jDecimalDegrees (" UTM Zone: True r South r State Plane Zane: q3 Units: us -ft C Legal Description [NAD27 only) Description Township: 012 N Range: 010 F- -3 -Meridian: I" J Section:34 FNL 2050.3399 FEL 143.73658 Transformer ) Quit Help 1 H-104wp26 TD Cl. CPA? CoordinateConverter :. `ID Datum NAD83 Region: alaska C' Latitude/Longitude IDecimal Degrees f UTM Zone:I r South C• State Plane Zone: q Units: us -ft f Legal Description (P-lN.D27 only) F Starting Coordinates: X: 11697004 Y: 5983764 - To: — Datum: INAD27 I Region: Falaska r Latitude/Longitude rpecimal Degrees • UTM Zone: True r South • State Plane Zone: F---] Units: us.ft r- Legal Description (NAD27 only) Township: 012 [R':,:] Range: 010 Meridian: U Section:26 F[---3 2023.4574 FEL : 3899.7833 Transform _ Quit Help As -built REVI DATE IBYICKIAPPI DESCRIPTION REV DATE BY CK rAPP I DESCRIPTION 1 12/05/01 MRT I CC I I Rev. Per K05014ACS 12 02/01/1A JAH I LGMI Rev. Per K170005ACS N25 30 29 28 27 25 IG 36 31 1B ]Odum _ KCS 32 33 34 35 36 T19MR10F T71N R I OE 6 5 4 3 2 ®12D lA 10 CPFI t0 ��Hf. c ASGRID NORTH 0119 27 8 0118 9 11 00117 40 12 0116 0115 18 7 1 615 14 13 0114 1E LEGEND 0113 0112 IF-ID. ID 24 0111 24 19 20 21 2 23 0 AS—BUILT CONDUCTOR MAP 40110 VICINITY • EXISTING CONDUCTOR 0109 SCALE: 1" = 2 MILES 0104 0108 0103 28 27 33 34 0102 0106 0101 NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSOC. DS1 H 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. *UGNU 01 4. ALL CONDUCTORS ARE LOCATED WITHIN •14 PROTRACTED SECTIONS 28 AND 33, •5 TOWNSHIP 12 NORTH, RANGE 10 EAST, •20 912 UMIAT MERIDIAN, ALASKA. 019 922 011 5. DATES OF SURVEY: 12-26-16 THRU •17 010 1-31-17 FIELD BOOKS L16-35, L16-40, 96 L17-02 & L17-03. •16 •21 915 •13 6. ALL DISTANCES SHOWN ARE GROUND. *1 •9 *2 •7 '3 •18 GRAPHIC SCALE D 100 200 400 •8 •4 1 inch = 200 ft. SEE SHEET 2 & 3 FOR COORDINATE TABLE LOUNSBURY & ASSOCIATES, C. INMRS FN ORS BNCIN88RS pWNN6R5 AREA: IH MODULE: XXXX UNIT: D1 ConocoPhillips WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD RLE N0. DRAWING N0. PART: REV: LK6108d31 2/05/05 CEA—DIHX-6108D31 1 of 3 2 1 1 102/01/171 JAH I LGM 1 (Create Per K170005ACS I I I I I I CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N.. R. 10 E.. UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geographic Coordinates Section Offset. Elev. Y I X Lat. Long. F.S.L F.E.L. O.G. PAD *103 5,980,722.55' 549,573.20' N 70' 21' 29.220" W 149' 35' 50.536" 19' 768' 48.0' 54.1' *104 5,980,782.43' 549,568.74' N 70' 21' 29.809" W 149' 35' 50.655" 79' 772' 48.0' 54.1' *108 5,980,752.52' 549,570.98' N 70' 21* 29.515" W 149' 35' 50.595" 49* 770' 48.0' 54.0' *109 5,980,812.20' 549,566.50' N 70' 21' 30.102" W 149' 35' 50.714" 109' 774' 48.0' 54.0' *110 5,980,842.21' 549,564.40' N 70' 21' 30.398" W 149' 35' 50.770" 139* 776' 48.0' 54.0' *111 5,980,872.05' 549,562.21' N 70' 21' 30.691" W 149' 35' 50.828' 169' 778' 48.0' 54.1' *112 5,980,902.08' 549,559.94' N 70' 21' 30.987" W 149' 35' 50.889" 199' 780' 48.0' 54.0' *113 5,980,932.00' 549,557.76' N 70' 21' 31.281" W 149' 35' 50.947" 229' 782' 48.0' 54.0' *114 5,980,961.86' 549,555.50' N 70' 21' 31.575" W 149' 35' 51.006" 259' 784' 48.0' 54.1' *115 5,980,991.68' 549,553.43' N 70' 21' 31.868" W 149' 35* 51.062" 289' 786' 48.0' 54.1' *116 5,981,021.61' 549,551.58' N 70' 21' 32.163" W 149' 35' 51.110" 319' 787' 48.0' 54.1' *117 5,981,051.73' 549,548.80' N 70' 21' 32.459" W 149' 35' 51.185" 349' 790' 48.0' 54.0' *118 5,981,081.22' 549,546.95' N 70' 21' 32.750" W 149' 35' 51.234" 378' 791' 48.0' 54.0' *119 5,981,111.42' 549,544.52' N 70' 21' 33.047" W 149' 35' 51.299" 408' 794' 48.0' 54.2' *120 5,981,141.33' 549,542.48' N 70' 21' 33.341" W 149' 35' 51.353" 438' 795' 48.0' 54.1- * CONDUCTOR ASBUILT THIS SURVEY OF .��P P .................. ..... 