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Home My WebLink About220-047Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/10/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260210 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 224-34T 50283202050000 225044 1/30/2026 AK E-LINE Perf T41349 CLU 11RD 50133205590100 225013 1/24/2026 AK E-LINE Perf T41350 CLU 11RD 50133205590100 225013 1/27/2026 AK E-LINE Plug/Perf T41350 KU 24-07RD2 50133203520200 225126 1/14/2026 AK E-LINE CBL T41351 KU 24-07RD2 50133203520200 225126 1/20/2026 AK E-LINE IPFOF T41351 MPI 2-74 50029237850000 224024 1/25/2026 AK E-LINE Whipstock T41352 MPU 1-36 50029236770000 220047 2/1/2026 AK E-LINE Packer T41353 MPU R-110 50029238260000 225085 10/24/2025 YELLOWJACKET RCBL T41354 NFU 14-25 50231200350000 210111 12/29/2025 YELLOWJACKET CBL T41355 SDI 3-15 50029217510000 187094 1/23/2026 AK E-LINE Whipstock T41356 SRU 214A-27 50133101580100 225133 2/4/2026 YELLOWJACKET SCBL T41357 SRU 231-33 50133101630100 223008 7/31/2025 YELLOWJACKET PLUG-PERF T41358 SRU 242-16 50133204050000 188157 1/24/2026 YELLOWJACKET PLUG-PERF T41359 SU 43-10 50133207390000 225107 1/19/2026 YELLOWJACKET GPT-PLUG- PERF T41360 SU 43-10 50133207390000 225107 12/31/2025 YELLOWJACKET SCBL T41360 Please include current contact information if different from above. MPU 1-36 50029236770000 220047 2/1/2026 AK E-LINE Packer Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.10 14:51:05 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 T41319MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Convert to JP 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 14,265 feet N/A feet true vertical 3,958 feet N/A feet Effective Depth measured 13,222 feet 4,301' & 5,080'feet true vertical 3,949 feet 3,658' & 3,805'feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / TXPM 5,065' 3,804' Packers and SSSV (type, measured and true vertical depth)Permanent TNT & SLZXP LTP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone:777-8520 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 4,760psi 3,950' Burst N/A 6,870psi 5,750psi 6,890psi7-5/8" 1,992' 3,817' 3,806' 3,090psi 4,790psi 2,077' 3,187' Surface Surface measured 5,086' 8,164' Junk measured true vertical Packer Liner Casing Conductor Length 4-1/2" 5,086' 13,244' 20" 9-5/8" 9-5/8" 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1,356 Gas-Mcf 300 Casing Pressure Tubing Pressure 161 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 312-140 354 Authorized Signature with date: Authorized Name: Ian Toomey itoomey@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 220-047 50-029-23677-00-00 Plugs ADL0025906 & ADL0315848 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 869 Representative Daily Average Production or Injection Data 3173,456 Oil-Bbl measured WINJ WAG 136 Water-Bbl MD 107' 2,077' 5,264' N/A Tieback TVD 107' 851 Hilcorp Alaska, LLC Size 107' 2,375 MILNE PT UNIT I-36 N/A Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 10:10 am, May 10, 2021 321 Chad Helgeson (1517) 2021.05.10 09:11:02 - 08'00' SFD 5/10/2021MGR30JUL2021 RBDMS HEW 5/12/2021 DSR-5/10/21 _____________________________________________________________________________________ Revised By: DH 5/4/2021 SCHEMATIC Milne Point Unit Well: MPU I-36 Last Completed: 4-12-2021 PTD: 220-047 TD = 14,265’ (MD) / TD =3,958’ (TVD) 5 20” Orig. KB Elev.: 60.19’ / GL Elev.: 33.6’ 7-5/8” 11 4 11 9-5/8 ” 1 2 3 See Screen/ Solid Liner Detail PBTD = 13,222’ (MD) / PBTD =3,949’ (TVD) 9-5/8” ‘ES’ Cementer @ 1935’ MD 4-1/2” Shoe @ 13,222’ 9 & 10 6 8 7 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5# / X56 / Weld N/A Surface 107’ N/A 9-5/8" Surface 47# & 40# / L-80 / TXP 8.525 26’ 5,264’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 25’ 5,086’ 0.0459 4-1/2” Liner 13.5 / L-80 / Hyd 625 3.920 5,080’ 13,244’ .0149 TUBING DETAIL 4-1/2" Tubing 12.6# / L-80 / TXPM 3.958 Surface 5,095’ 0.0152 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 – Lead – 450 sx / Tail – 400 sx Stg 2 – Lead – 525 sx / Tail – 270 sx 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 320’ Max Hole Angle = 93.05° @ 8780’ MD TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead FMC 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23677-00-00 Completion Date: June 10, 2020 Convert to Jet Pump: 4-12-2021 JEWELRY DETAIL No. Top MD Item ID 1 22’ 11” x 4-1/2” TCII Tubing Hanger 3.958” 2 4,226’ Gauge Carrier 3.9” 3 4,232’ Sliding Sleeve 3.81” 4 4,238’ Ported Pressure Sub 3.95” 5 4,301’ Permanent Packer, Halliburton TNT 3.856” 6 4,368’ XN Nipple, 3.813” Profile, 3.750” No Go 2.75” 7 5,070’ 7-5/8” Tieback Assy. 8 5,080’ BOT SLZXP LTP / Liner Hanger 7” x 9-5/8” (TVD 3805’) 6.190” 9 5,065’ WLEG – Bottom @ 5,095’ 3.958” 10 5,101’ 7” H563 x 4.5” Hyd 625 XO 3.850” 11 13,222’ Shoe 3.950” 4-1/2” LINER 250ђ SCREEN DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 65 5,272’ 3816’ 7,986’ 3838’ 5 8,314’ 3867’ 8,523’ 3888’ 27 8,772’ 3891’ 9,900’ 3899’ 77 9,982’ 3895’ 13,180’ 3949’ 4-1/2”SOLID LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 45,080’3805’5,272’3816’ 87,986’3838’8,314’3867’ 68,523’3888’8,772’3891’ 2 9,900’ 3899’ 9,982’ 3895’ Well Name Rig API Number Well Permit Number Start Date End Date MP I-36 Innovation 50-029-23677-00-00 220-047 4/8/2021 4/16/2021 Post scope derrick inspection. Cont. working on mud pumps. Work on rig acceptance checklist. Take on seawater. Rig up flow back tank. Rig up on tree to bleed gas cap from tubing and IA. Tubing = 150psi, IA=300 psi. Swap to high line power at 11:00. Rig accepted at 10:00. PT lines to flow back tank. Bleed tubing and IA to 0 psi. Well on vac. Line up and pump 280 bbls down the tubing, no returns, no pressure build. Well still on vac. Blow down and R/D circulation hoses. Install BPV with CTS. Break bolts and remove tree from wellhead. Install control line plug. Clean and check hanger threads - good. 7.5 turns with XO. P/U DSA, spacer spool and BOP stack and set on wellhead. TQ all connections with sweeny wrench. Install bell nipple and riser. Hook up hole fill line. Cross chain and center stack. Hook up choke and kill line and tighten flange connections. Open LPR doors and C/O upper seal on both rams. Install drain hoses. Safe out cellar. Energize accumulator. Function test BOPE. Obtain RKB's. Sim Ops: grease choke manifold and all cellar valves. Bring on seawater. C/O oil in degasser and risers. Process 4-1/2" TXP pipe. P/U and M/U XO, pump in sub, TIW and dart. P/U and get marks for LPR's, UPR's, and annular on donut test joints. M/U test sub to TD and test joints. Fill and flood stack and surface lines. Attempt body test on BOPE, leak on choke and kill flanges. Tighten flanges. Re-purge air. Perform shell test. Test BOPE: LPR, Dart and upper IBOP 250/2500 psi on 4-1/2" test joint - good. Matt Herrara waived witness. Observe spacer spool/BOP flange leaking on second test. Attempt to tighten, unable to. Pull test joint, remove air from boot. Break stack at spacer spool. Inspect API ring and observe grooves throughout face. Replace with new API and torque connection,Fill stack and lines, purge air. Perform shell test - good. 4/10/2021 4/9/2021 Continue moving rig, stomping to middle rig mats, turn sub 90°, hook up tow bar, truck and dozer move rig out of way, pull mats from I-20. Lay rig mats for sub on I-36. Spot sub in front of I-36. Hook up rear stearing arms, disconnect hydraulic lines and remove rear tires from sub base. Turn sub 90° and walk sub base over I-36. Spot, shim and level sub base. Hook up and set cattle chutes, pipe shed, md mod. Disconnect envirovac from gen mod. Start to spot gen mod. SimOps: Set outriggers, turn and retract stompers and set down on mats. Lower stairs and scope out cattle chute. Rig up pipe shed interconnect. Clean steam trap discs. Remove mats and herculite and clean around I-20. Continue spotting gen mod. Rig up steam lines and interconnects. Apply steam to rig. Assist electrician. Rig up break shack and cuttings box. Move flow back tank into position and install heater on manifold. Scope derrick. Plug in and verify derrick lights work. Bridle down. Put mud pumps back together. Hilcorp Alaska, LLC Weekly Operations Summary 4/8/2021 Finish rigging down steam, air and interconnects. Pull and secure stairs and landings. Trucks on location at 00:30. Hook up trucks. Split rig apart: Pull pipeshed, Gen Mod, Mud mod and cattle chute and stage on pad. Begin walking sub base off MP I-20. Well Name Rig API Number Well Permit Number Start Date End Date MP I-36 Innovation 50-029-23677-00-00 220-047 4/8/2021 4/16/2021 Hilcorp Alaska, LLC Weekly Operations Summary RIH with 4-1/2", 12.6#, L-80, TCP jet pump completion as per tally from 3138' to 5094'. Cont. to run cannon clamps every other joint, total 63 clamps. Test Baker gauge every 1000', observe 78 psi at 2127', and 457 psi at 3138'. M/U hanger and feed Tec wire through. PUW 81K, SOW 68K. Fill IA with 20 bph seawater. Pick hanger off seat, close annular. Pump 135 bbls corrosion inhibited seawater down backside at 4 bpm, no pressure. Land hanger, RILDS. Open IA to Little Red and pump 65 bbls diesel for freeze protect. Drop ball and rod. Start filling tubing up, allowing air to break out. Close bag and fill choke. Pressure up to 3500 psi to set Halliburton TNT packer. Pressure test tubing to 3500 psi/30 minutes - good. Bleed tubing down to 2500 psi. LRS fill IA with diesel, bleed and purge air. Pressure test IA to 3500 psi/30 minutes - good. Allow air to break out of tubing. Set BPV. Sim Ops: Rig down 4-1/2" tubing equipment. Rig down Weatherford, Centrilift. Clean and clear rig floor. N/D BOPE: flush choke, kill and stack. Blow down all surface lines. Suck out stack. De-energize accumulator and disconnect lines from stack. R/D choke and kill lines. Hook up bridge cranes and disconnect cross chains. Let air out of boots and pull riser to floor. Break all flange connections on spacer spool, DSA, and bottom of stack. Rack stack back on pedestal and chain off. Remove spacer spool and DSA from wellhead. Sim Ops: Blow down all pit and pump room lines. Begin cleaning pits. Take apart MP2 for inspection. Check/air up tires. N/U tree: Wellhead rep clean well head hanger void and fill with oil. Install CTS plug in BPV. N/U tree and torque. Perform final test on TEC wire - good. Test hanger void 500/5000 psi - good 10 minutes each. Test tree 250/5000 psi - good. Remove CTS and BPV. Sim Ops: Finish cleaning pits. Prep pump room for rig move. Bridal up, unplug and prep derrick for scope down. Scope derrick down. Raise cattle chute. Hook up wenches to all landings and flip roof caps. Blow down steam system. Disconnect remaining interconnects. Unplug and swap to cold start power at 23:30. Remove cuttings tank. Raise outriggers. Begin jacking up Gen Mod. Rig Released at 00:00. Final report for I-36. 4/11/2021 Cont. Test BOPE's 250/2500 psi with 3-1/2" and 4-1/2" test joints. Witness waived by AOGCC Matt Herrera. Test PVT alarms, flow paddle. Accumulator drawdown: starting pressure 3000 psi, final 1450 psi, first 200 psi recharge 25 sec, full recharge 95 sec. (6) N2 bottle backup at 2341 psi average. Blow down choke and kill lines. Clean and clear rig floor. Pick up T-bar. Pull CTS. Close blinds and pump 30 bbls down the tubing 2 bpm, 50 psi no returns. Tubing on vac. Pull BPV. Rig up to POOH with ESP completion. Pick up centrilift job box and tools. Make up landing joint and screw into hanger. BOLDS, unseat hanger with no overpull, PUW 80K. Pump 149 bbls down IA at 3 bpm, no pressue, no returns. Disconnect penetrator from hanger and crimp as per Baker rep. L/D hanger and landing joint. Hang ESP sheave and elephant truck in derrick. Feed rope through sheave/trunk and connect to spooling unit. Rig up power tongs, prep floor to POOH. POOH with 3-1/2" ESP completion to surface. P/U and disonnect moto lead. L/D all ESP components as per Centrilift. Perform diagnostic test and determine motor failure. L/D total 155 joints, XN nipple, 2 GLM's, 90 cannon clamps, and 8 pump/seal clamps. Add 20 bbls seawater down backside every hour. No returns. R/D spooling unit, derrick sheave and elephant trunk. Clean and clear rig floor of cannon clamps, thread protectors and all unnecessary tools and equipment. L/D 3-1/2" handling equipment. P/U 4.5" slips/elevators. Break XO's off landing joint. Bring clamps up for 4-1/2" run. Cont. to R/U to run 4- 1/2" jet pump. Rig up Weatherford power tongs, pick up Tec wire spooler and rig up with sheave. Rig up clamp running tools. Verify pipe count/order in shed. RIH with 4-1/2", 12.6#, L-80, TCP jet pump completion as per tally from surface to 3138'. Connect 1/4" cap line from ported sub to gauge. Connect TEC wire to gauge and run cannon clamp every joint for first 20 joints then every other joint. Test Baker gauge every 1000'. 4/12/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP I-36 Innovation 50-029-23677-00-00 220-047 4/8/2021 4/16/2021 Hilcorp Alaska, LLC Weekly Operations Summary 4/15/2021 WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2500H. RUN 4-1/2 42BO AND OPEN XD-SS AT 4225' SLM/4231' MD (pin not sheared, see ~200PSI pressure change). PULL BALL & ROD FROM RHC IN XN-NIP AT 4354' SLM (looks good, TBG & IA go on a vac). L/D FOR THE NIGHT, NOTIFY PAD-OP. CONTINUE TICKET 04-16-21. 4/16/2021 CONTINUE TICKET FROM 04-15-21. WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2500H. PULL 4-1/2 RHC FROM XN-NIP AT 4360' SLM/4367' MD (looks good, recovered all packing & nubbins). SET 3" JET PUMP (serial# BP-1133, ratio: 13B, sec lock, screen, OAL=70") IN XD-SS AT 4225' SLM/4231' MD (recovered all pins). RDMO, CLOSE PERMIT W/PAD- OP, TAG WELL. Well support techs set foundation, production lines and R/U hardline from the header and I-40 for production fluid. Pressure tested hardline and power fluid line to 4000 psi and production piping to 1150 psi. Set wellhouse, wrapped hardline with visqueen and installed heaters. 4/14/2021 1 Winston, Hugh E (CED) From:Carlisle, Samantha J (CED) Sent:Friday, March 19, 2021 2:19 PM To:Winston, Hugh E (CED) Subject:FW: [EXTERNAL] RE: PTD# 220-047; MPU I-36 From: Ian Toomey ‐ (C) <itoomey@hilcorp.com> Sent: Friday, March 19, 2021 1:51 PM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Subject: RE: [EXTERNAL] RE: PTD# 220‐047; MPU I‐36 Mel, Sounds good, we will cancel the sundry 320‐353 and I will be submitting a new sundry soon. Regards, Ian Toomey | Operations Engineer Hilcorp Alaska, LLC | Milne Point Office: 907‐777‐8520 Cell: 907‐903‐3987 From: Rixse, Melvin G (CED) [mailto:melvin.rixse@alaska.gov] Sent: Friday, March 19, 2021 1:30 PM To: Ian Toomey ‐ (C) <itoomey@hilcorp.com> Cc: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Subject: [EXTERNAL] RE: PTD# 220‐047; MPU I‐36 Ian, I would prefer to cancel the Sundry and submit a new one for the jet pump. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907‐793‐1231 Office 907‐223‐3605 Cell CONFIDENTIALITY NOTICE: This e‐mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e‐mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907‐793‐1231 ) or (Melvin.Rixse@alaska.gov). From: Ian Toomey ‐ (C) <itoomey@hilcorp.com> Sent: Friday, March 19, 2021 10:43 AM RBDMS HEW 3/25/2021 2 To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: PTD# 220‐047; MPU I‐36 Mel, We currently have an approved sundry (#320‐353) to pull and replace the ESP. Due to the poor ESP performance we have decided to change the completion to jet pump. Would you prefer to cancel sundry 320‐353 and submit a new sundry or would you prefer to use the current sundry with an updated procedure? Regards, Ian Toomey | Operations Engineer Hilcorp Alaska, LLC | Milne Point Office: 907‐777‐8520 Cell: 907‐903‐3987 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 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? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 14,265'N/A Casing Collapse Conductor N/A Surface 4,760 psi Surface 3,090 psi Tie-Back 4,790 psi Liner (screens)8,540 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: 8/21/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 9/1/2020 13,244'8,164' 3-1/2" 3,950' SLZXP LTP and N/A Authorized Title: Operations Manager Authorized Name: Chad Helgeson 5,086' Perforation Depth MD (ft): 5,264' See Schematic 5,086' 4-1/2" Perforation Depth TVD (ft): Tubing Size: 3,806' 107' 2,077 7-5/8" 20" 9-5/8" 107' 9-5/8"3,187' 2,077' 5,750 psi N/A 6,870 psi 107' 1,992' 3,826' Hilcorp Alaska, LLC Milne Point Field / Schrader Bluff Oil Pool MPU I-36 PRESENT WELL CONDITION SUMMARY 9.3# / L-80 / EUE 8rd TVD Burst 5,043' 6,890 psi MD 5,080' MD / 3,805' TVD and N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025906, ADL315848 220-047 3800 Centerpoint Drive, Suite 1400, Acnhorage, AK 99503 C.O. 477.05 50-029-23677-00-00 Size COMMISSION USE ONLY 9,020 psi Tubing Grade: Tubing MD (ft): See Schematic Other: Install Jet Pump Ian Toomey itoomey@hilcorp.com 777-8520 3,958' 13,222' 3,949' 1,093 N/A Length ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:51 am, Mar 22, 2021 321-140 Chad Helgeson (1517) 2021.03.19 15:52:01 - 08'00' MGR24MAR21 X 10-404 DSR-3/22/21 BOPE test to 2500 psi. DLB 03/22/2021 Com m. 3/24/21 dts 3/24/2021 JLC 3/24/2021 RBDMS HEW 3/25/2021 Convert to JP Well: MPU I-36 Date: 03-19-21 Well Name:MPU I-36 API Number:50-029-23677-00 Current Status:SI Producer (ESP Failed)Pad:I-Pad Estimated Start Date:March 27 th, 2021 Rig:Innovation Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:220-047 First Call Engineer:Ian Toomey (907) 777-8343 (O) (907) 903-3987 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:Job Type:Convert to JP Current Bottom Hole Pressure:1,250 psi @ 3,802’ TVD Downhole Gauge: PBU |6.4 PPG Maximum Expected BHP:1,473 psi @ 3,802’ TVD 30-day PBU Extrapolation |7.5 PPG MPSP:1,093 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 90+° from 5,264’ MD Max Dogleg:9.14°/100ft at 4,323’ MD Tree:Cameron 3-1/8” 5M Wellhead:FMC, 11” 5M, Gen 5 Tubing Hanger Lift threads:3-1/2” TC-II top & bottom BPV Profile:3” CIW Type H Brief Well Summary: MPU producer I-36 was drilled and completed by the Innovation rig in June 2020. The well was POP on 6/19/20 and the ESP failed 3/18/21. Notes Regarding Wellbore Condition x The 7-5/8” x 9-5/8” annulus passed an MIT to 1,000 psig on 6/11/2020. x Offset Injector Support o I-35 & I-37: OL Objective: x Pull 3-1/2” ESP completion. x Install new EPS components, re-run pulled 3-1/2” tubing and setting the new ESP higher in the well with less inclination. Pre-Rig Procedure: 1. RU Slickline unit 2. Pull OV from GLM at 130’ and install DV. 3. Pull DV from GLM at 4,302’ MD. Leave pocket open. 4. RD Slickline Unit 5. RU LRS and PT lines. 6. Pump 1 IA volume (173 bbls) with hot 8.3 ppg source water down IA. 7. Bullhead 44 bbls of 8.3 ppg source water down tubing to the formation. 8. RD well house and flowlines. Clear and level pad area around well. Spot rig mats and containment. 9. Confirm well is dead. Freeze protect tubing/casing as needed. a. Due to the low reservoir pressure, the tubing freeze protect should not be needed. Convert to JP Well: MPU I-36 Date: 03-19-21 b. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the rig. 10. RD LRS. 11. RU crane. Set 3” HP BPV. ND Tree. Inspect the lift threads on the tubing hanger. Install the plug off tool into the BPV. 12. NU dry hole tree. RD crane. RWO Procedure: 13. MIRU Hilcorp Innovation Rig, ancillary equipment and lines to returns tank. 14. ND the dry hole tree and NU the BOP stack. 15. Test BOPE to 250/2,500 psi and annular to 250/2,500 psi. a. Notify AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR’s and annular with 3-1/2” & 4-1/2” test joints. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency:If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test if the test witness was waived. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 16. RU to pull 3-1/2” ESP completion. 17. Pull the plug off tool, check for pressure under the BPV, if needed kill the well with 8.3 ppg source water and pull the BPV. 18. MU landing joint or spear. BOLDS, unseat the tubing hanger and pull to the rig floor. a. PU = 85K and SO = 62K with block weight of 35K when landed by Innovation in 9.5 ppg brine. 19. Lay down the landing joint and tubing hanger. RU to pull ESP cable over sheaves to spooling units. a. Inspect the tubing hanger and note any corrosion or damage. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger or test plug in tubing head. Test BOPE per standard procedure and sundry. 20. POOH standing back the 3-1/2” tubing spooling ESP cable and removing all jewelry as it presents itself. Lay down ESP components. a. Note any corrosion, sand, or scale on the tubing with associated depths and ESP components on the morning report. Convert to JP Well: MPU I-36 Date: 03-19-21 Equipment Disposition Tubing hanger Clean, dope and restock Tubing & Pup joints Clean, dope and restock Gaslift Mandrels/Nipple Clean, dope and restock ESP equipment/Power Cable Centrilift to take possession for inspection and teardown Cannon clamps (90)Clean and restock Seal clamps (4)Clean and restock Pump clamps (4)Clean and restock 21. RD ESP pulling equipment. 22. RU to run 4-1/2” JP completion. 23. PU and MU the following completion. a. WLEG/Mule shoe (~5,095’) b. XX joints, 4-1/2”, 12.6#, L-80, TXPM c. Nipple, 3.813” XN profile (3.750” no-go), 4-1/2”, TXPM (RHC plug body installed), with 10’ handling pups d. 1 joint, 4-1/2”, 12.6#, L-80, TXPM e. Pup joint, 1 joint, 4-1/2”, 12.6#, L-80, TXPM f. Crossover, 4-1/2” Vam Top Box x 4-1/2” TXP Pin g. Permanent Packer, Halliburton TNT, 4-1/2”, 12.6#, L-80 Vam Top (setting depth ~4,386’) h. Crossover, 4-1/2” TXPM Box x 4-1/2” Vam Top Pin i. Pup joint, 4-1/2”, 12.6#, L-80, TXPM j. 1 joint, 4-1/2”, 12.6#, L-80, TXPM k. Pup joint, 4-1/2”, 12.6#, L-80, TXPM l. Crossover, 4-1/2” EUE 8rd Box x 4-1/2” TXP Pin m. Ported Pressure Sub, 4-1/2”, 12.6#, L-80, EUE 8rd n. Crossover, 4-1/2” TXPM Box x 4-1/2” EUE 8rd Pin o. Pup joint, 4-1/2”, 12.6#, L-80, TXPM p. Crossover, 4-1/2” H521 Box x 4-1/2” TXP Pin q. Sliding Sleeve, 4-1/2”, 12.6#, L-80 Hydril 521 r. Crossover, 4-1/2” TXPM Box x 4-1/2” H521 Pin s. Pup joint, 4-1/2”, 12.6#, L-80, TXPM t. Crossover, 4-1/2” EUE 8rd Box x 4-1/2” TXP Pin u. Gauge Carrier, 4-1/2”, 12.6#, L-80, EUE 8rd v. Crossover, 4-1/2” TXPM Box x 4-1/2” EUE 8rd Pin w. Pup joint, 4-1/2”, 12.6#, L-80, TXPM x. XXX joints, 4-1/2”, 12.6#, L-80, TXPM 24. PU and MU the 4-1/2” tubing hanger. Make final splice of the TEC wire and ensure any unused control line ports are dummied off. 25. Land tubing hanger and RILDS. Lay down landing joint. Record PU and SO weights on the tally and WellEZ. Convert to JP Well: MPU I-36 Date: 03-19-21 26. Set 4” HP BPV. 27. ND BOPE. Install the plug off tool. 28. NU the tubing head adapter and NU dry hole tree. 29. PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 30. Pull the plug off tool and BPV. 31. Reverse circulate the well over to corrosion inhibited source water follow by diesel freeze protect to 2,500’ MD. 32. Drop the ball & rod. 33. Pressure up on the tubing to 3,500 psi to set the packer. PT the tubing to 3,500 psi for 30 minutes (charted). 34. Bleed the tubing pressure to 2,000 psi and PT the IA to 3,500 psi for 30 minutes (charted). Bleed both the IA and tubing to 0 psi. 35. Turn well over to production via handover form. Post-Rig Procedure: 36. Set 4” H BPV. 37. ND the dry hole tree 38. NU 4-1/16”, 5M tree. PT the tree to 250/5000 psi. 39. Pull BPV. 40. Replace gauge(s) if removed. 41. RU well house. 42. RU slickline. 43. Shift the sliding sleeve open. 44. Pull the ball & rod and RHC plug body. 45. Install the JP. 46. RD slickline. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Blank RWO MOC Form _____________________________________________________________________________________ Edited By: JNL 7-9-2020 Schematic Milne Point Unit Well: MPU I-36 Last Completed: 6-10-2020 PTD: 220-047 TD =14,265’(MD) / TD = 3,958’ (TVD) 4 20”00 Ori g. KB Elev.: 60.19’ / GL Elev.: 33.6’ 7-5/8”7/8 9/10 11 4 17 9-5/85”88 1 2 3 See Screen/ Solid Liner Detail PBTD = 13,222’ (MD) / PBTD = 3,949’ (TVD) 9-5/8” ‘ES’ Cementer @ 1935’ MD 5/6 4-1/2” Shoe @ 13,222’ 12 14 1315 16 3-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"Conductor 129.5# / X56 / Weld N/A Surface 107’N/A 9-5/8"Surface 47# & 40#/ L-80 / TXP 8.525 26’5,264’0.0758 7-5/8”Tieback 29.7 / L-80 / Hyd 521 6.875 25’5,086’0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 5,080’ 13,244’ .0149 TUBING DETAIL 3-1/2"Tubing 9.3 / L-80 / EUE-8rd 2.992 22’ 5,043’0.0087 OPEN HOLE / CEMENT DETAIL Conductor±270 ft3 12-1/4" Stg 1 –Lead –450 sx / Tail –400 sx Stg 2 – Lead – 525 sx / Tail – 270 sx 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 320’ Max Hole Angle = 93.05° @ 8780’ MD TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23677-00-00 Completion Date: June 10, 2020 4-1/2”SOLID LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 4 5,080’3805’5,272’ 3816’ 8 7,986’3838’8,314’ 3867’ 6 8,523’3888’8,772’ 3891’ 2 9,900’3899’ 9,982’3895’ JEWELRY DETAIL No.Top MD ItemID 1 130’GLM: 3-1/2” x 1” w/ Dual Flo OV 2.915” 2 4302’ GLM w/Dummy: 3-1/2” x 1” 2.920” 3 4,3611’2.813” XN Nipple, 2.75” no go 2.750” 4 4,978’Discharge Head: PMP 513 5 4,979’ Upper Tandem Pump: Zenith Ported Sub 513/539P 6 4,980’Lower Tandem Pump: 538PM SXD 086 7 5,000’ Gas Separator: 538 8 5,005’ Gas Avoider 513HS 9 5,008 Upper Tandem Seal: GSB3DBUT SB/SB PFSA 10 5,015’Lower Tandem Seal: GSB3DBUT SB/SB PFSA 11 5,021’Motor: CL5 XP –250hp / 2505V / 61A 12 5,038’Sensor, Zenith 13 5,040’ Centralizer: Bottom @ 5043’ 14 5,080’BOT SLZXP LTP / Liner Hanger 7” x 9 -5/8” (TVD 3805’)7.375” 15 5,070’7-5/8” Tieback Assy.6.180” 16 5,101’ 7” H563 x 4.5” Hyd 625 XO 3.840” 17 13,222’Shoe - 4-1/2” Screens LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 65 5,272’3816’ 7,986’3838’ 5 8,314’3867’ 8,523’3888’ 27 8,772’3891’ 9,900’3899’ 77 9,982’3895’13,180’3949’ _____________________________________________________________________________________ Revised By: TDF 3/19/2021 PROPOSED Milne Point Unit Well: MPU I-36 Last Completed: 6-10-2020 PTD: 220-047 TD = 14,265’ (MD) / TD =3,958’ (TVD) 5 20” Orig. KB Elev.: 60.19’ / GL Elev.: 33.6’ 7-5/8” 11 4 11 9-5/8 ” 1 2 3 See Screen/ Solid Liner Detail PBTD =13,222’ (MD) / PBTD =3,949’ (TVD) 9-5/8” ‘ES’ Cementer @ 1935’ MD 4-1/2” Shoe @ 13,222’ 9 & 10 6 8 7 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5# / X56 / Weld N/A Surface 107’ N/A 9-5/8" Surface 47# & 40# / L-80 / TXP 8.525 26’ 5,264’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 25’ 5,086’ 0.0459 4-1/2” Liner 13.5 / L-80 / Hyd 625 3.920 5,080’ 13,244’ .0149 TUBING DETAIL 4-1/2" Tubing 12.6# / L-80 / TXPM 3.958 Surface ±4,094’ 0.0152 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 – Lead – 450 sx / Tail – 400 sx Stg 2 – Lead – 525 sx / Tail – 270 sx 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 320’ Max Hole Angle = 93.05° @ 8780’ MD TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead FMC 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23677-00-00 Completion Date: June 10, 2020 JEWELRY DETAIL No. Top MD Item ID 1 ±24’ Tubing Hanger 3.950” 2 ±4,220’ Gauge Carrier 3.958” 3 ±4,230’ Sliding Sleeve 3.813” 4 ±4,240’ Ported Pressure Sub 3.958” 5 ±4,300’ Permanent Packer, Halliburton TNT 3.856” 6 ±5,045’ XN Nipple, 3.813” Profile, 3.750” No Go 3.750” 7 5,070’ 7-5/8” Tieback Assy. 8 5,080’ BOT SLZXP LTP / Liner Hanger 7” x 9-5/8”(TVD 3805’) 6.190” 9 ±5,095’ WLEG – Bottom @ 8,210’ 3.958” 10 5,101’ 7” H563 x 4.5” Hyd 625 XO 3.850” 11 13,222’ Shoe 3.950” 4-1/2” LINER 250ђ SCREEN DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 65 5,272’ 3816’ 7,986’ 3838’ 5 8,314’ 3867’ 8,523’ 3888’ 27 8,772’ 3891’ 9,900’ 3899’ 77 9,982’ 3895’ 13,180’ 3949’ Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: March 19th, 2021Subject: Changes to Approved Sundry Procedure for Well MP I-36Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23677-00-00Well Name/No. MILNE PT UNIT I-36Completion Status1-OILCompletion Date6/10/2020Permit to Drill2200470Operator Hilcorp Alaska, LLCMD14265TVD3958Current Status1-OIL9/22/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP, AGR, ABG, DGR, EWR, ADR MD & TVDNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF7/3/2020105 14265 Electronic Data Set, Filename: MPU I-36 LWD Final.las33472EDDigital DataDF7/3/20205250 14228 Electronic Data Set, Filename: MPU I-36 ADR Quadrants All Curves.las33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36 LWD Final MD.cgm33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36 LWD Final TVD.cgm33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36 Surveys.xlsx33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36_Definitive Survey Report.pdf33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36_DSR.txt33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36_GIS.txt33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36_Plan.pdf33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36_VSec.pdf33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36 LWD Final MD.emf33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36 LWD Final TVD.emf33472EDDigital DataDF7/3/2020 Electronic File: MPU_I-36_Geosteering.dlis33472EDDigital DataDF7/3/2020 Electronic File: MPU_I-36_Geosteering.ver33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36 LWD Final MD.pdf33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36 LWD Final TVD.pdf33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36 LWD Final MD.tif33472EDDigital DataDF7/3/2020 Electronic File: MPU I-36 LWD Final TVD.tif33472EDDigital Data0 0 2200470 MILNE PT UNIT I-36 LOG HEADERS33472LogLog Header ScansTuesday, September 22, 2020AOGCCPage 1 of 4PB1PB2MPU I-36 LWDFinal.