49th .................................... ............................... GI JEREMIAH F. CORNELI LS -12663 ••..................O •� FESSIONA� 10 SURVEYOR'S CERTIFICATE z} �� I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF 00 ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY T� DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION .'w ARE CORRECT AS OF JANUARY 31, 2017. LOUNSBURY do ASSOCTATKS, INC. MORS RNCMRRR9 PI NER9 `./ AREA: IH MODULE: XXXX UNIT: D1 ConocoPhillips DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE N0. DRANING NO. PART: REV: LK6108d31_ 12/27/16 CEA-D1HX-6108D31 3 OF 3 1 Fixed BOP configuration for West Sak Operations Fixed Blind Insult ved Coueuctm Cssing, 20", 419, K55 s 34', 0.312" t/-13d'MD 10.3/4",4559, 480, HY4563 Wellheid I T",.ic, Obi Wellkead/Tnbing Head/Tree' 1H-104 Producer Schematic Planned wo28 TubinB Suint': 4-12. 126b. L-BOTXP Gss Lift Mandrel, 4-12". I' .v/d., valve G. Lift Mandrel. 112" x 1" II dummy valve Gas Lip Mandol, 112'., 1 o SOV Vo" SSD witli 3.812" DB Nipple profile 1918'MID IHOW D Pernenem Dmvu Hole Gauge Tubing Seal Asxmbly U ZXP Pack. H M ' 3,75" He Nipple Profile — S in T' f N e O 2 Stacked Baker Hoak Hanger $w Level 3 Junction Systems r' • L2 "D" Sand Upper lobs Windowa 8142'MD 1378Y 6-31VDsand(L2) lateral ZXP Packer •`•. LIP"$laked Lover and Biaok pipe 1264 L -SO TXPASTM/SLHT 15771'MD/3843'WD ............ . ........................................................................ ..... ...................................................................................... Li 'U Said Lnwa Lobe Windom a 836Y MD 13828' TVD 6.3/4" DIB sand (LD hveral Lamral put, Mwule,,•�`•. 4-12'SIa4d Liner and BlmJ pipe 12.64480 TXPIIBTM/SLHT Mme ............ . 11917 MD 13926'TVD .................. •. ________________________________________________ Tobin, Tubing Scat AattmblY •.... .............................................................................•: •r a 3562'DPNipplcft [c G3p^A1A3 sand(maNbom) & LO ZXP pasha 4-12' Slnllnd Linc, and Blmd Pip, 12.69 TXPISLHT LBO Laterala 16085 MD /4030' TVD — 7-5X% 29]9. LBO, Hvd563, Cs8 __________________________________________________ 9,164 MD 14083' TVD '�____ ____________ _____________•_•_______..........._.______.__.___..............•' IH -104 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Miti tion Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate , Reduced pump rates, Reduced drilling fluid temperatures, Additions of ScreenKleen Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Washouts / Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible Anti -Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with, gym survey to ensure survey accuracy. 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mi ' tion Strategy__ Running Sands and Gravels Low _ Maintain planned mud parameters, increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation materia], stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out. 6-3/4" Open Hole / 4-1/2" Liner Intervals Hazard Risk Level Mitigation Strat Abnormal Reservoir Pressure Low . Stripping drills shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight if possible if pipe does get stuck. Lost Circulation Moderate . Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion ran. Differential Sticking Moderate Follow mud program, keep pipe moving when able. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sbeets), pumping out or backreatnin . Fault Crossings and Concretions Moderate Use developed best practices for concretion drilling. Anti -Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with. Utilize periscope to maintain geological cartainty to stay within zone. Casing wear Moderate Maintain low dog legs in the surface interval and utilize super sliders for drilling, milling, and liner rowing operations to minimize casing wear. Consider logging casing thickness to calibrate casine wear model. Getting Liner to Bottom - Moderate Properly clean hole on the trip out with the BHA, perform clean out run if necessary, utilize super sliders for weight transfer, monitor torque and drag. Whipstock Retrieval Moderate A dedicated clean out ran prior to attempting to pull wbipstock can be used to reduce the risk of fishing o erations. 