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23677-00-00Well Name/No. MILNE PT UNIT I-36Completion Status1-OILCompletion Date6/10/2020Permit to Drill2200470Operator Hilcorp Alaska, LLCMD14265TVD3958Current Status1-OIL9/22/2020UICNo0 0 2200470 MILNE PT UNIT I-36 PB1 LOG HEADERS33473LogLog Header ScansDF7/3/2020105 10302 Electronic Data Set, Filename: MPU I-36 PB1 LWD Final.las33473EDDigital DataDF7/3/20205250 10264 Electronic Data Set, Filename: MPU I-36 PB1 ADR Quadrants All Curves.las33473EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB1 LWD Final MD.cgm33473EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB1 LWD Final TVD.cgm33473EDDigital DataDF7/3/2020 Electronic File: MPU I-36PB1_Definitive Survey Report.pdf33473EDDigital DataDF7/3/2020 Electronic File: MPU I-36PB1_DSR.txt33473EDDigital DataDF7/3/2020 Electronic File: MPU I-36PB1_GIS.txt33473EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB1 LWD Final MD.emf33473EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB1 LWD Final TVD.emf33473EDDigital DataDF7/3/2020 Electronic File: MPU_I-36 PB1_Geosteering.dlis33473EDDigital DataDF7/3/2020 Electronic File: MPU_I-36 PB1_Geosteering.ver33473EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB1 LWD Final MD.pdf33473EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB1 LWD Final TVD.pdf33473EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB1 LWD Final MD.tif33473EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB1 LWD Final TVD.tif33473EDDigital DataDF7/3/2020105 10164 Electronic Data Set, Filename: MPU I-36 PB2 LWD Final.las33474EDDigital DataDF7/3/20205250 10126 Electronic Data Set, Filename: MPU I-36 PB2 ADR Quadrants All Curves.las33474EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB2 LWD Final MD.cgm33474EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB2 LWD Final TVD.cgm33474EDDigital DataDF7/3/2020 Electronic File: MPU I-36PB2_Definitive Survey Report.pdf33474EDDigital DataDF7/3/2020 Electronic File: MPU I-36PB2_DSR.txt33474EDDigital DataDF7/3/2020 Electronic File: MPU I-36PB2_GIS.txt33474EDDigital DataTuesday, September 22, 2020AOGCCPage 2 of 4MPU I-36 PB1 LWD Final.lasMPU I-36 PB2 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23677-00-00Well Name/No. MILNE PT UNIT I-36Completion Status1-OILCompletion Date6/10/2020Permit to Drill2200470Operator Hilcorp Alaska, LLCMD14265TVD3958Current Status1-OIL9/22/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:6/10/2020Release Date:5/20/2020DF7/3/2020 Electronic File: MPU I-36 PB2 LWD Final MD.emf33474EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB2 LWD Final TVD.emf33474EDDigital DataDF7/3/2020 Electronic File: MPU_I-36 PB2_Geosteering.dlis33474EDDigital DataDF7/3/2020 Electronic File: MPU_I-36 PB2_Geosteering.ver33474EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB2 LWD Final MD.pdf33474EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB2 LWD Final TVD.pdf33474EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB2 LWD Final MD.tif33474EDDigital DataDF7/3/2020 Electronic File: MPU I-36 PB2 LWD Final TVD.tif33474EDDigital Data0 0 2200470 MILNE PT UNIT I-36 PB2 LOG HEADERS33474LogLog Header ScansTuesday, September 22, 2020AOGCCPage 3 of 4 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23677-00-00Well Name/No. MILNE PT UNIT I-36Completion Status1-OILCompletion Date6/10/2020Permit to Drill2200470Operator Hilcorp Alaska, LLCMD14265TVD3958Current Status1-OIL9/22/2020UICNoCompliance Reviewed By:Date:Tuesday, September 22, 2020AOGCCPage 4 of 4M Guhl9/22/2020 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 ESP Swap 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 14,265'N/A Casing Collapse Conductor N/A Surface 4,760 psi Surface 3,090 psi Tie-Back 4,790 psi Liner (screens)8,540 psi 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.W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:8/21/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Ian Toomey itoomey@hilcorp.com 777-8520 3,958' 13,222' 3,949' 1,093 N/A Length Size COMMISSION USE ONLY 9,020 psi Tubing Grade: Tubing MD (ft): See Schematic 5,080' MD / 3,805' TVD and N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025906, ADL315848 220-047 3800 Centerpoint Drive, Suite 1400, Acnhorage, AK 99503 C.O. 477.05 50-029-23677-00-00 Hilcorp Alaska, LLC Milne Point Field / Schrader Bluff Oil Pool MPU I-36 PRESENT WELL CONDITION SUMMARY 9.3# / L-80 / EUE 8rd TVD Burst 5,043' 6,890 psi MD 5,750 psi N/A 6,870 psi 107' 1,992' 3,826' 107' 2,077 7-5/8" 20" 9-5/8" 107' 9-5/8"3,187' 2,077' Authorized Name: Chad Helgeson 5,086' Perforation Depth MD (ft): 5,264' See Schematic 5,086' 4-1/2" Perforation Depth TVD (ft): Tubing Size: 3,806' 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 9/1/2020 13,244'8,164' 3-1/2" 3,950' SLZXP LTP and N/A Authorized Title: Operations Manager Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad A Helgeson 2020.08.21 13:24:39 -08'00' By Samantha Carlisle at 1:49 pm, Aug 21, 2020 320-353 DSR-8/21/2020SFD 8/21/2020 10-404 MGR23SEP20 BOPE test to 2500 psi. Comm. 9/23/2020 dts 9/23/2020 JLC 9/23/2020 RBDMS HEW 9/25/2020 ESP Swap Well: MPU I-36 Date: 08-19-20 Well Name: MPU I-36 API Number: 50-029-23677-00 Current Status: Online ESP Producer Pad: I-Pad Estimated Start Date: September 1st, 2020 Rig: Innovation Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 220-047 First Call Engineer: Ian Toomey (907) 777-8343 (O) (907) 903-3987 (M) Second Call Engineer: David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number: Job Type: ESP Swap Current Bottom Hole Pressure: 1,250 psi @ 3,802’ TVD Downhole Gauge: PBU | 6.4 PPG Maximum Expected BHP: 1,473 psi @ 3,802’ TVD 30-day PBU Extrapolation | 7.5 PPG MPSP: 1,093 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 90+° from 5,264’ MD Max Dogleg: 9.14°/100ft at 4,323’ MD BPV Profile: 3” CIW Type H Brief Well Summary: MPU producer I-36 was drilled and completed by the Innovation rig in June 2020. The well was POP on June 19th but the ESP performance has been suboptimal only achieving about 80 psi drawdown on the reservoir. Notes Regarding Wellbore Condition x The 7-5/8” x 9-5/8” annulus passed an MIT to 1,000 psig on 6/11/2020. Objective: x Pull 3-1/2” ESP completion. x Install new EPS components, re-run pulled 3-1/2” tubing and setting the new ESP higher in the well with less inclination. Pre-Rig Procedure: 1. RU Slickline unit 2. Pull OV from GLM at 130’ and install DV. 3. Pull DV from GLM at 4,302’ MD. Leave pocket open. 4. RD Slickline Unit 5. RU LRS and PT lines. 6. Pump 1 IA volume (173 bbls) with 8.3 ppg source water down IA. 7. Bullhead 44 bbls of 8.3 ppg source water down tubing to the formation. 8. RD well house and flowlines. Clear and level pad area around well. Spot rig mats and containment. 9. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH. a. Due to the low reservoir pressure, the tubing freeze protect should not be needed. b. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the rig. 10. RD LRS. 11. RU crane. Set 3” HP BPV. ND Tree. Inspect the lift threads on the tubing hanger. Install the plug off tool into the BPV. 12. NU dry hole tree. RD crane. ESP Swap Well: MPU I-36 Date: 08-19-20 RWO Procedure: 13. MIRU Hilcorp Innovation Rig, ancillary equipment and lines to returns tank. 14. ND the dry hole tree and NU the BOP stack. 15. Test BOPE to 250/2,500 psi and annular to 250/2,500 psi. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per Innovation BOPE test procedure. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR’s and annular with 3-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 16. RU to pull 3-1/2” ESP completion. 17. Pull the plug off tool, check for pressure under the BPV, if needed kill the well with 8.3 ppg source water and pull the BPV. 18. MU landing joint or spear. BOLDS, unseat the tubing hanger and pull to the rig floor. a. PU = 85K and SO = 62K with block weight of 35K when landed by Innovation in 9.5 ppg brine. 19. Lay down the landing joint and tubing hanger. RU to pull ESP cable over sheaves to spooling units. a. Inspect the tubing hanger and note any corrosion or damage. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger or test plug in tubing head. Test BOPE per standard procedure and sundry. 20. POOH standing back the 3-1/2” tubing spooling ESP cable and removing all jewelry as it presents itself. Lay down ESP components. a. Note any corrosion, sand, or scale on the tubing with associated depths and ESP components on the morning report. b. If any joints appear suspect of damage to threads or tubing, send to G&I for disposal and replace with new. ESP Swap Well: MPU I-36 Date: 08-19-20 Equipment Disposition Tubing hanger Visually inspect on site and reuse Tubing & Pup joints Visually inspect on site and reuse Gaslift Mandrels/Nipple Visually inspect on site and reuse ESP equipment/Power Cable Centrilift to take possession for inspection and teardown Cannon clamps (90) Visually inspect on site and reuse Seal clamps (4) Visually inspect on site and reuse Pump clamps (4) Visually inspect on site and reuse 21. PU new ESP and RIH on 3-1/2”, 9.3#, L-80, EUE 8rd tubing spooling ESP cable and capillary line. Set base of ESP assembly at 4,200’ MD. Test the conductivity of the ESP cable and function of the capillary line every ~2,000’. a. Motor centralizer b. Motor gauge unit c. ESP motor d. Lower tandem seal e. Upper tandem seal f. Gas separator g. Pump h. Ported discharge head i. Bolt on discharge head, 3-1/2”, 9.3#, L-80, EUE 8rd box up j. 1 joint, 3-1/2”, 9.3#, L-80, EUE 8rd tubing k. Nipple, HES 2.813” XN (2.750” no-go) with 10’ handling pups above and below l. 2 joints, 3-1/2”, 9.3#, L-80, EUE 8rd tubing m. GLM, 3-1/2” x 1”, DV installed with 10’ handling pups above and below n. XXX joints, 3-1/2”, 9.3#, L-80, EUE 8rd tubing o. GLM, 3-1/2” x 1”, 0.25” OV installed with 10’ handling pups above and below (setting depth = ±200’ MD) p. XXX joints, 3-1/2”, 9.3#, L-80, EUE 8rd tubing 22. Space out with pup joints with one full joint below the tubing hanger. PU and MU the new 3-1/2” tubing hanger. Make final splice of the ESP cable to the penetrator, MU the control line to the tubing hanger and dummy off any additional control line ports if present. 23. Land tubing hanger with extreme caution to avoid damaging the ESP cable, penetrator or control line. RILDS. Record PU and SO weights on tally and WellEZ. 24. Install 3” BPV. 25. ND the BOP stack. Install the plug off tool. 26. NU the tubing head adapter and dry hole tree. PT tubing hanger void to 500/5000 psi. PT the tree to 250/5000 psi. 27. Turn well over to production via handover form. RU flowlines. ESP Swap Well: MPU I-36 Date: 08-19-20 Post-Rig Procedure: 28. ND the dry hole tree 29. NU 3-1/8”, 5M tree. PT the tree to 250/5000 psi. 30. Pull plug off tool and BPV. 31. Replace gauge(s) if removed. 32. RU well house. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Blank RWO MOC Form _____________________________________________________________________________________ Edited By: JNL 7-9-2020 Schematic Milne Point Unit Well: MPU I-36 Last Completed: 6-10-2020 PTD: 220-047 TD =14,265’(MD) / TD = 3,958’ (TVD) 4 20”00 Ori g. KB Elev.: 60.19’ / GL Elev.: 33.6’ 7-5/8”7/8 9/10 11 4 17 9-5/85”88 1 2 3 See Screen/ Solid Liner Detail PBTD = 13,222’ (MD) / PBTD = 3,949’ (TVD) 9-5/8” ‘ES’ Cementer @ 1935’ MD 5/6 4-1/2” Shoe @ 13,222’ 12 14 1315 16 3-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"Conductor 129.5# / X56 / Weld N/A Surface 107’N/A 9-5/8"Surface 47# & 40#/ L-80 / TXP 8.525 26’5,264’0.0758 7-5/8”Tieback 29.7 / L-80 / Hyd 521 6.875 25’5,086’0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 5,080’ 13,244’ .0149 TUBING DETAIL 3-1/2"Tubing 9.3 / L-80 / EUE-8rd 2.992 22’ 5,043’0.0087 OPEN HOLE / CEMENT DETAIL Conductor±270 ft3 12-1/4" Stg 1 –Lead –450 sx / Tail –400 sx Stg 2 – Lead – 525 sx / Tail – 270 sx 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 320’ Max Hole Angle = 93.05° @ 8780’ MD TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2 -1/16” 5K outs GENERAL WELL INFO API: 50-029-23677-00-00 Completion Date: June 10, 2020 4-1/2”SOLID LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 4 5,080’3805’5,272’ 3816’ 8 7,986’3838’8,314’ 3867’ 6 8,523’3888’8,772’ 3891’ 2 9,900’3899’ 9,982’3895’ JEWELRY DETAIL No.Top MD ItemID 1 130’GLM: 3-1/2” x 1” w/ Dual Flo OV 2.915” 2 4302’ GLM w/Dummy: 3-1/2” x 1” 2.920” 3 4,3611’2.813” XN Nipple, 2.75” no go 2.750” 4 4,978’Discharge Head: PMP 513 5 4,979’ Upper Tandem Pump: Zenith Ported Sub 513/539P 6 4,980’Lower Tandem Pump: 538PM SXD 086 7 5,000’ Gas Separator: 538 8 5,005’ Gas Avoider 513HS 9 5,008 Upper Tandem Seal: GSB3DBUT SB/SB PFSA 10 5,015’Lower Tandem Seal: GSB3DBUT SB/SB PFSA 11 5,021’Motor: CL5 XP –250hp / 2505V / 61A 12 5,038’Sensor, Zenith 13 5,040’ Centralizer: Bottom @ 5043’ 14 5,080’BOT SLZXP LTP / Liner Hanger 7” x 9 -5/8” (TVD 3805’)7.375” 15 5,070’7-5/8” Tieback Assy.6.180” 16 5,101’ 7” H563 x 4.5” Hyd 625 XO 3.840” 17 13,222’Shoe - 4-1/2” Screens LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 65 5,272’3816’ 7,986’3838’ 5 8,314’3867’ 8,523’3888’ 27 8,772’3891’ 9,900’3899’ 77 9,982’3895’13,180’3949’ _____________________________________________________________________________________ Edited By: IAT 8-20-2020 PROPOSED Milne Point Unit Well: MPU I-36 Last Completed: 6-10-2020 PTD: 220-047 TD =14,265’(MD) / TD = 3,958’ (TVD) 4 20”00 Ori g. KB Elev.: 60.19’ / GL Elev.: 33.6’ 7-5/8”7/8 9/10 11 4 17 9-5/85”88 1 2 3 See Screen/ Solid Liner Detail PBTD = 13,222’ (MD) / PBTD = 3,949’ (TVD) 9-5/8” ‘ES’ Cementer @ 1935’ MD 5/6 4-1/2” Shoe @ 13,222’ 12 14 1315 16 3-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"Conductor 129.5# / X56 / Weld N/A Surface 107’N/A 9-5/8"Surface 47# & 40#/ L-80 / TXP 8.525 26’5,264’0.0758 7-5/8”Tieback 29.7 / L-80 / Hyd 521 6.875 25’5,086’0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 5,080’ 13,244’ .0149 TUBING DETAIL 3-1/2"Tubing 9.3 / L-80 / EUE-8rd 2.992 22’±4,094’0.0087 OPEN HOLE / CEMENT DETAIL Conductor±270 ft3 12-1/4" Stg 1 –Lead –450 sx / Tail –400 sx Stg 2 – Lead – 525 sx / Tail – 270 sx 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 320’ Max Hole Angle = 93.05° @ 8780’ MD TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead FMC 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23677-00-00 Completion Date: June 10, 2020 4-1/2”SOLID LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 4 5,080’3805’5,272’ 3816’ 8 7,986’3838’8,314’ 3867’ 6 8,523’3888’8,772’ 3891’ 2 9,900’3899’ 9,982’3895’ JEWELRY DETAIL No.Top MD ItemID 1 ±200’GLM: 3-1/2” x 1” w/ Dual Flo OV 2.915” 2 ±4,024’ GLM w/Dummy: 3-1/2” x 1” 2.920” 3 ±4,083’2.813” XN Nipple, 2.75” no go 2.750” 4 ±4,135’Discharge Head: PMP 513 5 ±4,136’Upper Tandem Pump: Zenith Ported Sub 513/539P 6 ±4,137’Lower Tandem Pump: 538PM SXD 086 7 ±4,157’Gas Separator: 538 8 ±4,162’Gas Avoider 513HS 9 ±4,165 Upper Tandem Seal: GSB3DBUT SB/SB PFSA 10 ±4,172’Lower Tandem Seal: GSB3DBUT SB/SB PFSA 11 ±4,178’Motor: CL5 XP –250hp / 2505V / 61A 12 ±4,195’Sensor, Zenith 13 ±4,198’ Centralizer: Bottom @ 4,200’ 14 5,080’BOT SLZXP LTP / Liner Hanger 7” x 9 -5/8” (TVD 3805’)7.375” 15 5,070’7-5/8” Tieback Assy.6.180” 16 5,101’ 7” H563 x 4.5” Hyd 625 XO 3.840” 17 13,222’Shoe - 4-1/2” Screens LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 65 5,272’3816’ 7,986’3838’ 5 8,314’3867’ 8,523’3888’ 27 8,772’3891’ 9,900’3899’ 77 9,982’3895’13,180’3949’ Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: August 21st, 2020 Subject: Changes to Approved Sundry Procedure for Well MP I-36 Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 33.6 BF:33.6 Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" X-56 107' L-80 1992' L-80 3,826' 7-5/8" L-80 3,806' Uncemented Tieback 4-1/2" L-80 3950' Uncemented Screen Liner 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, Tieback TUBING RECORD Liner Top Packer 5043'3-1/2" 9.3# L-80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 13.5# 3805'5080' 13244' Stg 1 L - 450 sx / T - 400 sx 8-1/2" Stg 2 L - 525 sx / T - 270 sx12-1/4" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 6/10/2020 2328' FSL, 3682' FEL, Sec 33, T13N, R10E, UM AK 2158' FSL, 1367' FWL, Sec 21, T13N, R10E, UM, AK 220-047 Milne Point Field / Schrader Bluff Oil Pool 60.19 13222' MD / 3949' TVD MPU I-36 5/23/2020 551689 6009444 3688' FSL, 4994' FEL, Sec 33, T13N, R10E, UM, AK CEMENTING RECORD 6010794 Surface HOLE SIZE AMOUNT PULLEDTOP SETTING DEPTH MD Surface SETTING DEPTH TVD 6019831 WT. PER FT.GRADE 129.5# 40# 2077' 5080' / 3805' PACKER SET (MD/TVD) 29.7# Surface DEPTH SET (MD) BOTTOM TOP 5264' 1992' Driven Driven107' Gas-Oil Ratio:Choke Size: Surface Oil-Bbl: Per 20 AAC 25.283 (i)(2) attach electronic information 5086' Surface Date of Test: TBD Flow Tubing TBD ESP 4-1/2" Screen Liner 6/9/20 **Please see attached Schematic for detail** Water-Bbl: PRODUCTION TEST Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 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 ADL025906, ADL315848 LONS 88-004 1,803' MD / 1,757' TVD N/AN/A None 14265' MD / 3958' TVD 550364 551359 CASING 50-029-23677-00-00 9-5/8"47# Surface 2077' 6/6/2020 ROP, AGR, ABG, DGR, EWR, ADR MD & TVD PB1: ROP, AGR, ABG, DGR, EWR, ADR MD & TVD PB2: ROP, AGR, ABG, DGR, EWR, ADR MD & TVD Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Jody Colombie at 8:27 am, Jul 10, 2020 Completion Date 6/10/2020 HEW RBDMS HEW 7/14/2020 G SFD 7/15/2020 DSR-7/14/2020DLB 07/14/2020 13,222' MGR21SEP2020 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 35'35' 1,838' 1,792' Top of Productive Interval 5152' 3,823' 1,360' 1,350' 2,110' 2,019' 3,656' 3,286' 4,844' 3,783' 5152' 3,813' SB NB 5152' 3813' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Joe Lastufka Contact Email:joseph.lastufka@hilcorp.com Authorized Contact Phone: (907)227-8496 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: FORMATION TESTS Permafrost - Top SV5 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. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Plugback Summary, Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report Signature w/Date: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): Formation at total depth: SB NA Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME SB NB SV1 Ugnu LA3 The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). 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. INSTRUCTIONS 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. TPI (Top of Producing Interval). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). 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. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). 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. 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. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.07.09 12:37:40 -08'00' Monty M Myers PB1 TD 10300' MD / 3890' TVD KOP 8780' MD / 3891' TVD Date 6/3/2020 PB2 TD 10163' MD / 3866' TVD KOP 9340' MD / 3889' TVD Date 6/4/2020 MPU I-36 OH Sidetrack Summary PTD: 220-047 / API: 50-029-23677-71-00 PTD: 220-047 / API: 50-029-23677-70-00 _____________________________________________________________________________________ Edited By: JNL 7-9-2020 MPU I-36 Schematic Milne Point Unit Well: MPU I-36 Last Completed: 6-10-2020 PTD: 200-047 TD =14,265’(MD) / TD = 3,958’ (TVD) 4 20” Orig. KB Elev.: 60.19’ / GL Elev.: 33.6’ 7-5/8”7/8 9/10 11 4 17 9-5/8” 1 2 3 See Screen/ Solid Liner Detail PBTD =13,222’ (MD) / PBTD = 3,949’ (TVD) 9-5/8” ‘ES’ Cementer @ 1935’ MD 5/6 4-1/2” Shoe @ 13,222’ 12 14 1315 16 3-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5# / X56 / Weld N/A Surface 107’ N/A 9-5/8" Surface 47# & 40# / L-80 / TXP 8.525 26’ 5,264’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 25’ 5,086’ 0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 5,080’ 13,244’ .0149 TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE-8rd 2.992 22’ 5,043’ 0.0087 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 – Lead – 450 sx / Tail – 400 sx Stg 2 – Lead – 525 sx / Tail – 270 sx 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 320’ Max Hole Angle = 93.05° @ 8780’ MD TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23677-00-00 Completion Date: June 10, 2020 4-1/2”SOLID LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 45,080’3805’5,272’3816’ 87,986’3838’8,314’3867’ 68,523’3888’8,772’3891’ 2 9,900’ 3899’ 9,982’ 3895’ JEWELRY DETAIL No. Top MD Item ID 1 130’ GLM: 3-1/2” x 1” w/ Dual Flo OV 2.915” 2 4302’ GLM w/Dummy: 3-1/2” x 1” 2.920” 3 4,631’ 2.813” XN Nipple, 2.75” no go 2.750” 4 4,978’ Discharge Head: PMP 513 5 4,979’ Upper Tandem Pump: Zenith Ported Sub 513/539P 6 4,980’ Lower Tandem Pump: 538PM SXD 086 7 5,000’ Gas Separator: 538 8 5,005’ Gas Avoider 513HS 9 5,008 Upper Tandem Seal: GSB3DBUT SB/SB PFSA 10 5,015’ Lower Tandem Seal: GSB3DBUT SB/SB PFSA 11 5,021’ Motor: CL5 XP – 250hp / 2505V / 61A 12 5,038’ Sensor, Zenith 13 5,040’ Centralizer: Bottom @ 5043’ 14 5,080’ BOT SLZXP LTP / Liner Hanger 7” x 9-5/8”(TVD 3805’)7.375” 15 5,070’ 7-5/8” Tieback Assy. 6.180” 16 5,101’ 7” H563 x 4.5” Hyd 625 XO 3.840” 17 13,222’ Shoe - 4-1/2” Screens LINER DETAIL Jts Top (MD)Top (TVD) Btm (MD) Btm (TVD) 65 5,272’ 3816’ 7,986’ 3838’ 5 8,314’ 3867’ 8,523’ 3888’ 27 8,772’ 3891’ 9,900’ 3899’ 77 9,982’ 3895’ 13,180’ 3949’ 13,222' Activity Date Ops Summary 5/21/2020 PJSM Cont disconnect inner connects. Swap to cold start 07:00. R/D move cutting box. Jack up and install jeep to Gen Mon. Peak on location 09:00. Stage Gen Mod, Mud Mod, Pipe Shed and Cattle Chute. Set rig matts for walking off Sub to I-36. Walk Sub off to I-36.;PJSM Cont walking Sub off I-35 down well row. Stage RCD, DSA, Sliplock Head, Tree and Diverter adapter behind I-36 W/ Crane. Walk Sub over I-35. Install Sliplock Head on 20" Conductor as per NOS Rep onsite. SIMOPS C/O Sub HPU pump #2. Cont working on MP's and C/O valves in pits.;Cont spotting Sub. Retract rams and shut down hydraulics on Sub. Spot rig matts and spot Cattle Chute. Shim Pipe Shed side of Chute. Pull Mod ahead and retrieve rig matts. Spot 40' rig matts for Gen and Mud Mod's. Spot Mud Mod. Install flowline, mud lines and utilities.;Connect Pipe Shed inner connects. Spread Herculite and rig matts for cutting box. Adjust jeep postion on Gen Mod. Notified AOGCC for Diverter Test 19:30 5/23/20.;PJSM Cont spotting Gen Mod. Cont hooking up inner connects. Peak released at 02:00.;PJSM Spot and connect Enviro Vac and Break Shack. Spot MPD Choke House. Set cutting box and berm up. Hook up steam, air and H2O. Scope up Derrick and bridle down. Work on rig acceptance list. Safe out stairs, walkways and rooftops. Swap to Gen power at 04:00. Install Dog House stairs and landing.;Daily fluid hauled to G&I 0 bbls total = 0 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 0 bbls total = 0 bbls Daily Fluid lost 0 bbls total fluid lost =0 bbls 5/22/2020 Continue rigging up working on rig acceptance checklist. Hang rig tongs, install hydraulic elevators, process 190 jts 5" NC50. Load BHA and test same (MWD). Prep mud pits to take on mud.;Set DSA on starter head, Set Diverter "T" and 13 5/8" stack. Tighten flanges. N/U knife valve. Sym ops - continue process DP. Load 290 bbls 8.8 spud mud in pits. Function pit equipment. Install isolation valves for rotary table hydraulic controls (minor leak to be addressed at later time).;Continue N/U diverter system. Install 16" diverter line from "T" thru rig. Crane mats and set diverter line off pad. Tighten all flanges and install catch can at end of line. Perform post rig move derrick inspection, sheave wobble test (EAM) for blocks and crown 4 pt stack. Rig accepted at 18:00;PJSM Service and inspect Iron Roughneck. Inspect Top Drive and carriage. Inspect drilling line.;PJSM Function test Diverter Stack and Equip. Function tested Annular 7 sec close, Knife open 6 sec. Function tested Koomey System Press 2,800 PSI, after function 1,900 PSI. 200 PSI 17 sec, full 60 sec. 6 Nitrogen avg 2,308 PSI. Test pit level alarms. Tested rig alarms H2S 10-20 PPM, LEL 20-40%.;Witnessed by AOGCC rep Bob Noble. Take another 290 bbls Spud Mud into pits.;PJSM Bleed down Koomey and disconnect knife valve, recharge Koomey. P/U Mouse Hole and install in rotary table. Close Annular W/ 400 PSI on mouse hole. P/U M/U 5" NC50 19.5# S-135 D.P. F/ Pipe Shed and rack back in Derrick 43 stands. ( 86 Jnts) Drift 3.125" OD.;PJSM Cont. P/U M/U 5" NC50 19.5# S-135 D.P. F/ Pipe Shed and rack back in Derrick 52 stands. ( total 90 stands) Drift 3.125" OD. P/U M/U 9 stands 5" NC50 49# HWDP including SLB Jars. (2.75" Drift OD) Open Annular and L/D mouse hole. Hook up Knife Valve Hydraulic Koomey lines.;PJSM Hang Blocks. Cut and slip drilling line 77'. 13 wraps. Accum TM 35,464. 771' left on spool. Check brake air gap. Calibrate block height.;Daily fluid hauled to G&I 0 bbls total = 0 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 0 bbls total = 0 bbls Daily Fluid lost 0 bbls total fluid lost =0 bbls Contractor AFE #: AFE $: Job Name:2011148D MPU I-36 Drilling Spud Date: Well Name: Field: County/State: MP I-36 Milne Point Hilcorp Energy Company Composite Report , Alaska n (LAT/LONG): evation (RKB): API #: 5/23/2020 Perform EAM on crown sheaves. Grease traveling equipment.;Retract cattle chute and release 4 pt binders from stack. Raise and shim sub base due to settling that pulled sub off plumb. Put cattle chute back in place and 4 pt stack centered.;Install short mousehole. Mob BHA components to rig floor. M/U 12-1/4" KMX633 (.84" TFA) w/ 1.5° Mtr (4/5 lobe: 5.3 stg). XO to 5" HWDP. Flood surface lines and conductor. P/T to 3k with water (test good). Monitor tattle tell on diverter line (good). 28k tq on bit.;Wash dn F/ 35' to btm of conductor @ 107' MD. 300 gpm, 225 psi, 30 rpm, 1k tq. Saw coarse sand w/ slight residual oil @ shaker while washing down.;Drill 12.25" surface hole F/ 107' - T/ 218' MD. Displaced to 8.8 spud mud on the fly @ 108' MD. Minimum flow @ 300 gpm, 30 rpm, 1-2k wob when first exiting conductor (first 50') then increase flow to 350 gpm to help manage flowline issues (plugging off). 49k.;Heavy pea gravel encountered while drilling F/ 107 to 150' then turned more coarse sand. Final parameters 400 gpm, 350 psi, 40 rpm, 1.5k tq. Continually fight flowline issues during initial spud (saw same issues on I-35 / previous well) due to heavier than normal pea gravel and coarse sand.;CBU while slowly BROOH F/ 218' - T/ 200' then attempt to POOH on elevators (no go). Saw 15-20k overpulls @ 165' and 135' MD. Wrk thru overpull depths with min pump and rot up inside conductor. Attempt TIH past base conductor (tag @ 107' MD). Continue POOH to surface.;M/U MWD components to 12-1/4" mtr assy (DM, EWR,TM, UBHO). 40/809x360+= 17.80° RFO (witnessed by CoMan). Orient UBHO to HS. Download MWD. M/U NM flex w/ bottleneck XO to wrk past base of conductor. Went to high line power. BHA length =738.14'.;PJSM Slide & Rot F/ 219' to 426' MD total 207' (AROP 41.4') 425 GPM, 830 PSI, 40 RPM, TRQ 1K, WOB 3-5K, P/U 58K SLK 60K ROT 60K. Gyro 102' F/ Bit. Started Gyro surveys at 236' MD Unable to get clean Gyro survey and added WT bar to Gyro BHA. Started build 1.5°/100 271' to 463' to 3°.;MWD surveys are failing QC on dip. Adjusting flow rates due to high Vis, jetting flow line.;PJSM Pump out F/ 426' to 360' MD 1 stand 5" HWDP 400 GPM 750 PSI. No issue. P/U Jar stand. Install corrosion ring on top of jars. RIH to 426' MD.;PJSM Slide & Rot F/ 426' to 482' MD total 56' (AROP 56') 425 GPM, 844 PSI, 40 RPM, TRQ 1K, WOB 3-5K, P/U 68K SLK 62K ROT 64K. Attempt to Gyro getting hung up at 90' down hole. Decision was made to pull back to Jars.;POOH F/ 482' to 390' MD. Attempted to pull on elevators saw 15K over pull. Pump and Rot 400 GPM 660 PSI 20 RPM TRQ 1.5-2K, Pulled out corrosion ring and found to be bent. No shoulder for it to sit on. Ran Gyro through Jars W/O issue. Wash back down to 482' 400 GPM 660 PSI. No fill.;PJSM Slide & Rot F/ 482' to 675' MD total 193' (AROP 64.3') 450 GPM, 880 PSI, 50 RPM, TRQ 1-1.5K, WOB 3-6K, P/U 72K SLK 72K ROT 71K. Cont to Gyro every connection. Dropping to zero degree F/ 463' MD. First clean survey at 610' MD. Cont jetting flow line, mud seems to be evening out.;Slide hrs 1.15, Rot hrs 2.65, Distance to WP #7: 2.13', 1.28' high, 1.70' Left;Daily fluid hauled to G&I 171 bbls total = 171 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 260 bbls total = 781 bbls Daily Fluid lost 0 bbls total fluid lost =0 bbls 5/24/2020 Cont Drlg 12.25" surface F/ 675' - T/ 1053' MD (378' total = 63 fph AROP). 475 gpm, 1152 psi, 50 rpm, 2.5k tq, 3-8k wob, 80k up/dn/rot. Backream full stands @ connections. Continue using Gyro surveys. Negligible gas. 2.5°/100 build to 1,142'.;Cont Drlg 12.25" surface F/ 1053' - T/ 1562' MD / 1542' TVD (509' total = 85 fph AROP). 500 gpm, 1450 psi, 50 rpm, 4.1k tq, 5-8k wob, 91k up 86 dn 86rot. Backream full stands @ connections. Continue using Gyro surveys. Minimal gas w/ 55u BGG, 66u Max. 9 ppg MW w/ 190-210 vis. 10.1 ECD's.;PJSM Slide & Rot F/ 1,562' to 2,200' MD (2,093' TVD) total 638' (AROP 106.3') 500 GPM, 1,390 PSI, 60 RPM, TRQ 3.5K, WOB 2-5K, P/U 98K SLK 87K ROT 92K. ECD 9.88, Mac Gas 556U, BGG. Last Gyro survey at 1,689' Bit/ 1,588' Survey. MWD QC good.. 4°/100 build F/ 1,142' to 1,.905' MD 33.5° Inc 247.5 az;Tangent section F/ 1,905 to 2,351'. Started clearing F/ MP I-10 @ 1,905' MD. Back ream 30' at connections. MW 9.0 ppg, Relaxed Vis @ 2,000' to 110 Vis. BASE PERMAFROST @ 1,838' MD 1,792' TVD.;Slide & Rot F/ 2,200' to 2,774' MD (2,574' TVD) total 574' (AROP 95.6') 500 GPM, 1,532 PSI, 80 RPM, TRQ 5K, WOB 4-6K, P/U 112K SLK 96K ROT 100K. ECD 9.76, Mac Gas 1,298U, BGG 200U. Held Gyro till 2,200' MD to ensure no interference as per DD & MWD. Released Gyro at 01:00. Back ream full stands.;At ~2,350 saw 1,298U Gas W/ heavy oil at shakers cleaning up right away lower SV1. Start build turn 4°/100 at 2,351' MD. At 2,400' maintain 80-90 vis MW 9.0 ppg.;Slide hrs 6.12, Rot hrs 7.93 Distance to WP #7: 11', 7.58' high, 7.97' Left;Daily fluid hauled to G&I 855 bbls total = 1,026 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 1,040 bbls total = 1,820 bbls Daily Fluid lost 0 bbls total fluid lost =0 bbls 5/25/2020 Cont Drlg 12.25" surface F/ 2774' - T/ 3283' MD / 3002' TVD (509' total = 85 fph AROP). 