1H-104 Ddsing Hazartls Summary.doc 5511WO18 4:42:08 PM gr _ ! M'II I Drillw� DRAWN JlC ConocoPhllllps TITLE: D51H LAYOUT DRAWING Alaska, Inc. DRAWN BY: ALKET MICI DAIS 9, mts Rer � AOGCC PTD No. 218-084 Coordinate Check 23 July 2018 INPUT Geographic, NAD27 KRU 111-104 Latitude: 70 21 29.80900 Longitude: 149 35 50.65500 OUTPUT State Plane, NAD27 5004 -Alaska 4, U.S. Feet 1/1 Northing/V: 598 0782 .3 97 Easting/X: 549568.722 Convergence: 0 22 45.01443 Scale Factor: 0.999902791 Remark: Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: X�;eY1 /17 < –10 PTD: �'" s7 /Development —Service —Exploratory _ Stratigraphic Test —Non -Conventional FIELD:i 7� <tr u /� / I% _ POOL: J 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- be as a function of the original (If last two digits Production should continue to reported 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- from records, data and logs acquired for well name on ermit). 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 PTD#:2180840 Company CONOCOPHILLIPS ALASKA, INC. Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 17 Nonconven, gas conforms to AS31,05,030(j. 1..A),(].2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate_ _ Yes Surf Loc & Top Prod Int lie in ADL0025639; TO lies. in ADL0025638.. 3 Unique well. name and number _ _ Yes Yes.- Previous application for IH -104 (PTD #218-061) was cancelled per email from S. Brunswick, 4 Well located in. a. defined pool _ _ _ _ _ Yes . CPAI, rescinding permit. Kuparuk River, West Sak Oil Pool - 490150, governed by CO 406C _ 5 Well located proper distance from drilling unit. boundary Yes CO 4060, Rule 3; no restrictions as to well spacing except that no pay shall be opened in a well closer 6 Well located proper distance from other wells Yes than 500 feet to. an external property line where ownership or landownership changes....... 7 Sufficient acreage available in. drilling unit Yes _ _ _ As planned, well conforms to spacing requirements.. _ 8 If deviated, is wellbore plat. included _ Yes _ 9 Operator only affected party.. _ _ Yes 10 Operator hasappropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative. approval Yes SFD 7/23/2018 _ _ 13 Can permit be approved before 15 -day wait_ _ _ _ _ _ Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in. comments) (For! NA 15 All wells. within 1/4_ mile area of review identified (For service well only) _ NA 16 Pre -produced injector; duration of pre production less than 3 months (For service Welt only) . NA 18 Conductor string provided _ _ _ ....... .. Yes 80' conductor provided _ Engineering 19 Surface casing. protects all. known USDWs _ _ Yes Surface casing set at 1918' MD 20 CMT vol adequate to circulateon conductor & surf csg Yes 217%. excess 21 CMT vol adequate to tie-in long string to surf csg. No 22 OMT will cover all known productive horizons.. No Productive interval will be completed with. an uncemented slotted liner 23 Casing designs adequate for C, T, B 8. permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste. to approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures _ 27 If d]verter required, does it meet regulations. Yes _ Diverter and. route meet regulation... Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is. 1767 psig(8.4 ppg EMW ); will drill w/ 8.8-9.5 ppg EMW VTL 8/1/2018 29 BOPEs,_do they meet regulation Yes 30 BOPE.press rating appropriate; test to (put psig in comments) _ _ _ Yes _ _ MPSP is 1364 psig; will test BOPs to 3500 psig. 31 Choke manifold complies w/API. RP -53 (May 84)... Yes _ _ _ _ _ ...... 32 Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ Yes 33 Is presence of H2S gas probable Yes H2S measures required_ 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No H2S measures required. Well 1H-102_measured 20 ppm H2S on. November 20, 2017. Geology 36 Data. presented on potential overpressure zones Yes _ _ _ _ Expected reservoir pressure is -8.4 ppg EMW: will be drilled with 8.8 - 9.5 ppg mud. _ Appr Date 37 Seismic analysis of shallow gas. zones No _ _ No shallow gas expected. Some risk of encountering gas hydrates while drilling surface hole. SFD 7/23/2018 38 Seabed condition survey (if off -shore) _ _ NA _ Moderate potential for Jost circulation, differential sticking, swabbing, and fault crossing issues..... 39 Contact name/phone for weekly progress reports [exploratory only] NA _ Mitigation measures discussed in Drilling Hazards Summary. Geologic Engineering Public Commissioner: Date: Commissione Date oner Date