550 gpm, 1750 psi, 80 rpm, 7k tq, 10-14k wob, 126k up 100k dn 111k rot. Backream full stands @ connections. Gas w/ 851u BGG, 50u Max. 9 ppg MW w/ 80 vis. 9.76 ECD's. Build turn 4°/100.;Cont Drlg 12.25" surface F/ 3283' - T/ 3983' MD / 3494' TVD (700' total = 116 fph AROP). 550 gpm, 1824 psi, 80 rpm, 9k tq, 3-5k wob, 138k up 100k dn 114k rot. Backream full stands @ connections. Gas w/ 1435u BGG, 240u Max. 9 ppg MW w/ 80 vis. 9.73 ECD's. Build turn 4°/100.;Slide & Rot F/ 3,983' to 4,300' MD (3,654' TVD) total 317' (AROP 52.8') 550 GPM, 1,425 PSI, 80 RPM, TRQ 9K, WOB 4-7K, P/U 148K SLK 98K ROT 115K. ECD 9.88, Mac Gas 2,296U, BGG 500U. Back ream full stands.. MW 9.35 ppg, 65 Vis. Cont build turn 4°/100 till 4,237' 6°/100 as per Geo.;At ~4,194 encountered high Gas 2,296U hole unloading and screens blinded off W/ oil. Stage pumps down to 220 GPM 517 PSI C/O Shaker #1 to 2 140’s & 2 100’s Shaker #2 F/ 170’s to 140’s. Lost about 210 bbls over the Shakers. Increased MW to 9.35 ppg. UG_MD2 top is @ 4,100’ MD.;AT 4,270’ MD Gas 1,074U reduced flow rate to 250 GPM 640 PSI C/O Shaker #2 to 2 ea 140’s and 2 ea 100’s due to blinding off and gas. Increase mud WT to 9.4 oog. Cont fighting blinding at shakers.;Slide & Rot F/ 4,300' to 4,682' MD (3,766' TVD) total 382' (AROP 63.7') 525 GPM, 1,569 PSI, 80 RPM, TRQ 11.5K, WOB 10-15K, P/U 150K SLK 92K ROT 115K. ECD 9.88, Mac Gas 1,260U, BGG 230U. Back ream full stands.. MW 9.45 ppg, 83 Vis. Shakers have 1 ea 140 and 3 ea 100's. No more blinding issues.;Cont build turn 6°/100 as per Geo 15' above plan for expected fault.;Slide hrs 8.59, Rot hrs 3.46 Distance to WP #7: 6.90', 5.76' low, 3.8' Left;Daily fluid hauled to G&I 969 bbls total = 1,995 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 1,170 bbls total = 2,990 bbls Daily Fluid lost 0 bbls total fluid lost =0 bbls 5/26/2020 Continue Drlg 12.25" surface F/ 4682' - T/ 5063' MD (3,803' TVD) total 381' (AROP 64') 525 GPM, 1705 PSI, 80 RPM, 11.5K tq, WOB 12-18K, P/U 140K SLK 90K ROT 109K. ECD 10.3, Max Gas 611u, BGG 225u. Back ream full stands.. MW 9.35 ppg, 66 Vis. Shakers dressed w/ 140's (all). 30 bph water.;Continue Drlg 12.25" surface F/ 5063' - T/ TD @ 5274' MD (3,815' TVD) total 211' (AROP 71') 525 GPM, 1475 PSI, 80 RPM, 11K tq, WOB 12-18K, P/U 135K SLK 87K ROT 110K. ECD 10.4, Max Gas 1309u, BGG 340u. Back ream full stands.. MW 9.4 ppg, 66 Vis. Shakers-2x140's, 2x170's (both). 30 bph water. YP 26;Offsite Geo Derek Jaakola called TD @ 5274' MD / 3815' TVD in the NB sand. Landed in the NB @ 91° Inclination, 3.17° Az (extrapolated to bit).;Obtain final svy @ 5234' MD / 3816' TVD 90.53° Inc, 3.17° Az. BROOH F/ 5274' -T/ 5087' @150 fph pulling speed while circulating 2x btms up @525 gpm, 1560 psi, 10.18 ECD's, 80 rpm, 9.2k tq, 275u BGG, max gas 387U. 53% F/O. P/U 132K, S/O 92K, ROT 108K. Pump 40 bbls high vis sweep with 10% increase.;Wash and ream from 5,087' to 5,274' at 525 gpm, 1520 psi, 80 rpms, 10Kft-lbs. ECD 10.04, max gas 425U.;Monitor well, static. BROOH from 5247' to 3029' at 550 gpm, 1400 psi, 80 rpms. 7Kft-lbs. Max gas 316U, ECD 10.21. Pulling 5-20 fpm as hole allows. P/U 129K, S/O 97K, ROT 105K.;Cont. to BROOH from 3029' to 1056', 550 gpm,1280psi, 80rpms, 3-5Kft-lbs. Pulling 2-20 fpm as hole dictates. Slow pulling speed 3 stands prior to permafrost at 1838' and obtain 2 x BU. Slow rotary to 40rpms, 2.5-3.5Kft-lbs once below 30° at 1819'. Max gas 273U, ECD 10.38. P/U 85K. S/O 83K, ROT 80K.;Slide hrs 2.63 , Rot hrs 3.55 Distance to WP #7: 20.11', 19.36' High, 5.45' Right;Daily fluid hauled to G&I 770 bbls total = 2,765 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 780 bbls total = 3,770 bbls Daily Fluid lost 0 bbls total fluid lost =0 bbls 5/27/2020 Cont. to BROOH from 1056' to 395' MD. Attempted to pull on elevators @ 711' and 409' with same results each time (15k max overpull). Reduced flow rate to 450 gpm, 20-30 rpm. Saw 50-100 psi increases w/ tq spikes varying 1-3k until ~250' MD.;Monitor well (static). PJSM, L/D 3x NM flex DC's, Read MWD, L/D UBHO, MWD. Flush and Milk mtr. B/O and L/D bit. Bit Grade =1,1,CT,G,E,I,NO,TD. Slight BHA damage to ILS and mtr stab (pics in "O" drive).;Clean and clear rig floor. L/D BHA tools. Prep pipeshed for running casing.;Service rig. Grease crown, blocks and drawworks.;R/U CRT (Volant), Install bail extensions, 9-5/8" 250T elevators, Double stack power tongs. Function test equipment.;PJSM, M/U 9-5/8" shoe track and Baker lok. Install bypass baffle. Check floats - good.;RIH with 9-5/8", L-80, TXP, 40# casing to 2,512', torquing to 21Kft-lbs. Tag up at 1022', work through establishing rotary and circulation at 4 bpm, 135 psi, 5 rpms, 5Kft-lbs. PUW 115K, SOW 85K.;Circulate 1.5 x bottoms up, staging pumps up to 8 bpm 215 psi, 10 rpms, 7.5Kft-lbs. Max gas 36U.;Cont to RIH with 9-5/8", L- 80, TXP, 40# casing to 3,834'. Swap to 47# casing (M/U TQ 23,800ft-lbs) at 3,187'. Install ES cementer as per tally and Baker Lok.;Cont to RIH with 9-5/8", L-80, TXP, 47# casing from 3,834 to 5264',;Establish circulation, circulate surface to surface staging pumps up to 8 bpm, 195 psi, 1-3 rpms with torque limiter set at 15Kft-lbs, reciprocating pipe. Lower Yield point of drilling fluid to 16 in, 17 out. Rig up cementers. No losses. P/U 207K, S/O 137K.;Break out volant, blow down top drive. Blow down cement line and rig up.;Daily fluid hauled to G&I 509 bbls total = 3,274 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 520 bbls total = 4,290 bbls Daily Fluid lost 36 bbls total fluid lost = 36 bbls 5/28/2020 PJSM, R/U cmt line. Establish circulation staging up to 7 bpm, 500 psi w/ 9.3 mud. Rot/Recip w/ 1-5 rpm w/ 16-19k tq, 235k up, 140k dn. Turn over to HES cementers.;Wet lines w/ 5 bbls H2O. P/T lines 1000 psi low / 4500 psi high (test good). Pump 60 bbls 10# spacer (5# poly flake, 4# red dye in first 10bbls), 3.5 bpm, 245 psi. Drop btm bypass plug. 188 bbls 12# type I/II Lead cmt (2.349 yld)450sxs, 4 bpm, 250 psi.;82 bbls 15.8# Tail cmt (1.157 yld)400 sxs, 4 bpm, 680. Drop top shutoff plug. HES pump 20 bbls H2O, 4 bpm. Rig disp 213 bbls 9.3 spud mud, 6 bpm, 330 psi. HES- 76 bbls 9.4 ppg tuned spacer, 6 bpm.;Rig disp 79 bbls 9.3 ppg spud mud, 5 bpm, 585 psi. Slowed last 10 bbls to 3 bpm, FCP 690 psi. Bumped @ 4712 stks (384.8 bbls calc / 388.1 bbls act). Psi up to 1300 psi w/ 5 min hold. Bled back 4 bbls, floats held. CIP @ 11:30 hrs. Poly flake back @ 4700 stks. Full returns thru out job.;Psi up @ 3 bpm. Observed good indication of stg tool shifting @ 3300 psi. Stg up to 5 bpm, 275 psi, 44% flow. Overboard 42 bbls spacer, 80 bbls green cmt, 82 bbls contaminated mud before taking returns back to pits. Inc rate to 6 bpm, 315 bpm. Flush surface equipment, Cont circ. Prep for 2nd stg.;BOP test notification sent to AOGCC @ 19:00 hrs.;PJSM; second stage cement job. HES pumped: 5 bbls water at 3.5 bpm, 182 psi Pump 60 bbls 10# spacer (5# poly flake, 4# red dye in first 10bbls), 3.6 bpm, 130 psi 275 bbls 10.7# ArcticCem Lead cmt (2.944 yld)525 sxs, 4 bpm, 300 psi. 56 bbls 15.8# Class G tail cmt (1.169 yld)270sxs, 4.2 bpm, 270 psi.;Drop closing Plug. HES pump 20 bbls water at 6 bpm, 370 psi. Swap to rig pumps and displace with 121.2 bbls (122 bbls calculated) 9.3 ppg drilling fluid at 7 bpm, slowing to 3 bpm with 10 bbls to go, FCP 650 psi. Bumped plug, pressure up to 2140 psi, observe ES cementer close at 1731 psi.;Hold pressure for 5 minutes. Bleed back 2 bbls and confirm tool closed. CIP at 22:10. 245 bbls of green cement returned to surface. No losses during job.;Drain stack, flush with balck water x2. R/D cement line and Volant. Pump through cement line to bleeder with black hwater. B/D cement line and top drive. Install casing elevators. Bleed down accumulator an disconnect knife valve. Re-Energize accumulator. Fill stack with black water and cycle;annular x 3. Repeat flush x3.;Prep to cut casing. Suck out casing stump with vac. Bleed accumulator. Pull mouse hole, hook up bridge cranes to stack, and remove chains. Remove diverter vent line. Deflate 20" airboot. P/U on stack, and center casing. Set emergency slips with 115K on slips. Cut casing (cut joint 29.46').;Sim Ops: Empty and clean pits. L/D volant. Remove 4" conducter valves and install caps.;Set stack back on stump and hot bolt. Install riser. C/O elevators to 5". Pick up stack washing tool, wash BOP stack with black water both pumps. Drain stack, pull riser and remove Knife Valve.;Daily fluid hauled to G&I 1318 bbls total = 4,592 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 1215 bbls total = 5,505 bbls Daily Fluid lost 36 bbls total fluid lost = 36 bbls 5/29/2020 PJSM, N/D bell nipple, N/D speed head from conductor. N/D and B/O speedhead from stack and stage stack on stump. N/D DSA and Mob from cellar. Sim Ops - Continue prep pits. Load 310 jts NC50 5" DP in shed (strap and tally same).;Make final cut on 9-5/8" casing, dress same. Install FMC 9-5/8" sliplock wellhead assy. Tq to 400 ft/lbs and test 500 low, 3800 high w/ 5/15 min hold (good test, witnessed by CoMan). Install 11", 5M casing and tubing spool. Sim Ops- Mob test equipment to floor. Finish prepping pits.;N/U 11"x13-5/8" DSA. Hoist, stage RCD head below floor w/ TDS. Mob and set stack on DSA. Install RCD. Continue N/U choke and kill lines. Install drip pan, ctr and 4pt stack. Obtain RKB measurements. Sim Ops - Weld new hinges on cellar sliding doors. Build 8.9 Baradril "N" (770 bbls total).;C/O NC50 Saver sub. Inspect grabber dies, tq and safety wire lock rings. Adjust ht of backup wrench. C/O washpipe. Install koomey lines on stack.;Pull test cap. M/U and install test plug. Install MPD test cap. Flood Beyond choke lines. Test MPD, observe leak on wellhead flange. Bleed of pressure and tighten flange. Retest MPD 200/1500 - good. Pull MPD test cap, install trip nipple, air up boot and check for leaks.;Pick up and M/U 5" test joint with pump in sub, TIW's, and dart. Flood stack, kill and choke lines and purge.;Attempt to shell test BOPE. Trouble shoot leak. Choke manifold valve 15 leaking. Grease and function, still leaking. Cap off CMV 15 (to changeout between test joints) and continue; observer superchoke flange leaking, tighten. Obtain good shell test.;Test BOPE with 5" and 3-1/2" test joints 250/3000. AOGCC's right to witness waived by Matt Herrera. Trouble shoot first test. Upper IBOP leaking. Continue testing on 5" test joint with no other failures. L/D 5" test joint.;C/O CMV 15 and upper IBOP.;Daily fluid hauled to G&I 651 bbls total = 5,243 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 1040 bbls total = 6,545 bbls Daily Fluid lost 0 bbls total fluid lost = 36 bbls 5/30/2020 Continue C/O upper IBOP. Install tq lock ring and safety wire same. Test gas alarms - 10/20 ppm H2S, 20/40% LEL. Retest CMV #15 and upper IBOP (Test good). Test annular, upper pipe, lower pipe with 3.5" test joint. Test inside choke, HCR choke.;Perform Koomey drawdown - Initial 3000 psi, drawdown 1500 psi, 200 psi inc @ 25 secs, full charge @ 100 secs. 6 NO2 bottles w/ 2333 psi avg. 13 hours total test time w/ 2x F/P (upper IBOP, CMV #15- Replaced both). R/D test equipment. Pull test plug. Svc choke manifold and lineup for drilling ops.;M/U running tool with long wear bushing (9.125" ID, 37.875" Length). RIH and set same with 1/2" holes machined into body of wear bushing oriented towards annulus ports. RILDS (4x) and verify stack will drain thru small 1/2" holes (good). L/D running tool. Install mousehole. Mob tools to floor.;M/U 8.5" cleanout assy - 8.5" Smith XR Milltooth, 6-3/4" Terraforce (6/7, 6stg), Float sub (non ported plunger), 6x jts 5" NC50 HWDP, SLB jars, 11x jts NC50 HWDP. 594.44' Total length. Single in out of shed w/ 5" NC50, 19.5# S-135 DP F/ 594' - T/ 1868' MD.;Wash down F/ 1868' - T/ 1936' MD, Tag ES cmtr on depth. Drill stage tool 330 gpm, 475 psi, 40 rpm, 3.5k tq w/ 5-7k WOB. 87k up, 80k dn, 84k rot. Trip thru 2x clean without pump/rot. Continue RIH.;B/D top drive. Continue to pick up, drift (3.125") and single in the hole with 5" drill pipe from 1963' to 5,109'; washing down from 5,015.;Flow line packed off from collaborated up mud. Clear flow line and CBU while adjusting pump rate as needed and pumping through bleeder as needed to clear packed flowline. 310 gpm/600 psi.;Perform casing test; rig up, flush lines and purge air. Close UPR's. PT casing to 2500 psi for 30 minutes - good test. Took 4.2 bbls to pressure up, bled back 4.2 bbls. Blow down lines. R/D.;Obtain SPR's. Wash down from 5,109' to 5,130'. Tag hard cement. 310 gpm, 648 psi, 40 rpms, 11Kft-lbs.;Drill cement, shoe track, and 20' of new hole from 5,130' to 5294'. WOB 5-15K, 350 gpm, 800 psi, 60 rpms, 11Kft-lbs. Tag FE on depth. Start displacing to Baradril-N on the fly. PUW 155K, SOW 82K, ROT 106K.;Cont. to displace to Baradril-N at 350 gpm, 800 psi, 60 rpms, 11Kft-lbs. Rack back stand and Monitor well.;Daily fluid hauled to G&I 285 bbls total = 5,528 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 260 bbls total = 6,805 bbls Daily Fluid lost 0 bbls total fluid lost = 36 bbls 5/31/2020 Conduct FIT to 12.0 ppg EMW, 615 psi - good. 1 bbls to pressure up, 1 bbl bled back. Blow down choke and kill lines.;Obtain SPR's. Monitor well 10 minutes - static. Pump dry job. POOH from 5293' to 594'. Calculated hole fill observed.;L/D excess HWDP and BHA. Bit grade 1-1-WT-A-E-1-NO-BHA.;Clean and clear rig floor. Bring BHA components to rig floor.;M/U BHA #3 RSS drilling assy: 8-1/2" PDC bit, NOV, Geo-pilot 7600, ADR/HCIM, ILS, DGR, PWD, DM, TM HOC. Plug in and download. Float sub, (2) flex collars, float sub, (2) HWDP, Jars, (1) HWDP. Shallow pulse test - good.;Pick up, drift (3.125"), and single in the hole with 5" NC-50 19.5# drill pipe from 273' to 3,894'. RIH out of derrick to 5,168'. Fill pipe and break in Geo-Pilot at 2522'. PUW 112K, SOW 82K.;Fill pipe and CBU at 400 gpm, 855 psi. Max gas 45U.;Hang blocks. Cut and slip 56' of drilling line. Check brake air gap, calibrate block height. Monitor hole on trip tank - static.;Service rig: grease crown, blocks, wash pipe, top drive, drawworks, spinners and iron roughneck. Check oil in top drive, check welds on TD cradle.;Drain riser and remove. Stab and install RCD bearing onto stand. Install RCD head. Line up and pump at 2 bpm checking for leaks - good.;Wash down from 5,168' to 5,294' at 400 gpm, 900 psi, 40 rpms, 10,5Kft-lbs. PUW 152K, SOW 80K, ROTW 104K. Obtain SPR's 32/48 strokes MP1 150/194, MP2 152/198.;Drill 8.5" lateral F/ 5,294' - T/ 5,432' (138' total, 138fph AROP). WOB 2-6K, 500 gpm, 1275 psi, 120 rpm, 9-12K tq on, 10K tq off btom. 9.74 ECD's with 8.9 ppg MW. Max Gas = 1231U. P/U 151K, S/O 73K, ROT 102K.;Change out liner and swab MP#1, Mod#3.;Drill 8.5" lateral F/ 5,432' - T/ 5,678' (246' total, 99fph AROP). WOB 6-8K, 500 gpm, 1300 psi, 120 rpm, 11K tq on, 10K tq off btom. 9.92 ECD's with 8.9 ppg MW. Max Gas = 1050U. P/U 154K, S/O 74K, ROT 100K.;No faults have been crossed yet this lateral. 3 concretions have been drilled so far, for a total footage of 19’ (6.9% of the lateral). 276' drilled in NB sands. Distance to WP 07: 16.02', 15.49' High, 4.09' Right;Daily fluid hauled to G&I 575 bbls total = 6,103 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 260 bbls total = 7,065 bbls Daily Fluid lost 0 bbls total fluid lost Production = 0 bbls Fluid lost surface hole = 36 bbls 6/1/2020 Drill 8.5" lateral F/ 5,678' - T/ 6095' MD, 3817' TVD (417' total, 119' AROP). WOB 6-8K, 500 gpm In/Out, 1365 psi, 115 rpm, 12K tq on, 10.5K tq off btm. 10 ECD w/ 8.9 MW. 154k up, 72k dn, 98k rot. Drilling on concretion @ 6095' MD. Saw significant amount of oil back at shakers / 1530u gas.;Shakers unable to maintain due to heavy oil back at surface. Reduced rate to 230 gpm with no success. Shut down and close MPD. Floats not holding, show 263 psi on DP (10.3 EMW), 288 building to 300 psi on casing over 10 min. C/O shaker screens From 170/140's to 140/120's on both shakers.;Stage pumps up 2 bpm, 406 psi, 40 rpm, 7.5k tq w/ MPD holding 10.8 EMW. Work pipe while circulating btms up @ 6095' MD / 3817' TVD w/ 8.9 MW. Stage up to 200 gpm, 609 ps 1st btms up. Increase MW from 8.9 ppg to 9.3 ppg. Stage up to 500 gpm @ 2 btms up shakers cleaned up.;Drill 8.5" lateral F/ 6095' - T/ 6505' MD, 3817' TVD (410' total, 102' AROP). WOB 10-15K, 500 gpm In/Out, 1520 psi, 110 rpm, 11K tq on, 9.5K tq off btm. MPD holding back 275 psi dynamic, 320 psi on connections. 11.1 ECD w/ 9.3 MW. 130k up, 72k dn, 100k rot.;Drill 8.5" lateral F/ 6,505' - T/ 6,758' (253' total, 42fph AROP). WOB 10-12K, 400-500 gpm, 1105/1300 psi, 100-120 rpm, 11K tq on, 10K tq off btom. MPD holding 130 psi dynamic, 275 psi on connections. 10.6 ECD's with 9.3 ppg MW. Max Gas = 883U. P/U 154K, S/O 74K, ROT 100K.;Crossed fault #1 at 6684', correlating to a hard spot. Slow rotary and stage WOB up. At 6690' observe Beyond return falling by 50% and lost 15 bbls in 5 minutes. Pick up off bottom and regain full circulation. Attempt to continue drilling observing 50% decrease in return flow once on bottom and;200-300 psi increase. Oil at shakers from calc bottoms up from initial loss. Pick up and regain full circulation. Slow pumps to 400 gpm, 1105 psi, 80 rpms 10.2Kft-lbs, Beyond holding pressure for 10.6 ppg EMW ECD. Lower max WOB to 5K, and ease to bottom. Continue drilling with no issues.;Drill 8.5" lateral F/ 6,758' - T/ 7,331' (573' total, 96 fph AROP). WOB 8-12K, 450 gpm, 1418 psi, 120 rpm, 14.5K tq on, 13K tq off btom. MPD holding 120 psi dynamic, 275 psi on connections. 10.86 ECD's with 9.3 ppg MW. Max Gas = 650U. P/U 148K, S/O 71K, ROT 98K.;One fault has been crossed so far this lateral (6684') 11 concretions have been drilled so far, for a total footage of 52’ (2.7% of the lateral). 1901' drilled in NB sands. Distance to WP 07: 9.39', 5.98' Low, 7.24' Right;Daily fluid hauled to G&I 627 bbls total = 6,730 bbls Daily metal recovered 5 lbs, total = 5 lbs Daily water hauled from L Pad Lake 520 bbls total = 7,585 bbls Daily Fluid lost 30 bbls total fluid lost Production = 30 bbls Fluid lost surface hole = 36 bbls 6/2/2020 Drill 8.5" lateral F/ 7,331' - T/ 7,903' (572' total, 95 fph AROP). WOB 4-8K, 450 gpm, 1380 psi, 110 rpm, 14K tq on, 13K tq off btom. MPD holding 110 psi dynamic, 270 psi on connections. 10.88 ECD's with 9.3 ppg MW. Max Gas = 638U. P/U 155K, S/O 66K, ROT 100K.;Drill 8.5" lateral F/ 7,903' - T/ 8,540' (637' total, 106 fph AROP). WOB 10-13K, 470 gpm, 1530 psi, 100 rpm, 14K tq on, 13K tq off btom. MPD holding 80 psi dynamic, 230 psi on connections. 10.94 ECD's with 9.3 ppg MW. Max Gas = 838U. P/U 151K, S/O 66K, ROT 100K.;Crossed fault at 7,970', faulting above NB sands. Re-acquired NB sands at 8,333', exiting base at 8,514'.;Drill 8.5" lateral F/ 8,540'- T/9,239' (699' total, 116 fph AROP). WOB 13-17K, 430 gpm, 1555 psi, 120 rpm, 15.5K tq on, 16K tq off btom. MPD chokes open dynamic, 210psi on connections. 11.0 ECD's, 9.3 ppg MW. Max Gas = 951U. P/U 147K, S/O 60K, ROT 102K. Target 93° to re-acquire NB sands at 8758'.;Drill 8.5" lateral F/ 9,239'- T/9747' (508' total, 85 fph AROP). WOB 4-8K, 450 gpm, 1640 psi, 120 rpm, 17.5K tq on, 18K tq off btm. MPD chokes open dynamic, 210psi on connections. 11.04 ECD's, 9.3 ppg MW. Max Gas = 820U. P/U 170K, S/O 62K, ROT 101K. Exit base of NB at 9493'.;Target up to 93° to re- acquire NB sands with an 88.7° bed dip.;Two faults have been crossed so far this lateral (6,684', 7,970') 18 concretions have been drilled so far, for a total footage of 78’ (1.8% of the lateral). 3,622' drilled in NB sands, 754' out of NB sands. Distance to WP07: 39.98'; 39.68' low, 4.84' Right.;Daily fluid hauled to G&I 1026 bbls total = 7,756 bbls Daily metal recovered 5 lbs, total = 10 lbs Daily water hauled from L Pad Lake 1170 bbls total = 8,755 bbls Daily Fluid lost 0 bbls total fluid lost Production = 30 bbls Fluid lost surface hole = 36 bbls 6/3/2020 Drill 8.5" lateral F/ 9,747'- T/10,300' (553' total, 92 fph AROP). WOB 6-8K, 450 gpm, 1680 psi, 115 rpm, 19.5K tq on, 19K tq off btm. MPD chokes open dynamic, 200psi on connections. 11.37 ECD's, 9.3 ppg MW. Max Gas = 531U. P/U 196K, S/O N/A, ROT 97K. Lost SOW at 10,066'.;Drilling in what appeared to be NB sands since 9731' was actually NC-sands. After re-interpretation of logs a fault was determined to be crossed at 9520' with 21'DTS throw.;BROOH from 10,300' to 8,731' at 450 gpm, 1500 psi, 80 rpms, 15Kft-lbs. max gas 640U, ECD 10,5 ppg. P/U 175K, S/O 60K, ROTW 100K. MPD holding 190 psi on connections.;CBU at 450 gpm, 1500 psi, 80 rpm, 13.5Kft-lbs. Max gas 225U. ECD 10.9. Reciprocating pipe.;Pick up working single and trough from 8,780' to 8,855' at 35 fpm, 450 gpm, 1475 psi, 80 rpms, 13.5Kft-lbs. Observe 0.8° inclination drop from PB wellbore. Pick up and L/D working single. Time drill from 8,800' to 8.826' with TF of 170R at 450 gpm, 1475 psi, 100 rpms, 14.5Kft-lbs.;Initial ROP 10 fph. At 8814' Observe 1.94° drop in inclination with 1.68° difference from PB wellbore. Increase ROP to 15 fph staging up to 50 fph by 8,855'. Max gas 196. ECD 10.84. Backream up to KOP 8780' and slack off with no rotary into new hole.;Drill 8.5" lateral F/ 8,855'- T/9,239' (384' total, 70 fph AROP). WOB 6-10K, 450 gpm, 1650 psi, 135 rpm, 16K tq on, 15.5K tq off btm. MPD chokes open dynamic, 200psi on connections. 10.87 ECD's, 9.3 ppg MW. Max Gas = 766U. P/U 159K, S/O 63K, ROT 98K.;Two faults have been crossed so far this lateral in the motherbore; 6,684'; 7,970'. One plugback has been drilled (8,780'-10,300'). 19 concretions have been drilled so far, for a total footage of 103’ (2.7% of the motherbore lateral). Distance to WP07: 28.08', 27.5' Low, 5.66' right.;Daily fluid hauled to G&I 834 bbls total = 8,590 bbls Daily metal recovered 2 lbs, total = 12 lbs Daily water hauled from L Pad Lake 910 bbls total = 9,665 bbls Daily Fluid lost 0 bbls total fluid lost Production = 30 bbls Fluid lost surface hole = 36 bbls 6/4/2020 Drill 8.5" lateral F/ 9,239'- T/ 9,621' (382' total, 64 fph AROP). WOB 10K, 450 gpm, 1729 psi, 130 rpm, 17.5K tq on, 17K tq off btm. MPD chokes open dynamic, 200psi on connections. 10.98 ECD's, 9.3 ppg MW. Max Gas = 665U. P/U 163K, S/O 63K, ROT 97K.;Drill 8.5" lateral F/ 9,621'- T/ 9,938' (317' total, 53 fph AROP). WOB 17-21K, 450 gpm, 1950 psi, 90 rpm, 19-21K tq on, 16.5K tq off btm. MPD chokes open dynamic, 190psi on connections. 11.22 ECD's, 9.3 ppg MW. Max Gas = 665U. P/U 167K, S/O N/A, ROT 97K.;Drill 8.5" lateral F/ 9,938'- T/ 10,163' (224' total, 90 fph AROP). WOB 16-21K, 450 gpm, 1980 psi, 110 rpm, 19-20.5K tq on, 17K tq off btm. MPD chokes open dynamic, 190psi on connections. 11.2 ECD's, 9.3 ppg MW. Max Gas = 497U. P/U 167K, S/O N/A, ROT 97K. Re-interpretation of logs shows;fault #3 at 9,905' with a throw of 14' DTS placing wellbore above NB sands since 9579'. Obtain survey on bottom.;BROOH from 10,62' to 9340' at 450 gpm, 2020 psi, 80 rpms, 13-15Kft-lbs, max gas 379U. ECD 11.0 ppg EMW. P/U 157K, S/O 64K, ROT 100K. MPD choke open while pumping, holding 200 psi on connections.;Open hole sidetrack from 9,340' to 9431' at 450 gpm, 1650 psi, 80 rpms, 13.5Kft-lbs, ECD 10.88 ppg. P/U 157K, S/O 64K, ROT 100K. Attempt to trough at 30 fpm, but observe wellbore dropping quick 1.5° by 9350', 2.2° by 9360'. Continue sidetracking staging ROP up to 75 fph. BROOH to 9,330';wash down to 9431' to ensure tracking new wellbore.;Drill 8.5" lateral F/ 9,431'- T/ 9,747' (31' total, 90 fph AROP). WOB 5-10K, 450 gpm, 1564 psi, 130 rpm, 15.5K tq on, 15K tq off btm. MPD chokes open dynamic, 190psi on connections. 10.96 ECD's, 9.3 ppg MW. Max Gas = 748U. P/U 154K, S/O 60K, ROT 100K.;Two faults have been crossed so far this lateral in the motherbore; 6,684'; 7,970'. Two plug backs have been drilled; 8,780' - 10,300'; 9,340' - 10,163' 26 concretions have been drilled so far, for a total footage of 167’ (3.8% of the motherbore lateral).3,746' drilled in NB sands, 607' out of zone.;Distance to WP 07: 41.48', 33.81' low, 24.2' right.;Daily fluid hauled to G&I 570 bbls total = 9,160 bbls Daily metal recovered 3 lbs, total = 15 lbs Daily water hauled from L Pad Lake 650 bbls total = 10,315 bbls Daily Fluid lost 0 bbls total fluid lost Production = 30 bbls Fluid lost surface hole = 36 bbls 6/5/2020 Drill 8.5" lateral F/ 9,747'- T/ 10,385' (685' total, 106 fph AROP). WOB 2-6K, 450 gpm, 1692 psi, 130 rpm, 17.5K tq on, 17K tq off btm. 11.32 ECD's, 9.3 ppg MW. Max Gas = 673U. P/U 167K, S/O N/A, ROT 98K. Lost S/O at 10,385'. MPD holding 50-70 psi dynamic, 230psi on connections. Backream 30'.;Crossed fault #3 at 9,903' with estimate 14' DTS throw. Faulting below the NB-sands, Re-acquire NB sands at 10,013'.;Drill 8.5" lateral F/ 10,385'- T/ 11,000' (615' total, 103 fph AROP). WOB 4-6K, 450 gpm, 1635 psi, 130 rpm, 15.7K tq on, 16K tq off btm. 11.09 ECD's, 9.3 ppg MW. Max Gas = 920U. P/U 166K, S/O 50K, ROT 101K. MPD chokes open dynamic, 220psi on connections. Backream 30' on connections.;Drill 8.5" lateral F/ 11,000'- T/ 11,594' (594' total, 99 fph AROP). WOB 6K, 400 gpm, 1296 psi, 125 rpm, 15.5K tq on, 16K tq off btm. 10.94 ECD's, 9.3 ppg MW. Max Gas = 655U. P/U 177K, S/O 54K, ROT 104K. MPD chokes open dynamic, 220psi on connections. Backream 30' on connections.;Drill 8.5" lateral F/ 11,594'- T/ 12,200' (606' total, 101 fph AROP). WOB 6K, 450 gpm, 1454 psi, 125 rpm, 17.4K tq on, 18K tq off btm. 10.80 ECD's, 9.3 ppg MW. Max Gas = 688U. P/U 171K, S/O N/A, ROT 101K. MPD holding 60 psi dynamic, 190 psi on connections. Backream 30' on connections.;Three faults have been crossed so far this lateral in the motherbore; 6,684'; 7,970'; 9,903'. Two plug backs have been drilled; 8,780' - 10,300'; 9,340' - 10,163'. 45 concretions have been drilled so far, for a total footage of 250’ (3.7% of the motherbore lateral).;6,099' drilled in NB sands, 717' out of zone. Distance to WP07: 24.24'; 19.23' low, 14.75' left.;Daily fluid hauled to G&I 1140 bbls total = 10,300 bbls Daily metal recovered 10 lbs, total = 25 lbs Daily water hauled from L Pad Lake 910 bbls total = 11,225 bbls Daily Fluid lost 0 bbls total fluid lost Production = 30 bbls Fluid lost surface hole = 36 bbls 6/6/2020 Drill 8.5" lateral F/ 12,200'- T/ 12,798' (598' total, 100 fph AROP). WOB 11K, 450 gpm, 1640 psi, 150 rpm, 22K tq on, 23K tq off btm. 11.25 ECD's, 9.3 ppg MW. Max Gas = 645U. P/U 201K, S/O N/A, ROT 99K. MPD holding 40 psi dynamic, 220 psi on connections. Backream 30' on connections.;Drill 8.5" lateral F/ 12,798'- T/ 13,434' (636' total, 106 fph AROP). WOB 12K, 450 gpm, 1760 psi, 120 rpm, 24K tq on, 26K tq off btm. 11.43 ECD's, 9.3 ppg MW. Max Gas = 685U. P/U 203K, S/O N/A, ROT 97K. MPD chokes open dynamic, 190 psi on connections. Backream 30' on connections.;Drill 8.5" lateral F/ 13,434'- T/ 13,817' (383' total, 64 fph AROP). WOB 15K, 450 gpm, 1721 psi, 120 rpm, 22K tq on, 23.5K tq off btm. 11.43 ECD's, 9.4 ppg MW. Max Gas = 644U. P/U 201K, S/O N/A, ROT 95K. MPD chokes open dynamic, 190 psi on connections. Backream 30' on connections.;Drill 8.5" lateral F/ 13,817'- T/ 14,265' (448' total, 75fph AROP). WOB 15K, 450gpm, 1889 psi, 120 rpm, 24K tq on, 24.5K tq off btm. 11.63 ECD's, 9.3 ppg MW. Max Gas=655U. P/U 199K, S/O N/A, ROT 97K. MPD chokes open dynamic, 190 psi on connections. Backream 30' on connections.Obtain final survey.;Three faults have been crossed so far this lateral in the motherbore; 6,684'; 7,970'; 9,903' Two plug backs have been drilled; 8,780' - 10,300'; 9,340' - 10,163' 68 concretions were drilled for a total footage of 357’ (4.0% of the motherbore lateral).;8,284' drilled in NB sands, 717' out of zone. Distance to WP07: 8.86'; 0.05' low, 8.86' left.;Daily fluid hauled to G&I 1430 bbls total = 11,730 bbls Daily metal recovered 5 lbs, total = 30 lbs Daily water hauled from L Pad Lake 1300 bbls total = 12,525 bbls Daily Fluid lost 0 bbls total fluid lost Production = 30 bbls Fluid lost surface hole = 36 bbls 6/7/2020 Pump tandem low vis/wt, high vis/wt sweeps, 100 bbls late ,100% increase in cuttings. Circulate total of 4 bottoms up, racking stand back every BU at 500 gpm, 1803 psi, 130 rpms, 22.5Kft-lbs, reciprocating pipe. ECD 11.47 ppg. P/U 210K, S/O N/A, ROT 99K. SimOps: Clean pits, Build SAPP pills.;Wash and ream from 14,008 to TD 14,265' 500 gpm, 1875 psi, 130 rpms, 21Kft-lbs.;Pump SAPP train and displace to 9.3 ppg Quickdril at 290 gpm, 1055 psi, 115 rpms, 22Kft-lbs. MPD holding 50-200 psi to maintain 10.7 ppg ECD. Opbtain SPR's at 14,260 32/48 stokes MPD holding 160 psi MP 1 420/492 psi, MP2 418/490 psi.;BROOH from 14260' to 12,940' at 500 gpm, 1750 psi, 120 rpms, 13-19Kft-lbs. P/U 172K, S/O N/A ROT 102K. Drop 2.375" OD drift at stand 218. Pull 15 -35 fpm as hole dictates. Slack off 15' and slow pulling speed when slight pack-offs observed at 13,175, 12,948'.;BROOH from 12,940' to 10,000' at 500 gpm, 1600 psi, 120 rpms, 10-12K. P/U 153K, S/O 57K, ROT 103K. Max Gas 253U. ECD 10.56 ppg. MPD holding 165 psi on connections. Pull 10-35 fpm as hole dictates. Slack off 15' and slow pulling speed when slight pack-offs observed at 12318'; 12146',11161', 10234'.;BROOH from 10,000' to 8,144' at 500 gpm, 1500 psi, 130 rpms, 10.5K. P/U 148K, S/O 69K, ROT 102K. Max Gas 1144U. ECD 10.7 ppg. MPD holding 165 psi on connections. Pull 2-30 fpm as hole dictates. Multiple packoffs through NB- clay from 8700'-8400', and NA-Clay from 8290'; slow pulling speed 2-15 fpm as;hole dictates, slacking off ~15' when pack-offs observed. Increase rotary to 130 rpms.;Daily fluid hauled to G&I 1836 bbls total = 13,566 bbls Daily metal recovered 6 lbs, total = 36 lbs Daily water hauled from L Pad Lake 390 bbls total = 12,915 bbls Daily Fluid lost 0 bbls total fluid lost Production = 30 bbls Fluid lost surface hole = 36 bbls 6/8/2020 Cont. to BROOH from 8144' to 5614' at 500 gpm, 1340 psi, 130 rpms, 8Kft-lbs. P/U 136K, S/O 82K, ROT 103K. Max gas 362U. Pull 2-30 fpm as hole dictates. Cont. pulling 2-15 fpm through NA-Clay from 8290' to 7967' with multiple packoffs. MPD chokes wide open dynamically, holding 160psi on connect.;Cont. to BROOH from 5614' to 5232', inside casing shoe. 450 gpm, 1100 psi, 60 rpms, 8Kft-lbs. P/U 144, S/O 82K, ROT 104K. Max gas 18U. Observed high torque (18K max) and slight packoffs as drill collars come through shoe. MPD holding 160 on connections, open chokes dynamically.;Pump high vis sweep (10% increase in cuttings) and circulate additional bottoms up at 550 gpm, 1580 psi, 40 rpms, 7.5Kft-lbs. Max gas 58U. Reciprocating pipe.;Monitor well. Observe flow out diminish from 60 to 5 gpm in 10 minutes. Shut in and monitor, built 29 psi in 5 minutes. Open chokes, static in three minutes. Shut in and observe 7 psi build. Open chokes - well static. Sim Ops tighten hyd valves on top drive and shot pin assembly.;Weigh up mud from 9.3 ppg to 9.5 ppg for trip margin. 550 gpm, 1580 psi.;Monitor hole - static. Pull MPD bearing, install riser.;POOH from 5232' to 273'. Laying down drill pipe. After 5 stands pump dry job with corrosion inhibitor. Calc hole fill 51, Act. 60 lost 9 bbls.;L/D BHA. L/D HWDP, Jars, DC, Drift recovered on float. Attempt to download MWD. Download locked up. continue to L/D BHA to download MWD on ground. ILS on ADR had significant wear on top. Bit Grade 3-4-BT-A-X-I-CT-TD. Clean and clear rig floor of BHA components.;Service rig: grease and inspect crown, blocks and top drive.;Rig up Weatherford power tongs, Change out elevators. Bring up centralizers and stop rings to rig floor.;P/U Innovex Solid guide shoe and RIH with 4-1/2", 13.5#, L-80, 625W 250 screens to 2990' as per tally. Torque connections to 9,600 ft-lbs P/U 78K, S/O 73K. Calculated displacement=14 bbls, actual 11 bbls.;Daily fluid hauled to G&I 228 bbls total = 13,794 bbls Daily metal recovered 10 lbs, total = 46 lbs Daily water hauled from L Pad Lake 390 bbls total = 13,305 bbls Daily Fluid lost 9 bbls total fluid lost Production = 39 bbls Fluid lost surface hole = 36 bbls 6/9/2020 PJSM P/U Innovex Solid Guide Shoe RIH 4.5" 13.3# L-80 W625 250u Screens W/ SB Centralizers W/ 7.5" SB Centralizers F/ 2,990' to 8,118' MD as per tally. Trq 9,600 ft/lb. Install 7.5" SB Cent & stop rings in blanks. P/U M/U SLZXP as per Baker Rep. P/U 111K SLK 71K Lost 3.4 bbls.;PJSM Convey production 4.5" Liner on 5" D.P. F/ Derrick F/ 8,154' to 10,126' MD. P/U 140K SLK 72K Fill every 5 stands W/ fill up line. Obtain parameters @ 8,282' MD 3 BPM 147 PSI 12 RPM 6.3K TRQ. P/U 140K SLK 82K ROT 89K.;PJSM Cont to convey 4.5" Liner W/ singling in hole W/ 5" HWDP F/ 10,126' to 13,224' MD. 2.75" OD Drift. RIH 90 ft/min filling every 5 stands W/ fill up line. Lost 11 bbls. P/U 227K SLK 130K. No issues.;PJSM Break Circ W/ 6 BPM 760 PSI for DS volume. P/U 227K SLK 130K. Drop 29/32 Phenolic ball as per Baker rep onsite. Pump down at 3 bpm 280 PSI slow to 1.5 BPM 145 PSI seated 3.5 bbls early. Cont to Press up to 3,000 PSI, Packer set at 2,760 PSI. Hold 3,000 PSI 5 min. Set DN 40K.;Press up to 3,700 PSI W/ Mud Pump. Swap to test pump and Press up to 4,503 PSI shift Neutralizer and release HST. P/U 3' confirm released. .R/U and test SLZXP W/ 1,500 PSI for 10 min. TOL at 5,080' MD.;PJSM L/D 2 jnts 5" HWDP F/ 5,080' to 5,035' MD. CBU at 500 GPM 1,000 PSI. Pump Corrosion Inhibited Dry Job. Blow down Top Drive, Choke and Kill Lines. Monitor hole, static.;PJSM POOH L/D 5" HWDP and 5" D.P. F/ 5,035' to surface. Lost 12 bbls. Culled pipe for CAT IV/V as per tally.;PJSM L/D Running Assy as per Baker Rep. Assy looked good and functioned properly. Break down 4.5" safety joint and X/O's.;PJSM P/U M/U 3.5" Mule Shoe stingier and 8.40" OD NoGo 30.71'. RIH W/ 5" D.P. F/ Derrick to 1,621' MD. Lost 3 bbls. P/U 65K SLK 64K.;PJSM Cont RIH W/ Stinger Assy F/ 1,621' to 5,109' MD. NoGo tagged TOL at 5,080' MD W/ 3K 2X. Break Circ at 168 BPM 185 PSI washing up above TOL to 5,055' MD. P/U 137K SLK 95K. Lost 4.5 bbls.;PJSM CBU at 5,055' MD 336 GPM 244 PSI. Monitor well 10 min, static. Pump 15 bbl 10.2 ppg Dry Job. Blow down.;PJSM Install stripping rubber and air slips. POOH L/D 5" D.P. F/ 5,055' to 2,510' MD. Culled Cat IV/ V as per tally. P/U 85K SLK 78K Lost 4.5 bbls.;PJSM RIH W/ 5" D.P. F/ Derrick F/ 2,510' to 3,782' MD. P/U 114K SLK 95K Lost 3 bbls.;Daily fluid hauled to G&I 50 bbls total = 13,844 bbls Daily metal recovered 0 lbs, total = 46 lbs Daily water hauled from L Pad Lake 130 bbls total = 13,435 bbls Daily Fluid lost 11 bbls total fluid lost Production = 50 bbls Fluid lost surface hole = 36 bbls Activity Date Ops Summary 6/10/2020 PJSM Cont RIH W/ 5" D.P. F/ Derrick F/ 3,782' to 4,734' MD. Lost 2.24 bbls. P/U 133K SLK 97K,PJSM Cut and slip drilling line 79 '. 13 wraps. ACCUM TM 37,153, 631' left on spool. Check brake gap. Grease and inspect Crown, Blocks and Top Drive. Calibrate block height. Monitor hole on TT, static.,PJSM Pump 15 bbl 10.2 ppg Dry Job. POOH L/D 5" D.P. F/ 4,734' to surface L/D NoGo stinger. Culled CAT IV/ V as per tally. Lost 9.5 bbls.,PJSM C/O Upper Rams to 7.625" Rams and test.,PJSM Pull wear ring and L/D.,PJSM P/U and dummy run landing joint and Hanger. Landed out at 24.5'. L/D,PJSM P/U 7.625" Test Jnt. M/U Head Pin and test plug. Flood Stack W/ H2O. Perform Shell Test. Test 7.625" Rams 250 PSI low and 3,000 PSI high F/ 5 min. Good. L/D Test Tools.,PJSM Swap out " Elevators to 7.625" Elevaotrs. Bring to rig floor 7.625" Slips, Dog Collar, Air Slips and Power Tongs.,PJSM P/U M/U 7" Tie Back Bullet Seal Assy to Jnt #1 7.625" 29.7# L-80 W521 as per Baker Rep onsite. RIH to 546' at 90 ft/min. Brine coming over stump at connections. P/U 57K SLK 57K TRQ to 10.1K.,PJSM Cont RIH W/ 7.625" 29.7# L-80 W521 F/ 546' to NoGo at 5,078.03' MD. Run speed 90 ft/min. Brine coming over stump at connections. TRQ 10.1K. L/D Jnts 125, 126 & 127. Space W/ Jnts 129 and 130. P/U M/U Hanger and landing jnt. Land Hanger W/ 74K on Hanger 1.26' off NoGo. Swallowed 8.33' of seals. P/U 158K SLK 109K Lost 17 bbls.,PJSM M/U Head Pin and HP lines to landing jnt. Flush through Kill and Choke Manifold. Close Annular and Press up to 500 PSI for 2 min, bleed down to 250 PSI. Slowly pick up string until 1 ports were exposed and Press dropped.,PJSM Reverse Circ and displace 9.5 Quickdril to 9.5 ppg 2% KCL / NaCl W/ Corrosion Inhibited brine. Pumped 290 bbls 9.5 ppg Brine followed by 50 bbls Diesel at 4 bpm ICP 175 PSI FCP 503 PSI. Pump 100 bbls H2O to clear lines. No losses. SIMOPS Process 3.5" Tubing and spot Spooling Unit.,PJSM Strip down through Annular and land Hanger W/ 74K. Bleed off Press & check for flow, static. R/D HP lines and L/D landing joint. P/U 5" D.P. and set Pack Off as per NOS. RILDS. Test Pack Off 500 PSI low 5 min, 5,000 PSI high 10 min. Test 9 5/8" X 7.625" to 1,000 PSI for 30 min on chart Pump 1.4 bbls, bled bacl 1.4 bbls. SIMOPS process 3.5" Tubing and bring in completion jewelry. Clean and clear rig floor.,PJSM Stage on rig floor Cannon Clamps, Flat Clamps, ESP Sheave and Job Box.,Daily fluid hauled to G&I 114 bbls total = 13,958 bbls Daily metal recovered 0 lbs, total = 46 lbs Daily water hauled from L Pad Lake 0 bbls total = 13,435 bbls Daily Fluid lost 28 bbls total fluid lost Production = 78 bbls Fluid lost surface hole = 36 bbls 6/11/2020 PJSM R/U Centrilift and ESP sheave. String up ESP cable. P/U M/U 562 XP Motor and service W/ oil and work out air. M/U Upper and Lower Tandem Seals to motor. P/U and install Centralizer. Install motor lead and test, Terminate CAP line F/ Motor Gauge Zenith to Zenith ported sub. R/U 3.5" Elevators and Power Tongs. Trq Discharge Head to 3.5" Tubing Pup.,RIH ESP W/ 3.5" 9.3# L-80 8rd EUE F/ 74' to 1,410' MD. Install Cannon Clamps on first 15 Jnts and every other one after. TRQ 3200 ft/lb. P/U 50K SLK 50K. Test ESP cable every 1,000'. Install X/N 6.75" NoGo and GLM W/ Dummy as per tally. No losses.,PJSM Cont RIH ESP W/ 3.5" 9.3# L-80 8rd EUE F/ 1,410' to 5,017' MD. Install Cannon Clamps every other Jnt. TRQ 3200 ft/lb. P/U 85K SLK 62K. Test ESP cable every 1,000'. Install GLM W/ SO as per tally. Lost 7 bbls.,PJSM R/D 3.5" Elevators and install 5" Elevators. M/U 5" D.P. X/O to NSCT to Hanger. M/U Hanger and terminate ESP cable. Make up Penetrator. Total Pump Clamps 4 ea. Seal Clamps 4 ea, CC 90 ea. L/D Weatherford handling Equip.,PJSM Spool up excess ESP Cable to Spooler. R/D ESP Sheave. Perform final test on ESP Penetrator as per Centrilift. PH-PH 3m, PH-GRD 1.8g, PI 1,906 PSI, PD ,1906 PSI, TI 77° F, TM 77° F, VX .007, VY .015, VT 121, CT 9.9. INstall BPV and land Hanger to 5,042' MD. 27K on Hanger. P/U 85K, SLK 62K.,PJSM Flush thru BOP Stack and Johnny Whack. Flush Choke, Kill, Choke Manifold and Poorboy W/ corrosion inhibited soapy water.,PJSM Bleed off Koomey. Open ram doors and C/O 7" Upper Rams to 2.875" X 5.5" Rams.,PJSM 4 Bolt BOP Stack. P/U RCD W Blocks. Remove RCD bolts F/ Annular. Rack back BOP to pedestal W/ spacer spool, secure. Remove 11" X 13 5/8" DSA. SIMOPS Clean Pits and load 5" D.P. in Pipe Shed.,PJSM Test ESP cable and pump as per Centrilift. Install CTS on BPV. Clean ring groove. P/U Dry Hole Tree and install. Trq head to spec. Test void 500 PSI low 5 min, 5,000 PSI high 15 min. SIMOPS Process 5" D.P., clean Pits and PM on MP's. Prep Pipe Shed for move. Rig Released 06:00,Daily fluid hauled to G&I 986 bbls total = 14,944 bbls Daily metal recovered 0 lbs, total = 46 lbs Daily water hauled from L Pad Lake 130 bbls total = 13,565 bbls Daily Fluid lost 7 bbls total fluid lost Production = 85 bbls Fluid lost surface hole = 36 bbls Contractor AFE #: AFE $: Job Name:2011148C MPU I-36 Completion Spud Date: Well Name: Field: County/State: MP I-36 Milne Point Hilcorp Energy Company Composite Report , Alaska n (LAT/LONG): evation (RKB): API #: 08 June, 2020 Milne Point M Pt I Pad MPU I-36 500292367700 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: MPU I-36, Slot I-26 usft usft 0.00 0.00 6,009,444.08 551,689.19 33.60Wellhead Elevation:33.60 usft0.50 70° 26' 11.572 N 149° 34' 42.850 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-36 Model NameMagnetics IFR 6/1/2020 15.96 80.87 57,384.00000000 Phase:Version: Audit Notes: Design MPU I-36 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:9,296.01 6.500.000.0026.59 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 6/8/2020 Survey Date 3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing100.00 951.00 MPU I-36PB1 E-Line gyro (1) (MPU I-36P 05/18/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa1,015.18 1,142.57 MPU I-36PB1 MWD+IFR2+MS+Sag (1) (05/18/2020 3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing1,207.00 1,588.00 MPU I-36PB1 E-Line gyro (2) (MPU I-36P 05/18/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa1,651.17 5,234.71 MPU I-36PB1 MWD+IFR2+MS+Sag (2) (05/26/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa5,287.70 8,722.74 MPU I-36PB1 MWD+IFR2+MS+Sag (3) (06/01/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa8,780.00 9,296.01 MPU I-36PB2 MWD+IFR2+MS+Sag (4) (06/03/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa9,340.00 14,195.54 MPU I-36 MWD+IFR2+MS+Sag (5) (MPU 06/03/2020 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 26.59 0.00 0.00 26.59 0.00 0.00-33.60 6,009,444.08 551,689.19 0.00 0.00 UNDEFINED 100.00 0.09 93.95 100.00 0.00 0.0639.81 6,009,444.08 551,689.25 0.12 0.00 3_Gyro-GC_Csg (1) 134.00 0.30 210.44 134.00 -0.08 0.0473.81 6,009,444.00 551,689.23 1.03 -0.08 3_Gyro-GC_Csg (1) 198.00 0.32 263.84 198.00 -0.25 -0.22137.81 6,009,443.83 551,688.97 0.44 -0.27 3_Gyro-GC_Csg (1) 258.00 0.27 341.36 258.00 -0.13 -0.44197.81 6,009,443.95 551,688.76 0.62 -0.18 3_Gyro-GC_Csg (1) 320.00 1.34 342.11 319.99 0.70 -0.70259.80 6,009,444.77 551,688.48 1.73 0.61 3_Gyro-GC_Csg (1) 383.00 2.49 332.26 382.96 2.61 -1.57322.77 6,009,446.68 551,687.60 1.89 2.42 3_Gyro-GC_Csg (1) 446.00 2.91 327.90 445.89 5.18 -3.05385.70 6,009,449.23 551,686.10 0.74 4.80 3_Gyro-GC_Csg (1) 509.00 2.58 323.81 508.81 7.68 -4.74448.62 6,009,451.72 551,684.40 0.61 7.09 3_Gyro-GC_Csg (1) 6/8/2020 5:33:11PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 571.00 2.24 307.24 570.76 9.53 -6.53510.57 6,009,453.57 551,682.59 1.24 8.73 3_Gyro-GC_Csg (1) 633.00 2.01 296.37 632.72 10.75 -8.47572.53 6,009,454.77 551,680.65 0.75 9.72 3_Gyro-GC_Csg (1) 697.00 2.06 281.35 696.68 11.48 -10.60636.49 6,009,455.48 551,678.51 0.83 10.20 3_Gyro-GC_Csg (1) 761.00 3.44 261.49 760.60 11.42 -13.63700.41 6,009,455.40 551,675.48 2.59 9.80 3_Gyro-GC_Csg (1) 824.00 4.70 248.27 823.44 10.18 -17.90763.25 6,009,454.14 551,671.22 2.48 8.09 3_Gyro-GC_Csg (1) 888.00 6.29 240.57 887.15 7.49 -23.39826.96 6,009,451.41 551,665.75 2.73 4.79 3_Gyro-GC_Csg (1) 951.00 7.59 232.77 949.69 3.28 -29.71889.50 6,009,447.15 551,659.47 2.54 -0.11 3_Gyro-GC_Csg (1) 1,015.18 9.12 234.54 1,013.18 -2.24 -37.22952.99 6,009,441.58 551,651.99 2.42 -6.44 3_MWD+IFR2+MS+Sag (2) 1,078.44 10.56 232.07 1,075.51 -8.71 -45.881,015.32 6,009,435.05 551,643.38 2.37 -13.85 3_MWD+IFR2+MS+Sag (2) 1,142.57 11.51 238.22 1,138.46 -15.69 -55.951,078.27 6,009,428.00 551,633.35 2.36 -21.93 3_MWD+IFR2+MS+Sag (2) 1,207.00 12.45 235.14 1,201.48 -23.05 -67.121,141.29 6,009,420.57 551,622.24 1.76 -30.50 3_Gyro-GC_Csg (3) 1,270.00 13.12 234.68 1,262.92 -31.06 -78.521,202.73 6,009,412.47 551,610.89 1.08 -39.75 3_Gyro-GC_Csg (3) 1,333.00 14.49 240.80 1,324.10 -39.04 -91.241,263.91 6,009,404.41 551,598.23 3.18 -49.12 3_Gyro-GC_Csg (3) 1,396.00 16.11 244.83 1,384.87 -46.61 -106.031,324.68 6,009,396.74 551,583.49 3.07 -58.31 3_Gyro-GC_Csg (3) 1,462.00 18.22 243.34 1,447.93 -55.13 -123.541,387.74 6,009,388.10 551,566.04 3.27 -68.76 3_Gyro-GC_Csg (3) 1,526.00 18.84 242.71 1,508.61 -64.36 -141.671,448.42 6,009,378.75 551,547.98 1.02 -79.98 3_Gyro-GC_Csg (3) 1,588.00 21.89 241.04 1,566.73 -74.55 -160.681,506.54 6,009,368.43 551,529.04 5.01 -92.26 3_Gyro-GC_Csg (3) 1,651.17 23.72 240.78 1,624.96 -86.45 -182.081,564.77 6,009,356.37 551,507.74 2.90 -106.51 3_MWD+IFR2+MS+Sag (4) 1,715.52 24.91 242.99 1,683.60 -98.93 -205.451,623.41 6,009,343.74 551,484.45 2.33 -121.55 3_MWD+IFR2+MS+Sag (4) 1,778.74 27.19 244.68 1,740.39 -111.15 -230.371,680.20 6,009,331.34 551,459.62 3.79 -136.52 3_MWD+IFR2+MS+Sag (4) 1,841.94 31.04 245.69 1,795.60 -124.04 -258.281,735.41 6,009,318.26 551,431.80 6.14 -152.48 3_MWD+IFR2+MS+Sag (4) 1,905.18 33.50 246.09 1,849.07 -137.83 -289.101,788.88 6,009,304.26 551,401.08 3.90 -169.67 3_MWD+IFR2+MS+Sag (4) 1,968.43 33.50 247.53 1,901.81 -151.58 -321.191,841.62 6,009,290.30 551,369.09 1.26 -186.96 3_MWD+IFR2+MS+Sag (4) 2,032.25 34.34 247.87 1,954.77 -165.09 -354.141,894.58 6,009,276.56 551,336.24 1.35 -204.12 3_MWD+IFR2+MS+Sag (4) 2,095.61 34.07 248.38 2,007.17 -178.36 -387.191,946.98 6,009,263.06 551,303.28 0.62 -221.04 3_MWD+IFR2+MS+Sag (4) 2,159.62 34.29 248.80 2,060.12 -191.49 -420.671,999.93 6,009,249.70 551,269.90 0.50 -237.88 3_MWD+IFR2+MS+Sag (4) 2,223.28 34.49 247.89 2,112.66 -204.75 -454.092,052.47 6,009,236.20 551,236.58 0.87 -254.84 3_MWD+IFR2+MS+Sag (4) 2,287.07 34.39 247.55 2,165.27 -218.43 -487.472,105.08 6,009,222.30 551,203.29 0.34 -272.21 3_MWD+IFR2+MS+Sag (4) 2,351.14 33.70 248.66 2,218.35 -231.81 -520.752,158.16 6,009,208.69 551,170.11 1.45 -289.27 3_MWD+IFR2+MS+Sag (4) 2,414.81 34.22 252.54 2,271.17 -243.61 -554.282,210.98 6,009,196.66 551,136.66 3.50 -304.79 3_MWD+IFR2+MS+Sag (4) 2,478.53 34.17 256.81 2,323.88 -253.07 -588.802,263.69 6,009,186.96 551,102.21 3.77 -318.10 3_MWD+IFR2+MS+Sag (4) 2,541.98 34.10 258.92 2,376.40 -260.56 -623.612,316.21 6,009,179.23 551,067.46 1.87 -329.47 3_MWD+IFR2+MS+Sag (4) 2,605.73 31.91 262.13 2,429.87 -266.30 -657.842,369.68 6,009,173.26 551,033.27 4.39 -339.06 3_MWD+IFR2+MS+Sag (4) 2,669.90 30.49 265.38 2,484.76 -269.93 -690.872,424.57 6,009,169.39 551,000.27 3.43 -346.41 3_MWD+IFR2+MS+Sag (4) 2,732.94 29.82 269.83 2,539.27 -271.27 -722.492,479.08 6,009,167.84 550,968.67 3.70 -351.31 3_MWD+IFR2+MS+Sag (4) 2,796.95 30.07 274.78 2,594.75 -269.98 -754.392,534.56 6,009,168.91 550,936.76 3.88 -353.64 3_MWD+IFR2+MS+Sag (4) 2,860.80 30.66 281.62 2,649.85 -265.36 -786.292,589.66 6,009,173.30 550,904.84 5.49 -352.67 3_MWD+IFR2+MS+Sag (4) 2,924.72 32.36 288.10 2,704.36 -256.76 -818.522,644.17 6,009,181.68 550,872.55 5.93 -347.77 3_MWD+IFR2+MS+Sag (4) 2,988.20 33.08 292.34 2,757.78 -244.90 -850.702,697.59 6,009,193.32 550,840.29 3.78 -339.63 3_MWD+IFR2+MS+Sag (4) 3,051.62 33.27 296.39 2,810.87 -230.59 -882.292,750.68 6,009,207.41 550,808.60 3.51 -328.98 3_MWD+IFR2+MS+Sag (4) 6/8/2020 5:33:11PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,115.64 33.39 302.54 2,864.37 -213.30 -912.882,804.18 6,009,224.48 550,777.89 5.28 -315.27 3_MWD+IFR2+MS+Sag (4) 3,179.02 33.93 307.50 2,917.14 -193.15 -941.632,856.95 6,009,244.43 550,749.02 4.42 -298.50 3_MWD+IFR2+MS+Sag (4) 3,242.65 35.63 311.29 2,969.40 -170.10 -969.652,909.21 6,009,267.28 550,720.84 4.32 -278.78 3_MWD+IFR2+MS+Sag (4) 3,305.89 37.03 314.38 3,020.35 -144.63 -997.102,960.16 6,009,292.56 550,693.21 3.64 -256.57 3_MWD+IFR2+MS+Sag (4) 3,369.25 39.05 319.23 3,070.26 -116.16 -1,023.783,010.07 6,009,320.84 550,666.34 5.69 -231.31 3_MWD+IFR2+MS+Sag (4) 3,432.86 39.96 321.90 3,119.35 -84.90 -1,049.473,059.16 6,009,351.91 550,640.44 3.03 -203.16 3_MWD+IFR2+MS+Sag (4) 3,496.26 40.65 323.91 3,167.70 -52.19 -1,074.203,107.51 6,009,384.45 550,615.48 2.32 -173.46 3_MWD+IFR2+MS+Sag (4) 3,559.87 41.10 325.94 3,215.80 -18.13 -1,098.113,155.61 6,009,418.34 550,591.34 2.20 -142.32 3_MWD+IFR2+MS+Sag (4) 3,623.46 43.42 328.60 3,262.86 17.85 -1,121.213,202.67 6,009,454.16 550,567.99 4.61 -109.19 3_MWD+IFR2+MS+Sag (4) 3,687.36 45.93 330.60 3,308.30 56.60 -1,143.933,248.11 6,009,492.75 550,545.01 4.50 -73.26 3_MWD+IFR2+MS+Sag (4) 3,751.01 48.36 333.01 3,351.59 97.72 -1,165.953,291.40 6,009,533.71 550,522.70 4.72 -34.89 3_MWD+IFR2+MS+Sag (4) 3,814.61 50.62 334.54 3,392.90 141.10 -1,187.313,332.71 6,009,576.94 550,501.05 4.00 5.79 3_MWD+IFR2+MS+Sag (4) 3,878.33 53.08 337.37 3,432.27 186.86 -1,207.703,372.08 6,009,622.55 550,480.34 5.21 48.94 3_MWD+IFR2+MS+Sag (4) 3,942.08 53.73 340.20 3,470.27 234.57 -1,226.213,410.08 6,009,670.12 550,461.50 3.71 94.25 3_MWD+IFR2+MS+Sag (4) 4,005.70 55.71 342.91 3,507.02 283.83 -1,242.633,446.83 6,009,719.26 550,444.75 4.67 141.34 3_MWD+IFR2+MS+Sag (4) 4,068.79 58.34 345.42 3,541.36 334.74 -1,257.053,481.17 6,009,770.07 550,429.97 5.34 190.29 3_MWD+IFR2+MS+Sag (4) 4,132.17 58.87 347.23 3,574.38 387.31 -1,269.843,514.19 6,009,822.54 550,416.82 2.58 241.07 3_MWD+IFR2+MS+Sag (4) 4,196.17 59.31 347.63 3,607.26 440.90 -1,281.793,547.07 6,009,876.04 550,404.50 0.87 292.96 3_MWD+IFR2+MS+Sag (4) 4,259.52 60.51 348.41 3,639.02 494.52 -1,293.163,578.83 6,009,929.58 550,392.76 2.17 344.95 3_MWD+IFR2+MS+Sag (4) 4,322.71 66.27 348.87 3,667.31 549.88 -1,304.283,607.12 6,009,984.86 550,381.26 9.14 398.70 3_MWD+IFR2+MS+Sag (4) 4,386.86 70.42 350.37 3,690.98 608.52 -1,315.013,630.79 6,010,043.41 550,370.13 6.82 455.74 3_MWD+IFR2+MS+Sag (4) 4,449.92 72.89 351.55 3,710.82 667.63 -1,324.413,650.63 6,010,102.45 550,360.32 4.30 513.41 3_MWD+IFR2+MS+Sag (4) 4,513.38 74.22 354.14 3,728.79 728.01 -1,331.983,668.60 6,010,162.77 550,352.32 4.44 572.54 3_MWD+IFR2+MS+Sag (4) 4,576.91 76.55 356.26 3,744.82 789.26 -1,337.123,684.63 6,010,223.98 550,346.76 4.89 632.82 3_MWD+IFR2+MS+Sag (4) 4,640.54 78.38 358.01 3,758.63 851.29 -1,340.223,698.44 6,010,285.98 550,343.23 3.93 694.10 3_MWD+IFR2+MS+Sag (4) 4,703.10 81.90 359.52 3,769.35 912.90 -1,341.543,709.16 6,010,347.57 550,341.48 6.11 755.16 3_MWD+IFR2+MS+Sag (4) 4,767.79 85.16 1.94 3,776.63 977.16 -1,340.723,716.44 6,010,411.83 550,341.86 6.26 819.10 3_MWD+IFR2+MS+Sag (4) 4,831.29 85.55 4.01 3,781.78 1,040.36 -1,337.443,721.59 6,010,475.05 550,344.71 3.31 882.27 3_MWD+IFR2+MS+Sag (4) 4,894.64 84.88 3.99 3,787.06 1,103.34 -1,333.033,726.87 6,010,538.05 550,348.67 1.06 945.34 3_MWD+IFR2+MS+Sag (4) 4,958.06 84.37 4.43 3,793.00 1,166.31 -1,328.403,732.81 6,010,601.04 550,352.87 1.06 1,008.43 3_MWD+IFR2+MS+Sag (4) 5,021.50 84.05 4.32 3,799.40 1,229.24 -1,323.583,739.21 6,010,664.00 550,357.25 0.53 1,071.50 3_MWD+IFR2+MS+Sag (4) 5,085.41 84.26 2.84 3,805.91 1,292.69 -1,319.613,745.72 6,010,727.47 550,360.78 2.33 1,135.00 3_MWD+IFR2+MS+Sag (4) 5,148.97 83.95 3.45 3,812.44 1,355.82 -1,316.143,752.25 6,010,790.61 550,363.81 1.07 1,198.11 3_MWD+IFR2+MS+Sag (4) 5,212.10 88.53 2.58 3,816.58 1,418.71 -1,312.833,756.39 6,010,853.52 550,366.68 7.38 1,260.97 3_MWD+IFR2+MS+Sag (4) 5,234.71 90.53 3.17 3,816.76 1,441.29 -1,311.703,756.57 6,010,876.10 550,367.66 9.22 1,283.54 3_MWD+IFR2+MS+Sag (4) 5,287.70 90.45 2.94 3,816.31 1,494.20 -1,308.873,756.12 6,010,929.03 550,370.12 0.46 1,336.43 3_MWD+IFR2+MS+Sag (5) 5,351.13 89.40 1.74 3,816.39 1,557.58 -1,306.283,756.20 6,010,992.42 550,372.27 2.51 1,399.69 3_MWD+IFR2+MS+Sag (5) 5,414.70 87.66 1.44 3,818.02 1,621.10 -1,304.523,757.83 6,011,055.94 550,373.59 2.78 1,463.00 3_MWD+IFR2+MS+Sag (5) 5,478.71 88.23 1.14 3,820.32 1,685.05 -1,303.083,760.13 6,011,119.90 550,374.59 1.01 1,526.71 3_MWD+IFR2+MS+Sag (5) 5,542.31 89.71 2.37 3,821.46 1,748.61 -1,301.133,761.27 6,011,183.46 550,376.10 3.03 1,590.08 3_MWD+IFR2+MS+Sag (5) 6/8/2020 5:33:11PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 5,605.80 89.77 3.63 3,821.75 1,812.01 -1,297.813,761.56 6,011,246.88 550,378.98 1.99 1,653.44 3_MWD+IFR2+MS+Sag (5) 5,669.61 90.57 3.88 3,821.56 1,875.68 -1,293.633,761.37 6,011,310.57 550,382.72 1.31 1,717.18 3_MWD+IFR2+MS+Sag (5) 5,733.18 91.19 1.97 3,820.59 1,939.16 -1,290.393,760.40 6,011,374.06 550,385.52 3.16 1,780.62 3_MWD+IFR2+MS+Sag (5) 5,796.98 90.82 2.00 3,819.47 2,002.91 -1,288.183,759.28 6,011,437.82 550,387.29 0.58 1,844.21 3_MWD+IFR2+MS+Sag (5) 5,860.64 90.14 1.86 3,818.93 2,066.53 -1,286.043,758.74 6,011,501.45 550,388.99 1.09 1,907.66 3_MWD+IFR2+MS+Sag (5) 5,924.04 90.51 1.81 3,818.57 2,129.90 -1,284.013,758.38 6,011,564.82 550,390.58 0.59 1,970.85 3_MWD+IFR2+MS+Sag (5) 5,988.06 90.39 1.22 3,818.07 2,193.89 -1,282.313,757.88 6,011,628.82 550,391.83 0.94 2,034.63 3_MWD+IFR2+MS+Sag (5) 6,052.27 90.45 359.73 3,817.60 2,258.10 -1,281.783,757.41 6,011,693.02 550,391.92 2.32 2,098.48 3_MWD+IFR2+MS+Sag (5) 6,115.77 89.95 359.60 3,817.38 2,321.59 -1,282.153,757.19 6,011,756.51 550,391.10 0.81 2,161.53 3_MWD+IFR2+MS+Sag (5) 6,178.80 89.64 0.86 3,817.60 2,384.62 -1,281.903,757.41 6,011,819.53 550,390.92 2.06 2,224.18 3_MWD+IFR2+MS+Sag (5) 6,242.73 90.63 2.85 3,817.45 2,448.52 -1,279.833,757.26 6,011,883.43 550,392.55 3.48 2,287.89 3_MWD+IFR2+MS+Sag (5) 6,306.50 90.57 4.89 3,816.79 2,512.13 -1,275.533,756.60 6,011,947.07 550,396.41 3.20 2,351.59 3_MWD+IFR2+MS+Sag (5) 6,369.94 90.32 4.91 3,816.29 2,575.34 -1,270.113,756.10 6,012,010.31 550,401.39 0.40 2,415.00 3_MWD+IFR2+MS+Sag (5) 6,433.14 89.89 5.15 3,816.18 2,638.30 -1,264.573,755.99 6,012,073.29 550,406.49 0.78 2,478.18 3_MWD+IFR2+MS+Sag (5) 6,496.32 89.77 4.56 3,816.36 2,701.25 -1,259.223,756.17 6,012,136.27 550,411.40 0.95 2,541.34 3_MWD+IFR2+MS+Sag (5) 6,560.22 88.59 4.70 3,817.28 2,764.93 -1,254.063,757.09 6,012,199.99 550,416.12 1.86 2,605.19 3_MWD+IFR2+MS+Sag (5) 6,623.80 88.78 4.81 3,818.74 2,828.28 -1,248.793,758.55 6,012,263.36 550,420.95 0.35 2,668.73 3_MWD+IFR2+MS+Sag (5) 6,684.94 88.66 4.72 3,820.10 2,889.19 -1,243.713,759.91 6,012,324.30 550,425.60 0.25 2,729.83 3_MWD+IFR2+MS+Sag (5) 6,750.74 87.91 5.03 3,822.07 2,954.72 -1,238.133,761.88 6,012,389.86 550,430.74 1.23 2,795.57 3_MWD+IFR2+MS+Sag (5) 6,814.12 87.85 5.73 3,824.42 3,017.78 -1,232.193,764.23 6,012,452.95 550,436.24 1.11 2,858.89 3_MWD+IFR2+MS+Sag (5) 6,877.92 89.84 7.33 3,825.70 3,081.15 -1,224.933,765.51 6,012,516.37 550,443.05 4.00 2,922.67 3_MWD+IFR2+MS+Sag (5) 6,941.27 90.57 7.78 3,825.48 3,143.95 -1,216.603,765.29 6,012,579.21 550,450.94 1.35 2,986.01 3_MWD+IFR2+MS+Sag (5) 7,004.97 90.26 6.97 3,825.02 3,207.12 -1,208.433,764.83 6,012,642.43 550,458.68 1.36 3,049.70 3_MWD+IFR2+MS+Sag (5) 7,068.83 90.32 6.34 3,824.69 3,270.55 -1,201.033,764.50 6,012,705.91 550,465.64 0.99 3,113.56 3_MWD+IFR2+MS+Sag (5) 7,132.54 90.57 5.72 3,824.20 3,333.90 -1,194.333,764.01 6,012,769.30 550,471.90 1.05 3,177.27 3_MWD+IFR2+MS+Sag (5) 7,195.63 89.27 5.87 3,824.29 3,396.67 -1,187.963,764.10 6,012,832.10 550,477.83 2.07 3,240.35 3_MWD+IFR2+MS+Sag (5) 7,257.84 89.21 5.54 3,825.11 3,458.56 -1,181.783,764.92 6,012,894.03 550,483.58 0.54 3,302.55 3_MWD+IFR2+MS+Sag (5) 7,322.46 89.15 5.23 3,826.04 3,522.89 -1,175.723,765.85 6,012,958.40 550,489.20 0.49 3,367.15 3_MWD+IFR2+MS+Sag (5) 7,386.52 88.84 5.33 3,827.16 3,586.67 -1,169.823,766.97 6,013,022.21 550,494.65 0.51 3,431.19 3_MWD+IFR2+MS+Sag (5) 7,450.42 88.97 5.11 3,828.38 3,650.29 -1,164.013,768.19 6,013,085.86 550,500.02 0.40 3,495.06 3_MWD+IFR2+MS+Sag (5) 7,513.79 88.84 4.97 3,829.59 3,713.41 -1,158.443,769.40 6,013,149.01 550,505.15 0.30 3,558.40 3_MWD+IFR2+MS+Sag (5) 7,577.60 88.97 5.28 3,830.81 3,776.95 -1,152.753,770.62 6,013,212.58 550,510.41 0.53 3,622.18 3_MWD+IFR2+MS+Sag (5) 7,640.82 89.22 5.58 3,831.81 3,839.88 -1,146.763,771.62 6,013,275.55 550,515.95 0.62 3,685.38 3_MWD+IFR2+MS+Sag (5) 7,704.41 89.27 5.90 3,832.65 3,903.14 -1,140.403,772.46 6,013,338.85 550,521.87 0.51 3,748.96 3_MWD+IFR2+MS+Sag (5) 7,768.20 89.15 6.72 3,833.53 3,966.54 -1,133.393,773.34 6,013,402.29 550,528.44 1.30 3,812.74 3_MWD+IFR2+MS+Sag (5) 7,831.75 88.84 7.25 3,834.64 4,029.61 -1,125.673,774.45 6,013,465.40 550,535.73 0.97 3,876.28 3_MWD+IFR2+MS+Sag (5) 7,895.34 88.91 6.72 3,835.89 4,092.71 -1,117.943,775.70 6,013,528.55 550,543.03 0.84 3,939.85 3_MWD+IFR2+MS+Sag (5) 7,959.12 88.10 6.35 3,837.55 4,156.06 -1,110.683,777.36 6,013,591.94 550,549.84 1.40 4,003.61 3_MWD+IFR2+MS+Sag (5) 8,022.59 87.73 5.51 3,839.86 4,219.15 -1,104.133,779.67 6,013,655.06 550,555.96 1.45 4,067.03 3_MWD+IFR2+MS+Sag (5) 8,085.96 85.56 5.06 3,843.57 4,282.13 -1,098.303,783.38 6,013,718.08 550,561.35 3.50 4,130.28 3_MWD+IFR2+MS+Sag (5) 6/8/2020 5:33:11PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,149.61 83.71 5.21 3,849.52 4,345.25 -1,092.633,789.33 6,013,781.23 550,566.58 2.92 4,193.63 3_MWD+IFR2+MS+Sag (5) 8,213.37 84.45 5.97 3,856.10 4,408.37 -1,086.453,795.91 6,013,844.38 550,572.32 1.66 4,257.04 3_MWD+IFR2+MS+Sag (5) 8,277.18 83.70 6.56 3,862.69 4,471.45 -1,079.523,802.50 6,013,907.51 550,578.81 1.49 4,320.51 3_MWD+IFR2+MS+Sag (5) 8,340.79 84.02 7.60 3,869.49 4,534.22 -1,071.733,809.30 6,013,970.32 550,586.17 1.70 4,383.75 3_MWD+IFR2+MS+Sag (5) 8,404.46 83.71 8.41 3,876.29 4,596.90 -1,062.913,816.10 6,014,033.06 550,594.55 1.36 4,447.03 3_MWD+IFR2+MS+Sag (5) 8,468.17 84.01 8.83 3,883.11 4,659.53 -1,053.423,822.92 6,014,095.75 550,603.61 0.81 4,510.33 3_MWD+IFR2+MS+Sag (5) 8,531.96 85.08 8.85 3,889.17 4,722.28 -1,043.663,828.98 6,014,158.56 550,612.93 1.68 4,573.78 3_MWD+IFR2+MS+Sag (5) 8,595.55 87.05 7.66 3,893.54 4,785.06 -1,034.553,833.35 6,014,221.39 550,621.60 3.62 4,637.18 3_MWD+IFR2+MS+Sag (5) 8,659.41 89.90 6.22 3,895.24 4,848.42 -1,026.843,835.05 6,014,284.80 550,628.87 5.00 4,701.01 3_MWD+IFR2+MS+Sag (5) 8,722.74 92.62 5.35 3,893.84 4,911.41 -1,020.463,833.65 6,014,347.82 550,634.82 4.51 4,764.31 3_MWD+IFR2+MS+Sag (5) 8,780.00 93.05 5.31 3,891.01 4,968.35 -1,015.153,830.82 6,014,404.79 550,639.73 0.75 4,821.49 3_MWD+IFR2+MS+Sag (6) 8,850.86 89.76 6.19 3,889.27 5,038.82 -1,008.053,829.08 6,014,475.30 550,646.34 4.81 4,892.31 3_MWD+IFR2+MS+Sag (6) 8,914.52 88.96 7.52 3,889.98 5,102.02 -1,000.453,829.79 6,014,538.55 550,653.50 2.44 4,955.97 3_MWD+IFR2+MS+Sag (6) 8,978.08 89.03 8.64 3,891.10 5,164.94 -991.523,830.91 6,014,601.52 550,661.99 1.77 5,019.49 3_MWD+IFR2+MS+Sag (6) 9,041.28 89.09 9.08 3,892.14 5,227.37 -981.793,831.95 6,014,664.02 550,671.29 0.70 5,082.63 3_MWD+IFR2+MS+Sag (6) 9,104.83 88.28 9.45 3,893.59 5,290.08 -971.563,833.40 6,014,726.79 550,681.09 1.40 5,146.09 3_MWD+IFR2+MS+Sag (6) 9,168.22 87.98 8.80 3,895.66 5,352.63 -961.513,835.47 6,014,789.40 550,690.70 1.13 5,209.38 3_MWD+IFR2+MS+Sag (6) 9,232.03 88.23 10.20 3,897.77 5,415.53 -950.993,837.58 6,014,852.37 550,700.79 2.23 5,273.06 3_MWD+IFR2+MS+Sag (6) 9,296.01 89.09 9.89 3,899.27 5,478.51 -939.833,839.08 6,014,915.42 550,711.51 1.43 5,336.90 3_MWD+IFR2+MS+Sag (6) 9,340.00 90.28 9.26 3,899.51 5,521.89 -932.513,839.32 6,014,958.84 550,718.52 3.06 5,380.83 3_MWD+IFR2+MS+Sag (7) 9,359.42 88.53 9.58 3,899.71 5,541.04 -929.333,839.52 6,014,978.01 550,721.57 9.17 5,400.22 3_MWD+IFR2+MS+Sag (7) 9,423.02 88.35 7.86 3,901.44 5,603.88 -919.703,841.25 6,015,040.91 550,730.77 2.72 5,463.75 3_MWD+IFR2+MS+Sag (7) 9,486.14 88.16 8.01 3,903.37 5,666.37 -910.993,843.18 6,015,103.45 550,739.05 0.38 5,526.82 3_MWD+IFR2+MS+Sag (7) 9,549.50 90.08 8.00 3,904.34 5,729.10 -902.163,844.15 6,015,166.24 550,747.43 3.03 5,590.15 3_MWD+IFR2+MS+Sag (7) 9,612.63 90.63 6.45 3,903.95 5,791.73 -894.223,843.76 6,015,228.91 550,754.94 2.61 5,653.27 3_MWD+IFR2+MS+Sag (7) 9,676.39 90.94 5.55 3,903.07 5,855.13 -887.563,842.88 6,015,292.35 550,761.16 1.49 5,717.02 3_MWD+IFR2+MS+Sag (7) 9,739.74 90.20 5.60 3,902.44 5,918.18 -881.413,842.25 6,015,355.43 550,766.88 1.17 5,780.36 3_MWD+IFR2+MS+Sag (7) 9,803.36 91.50 5.63 3,901.50 5,981.48 -875.183,841.31 6,015,418.78 550,772.66 2.04 5,843.96 3_MWD+IFR2+MS+Sag (7) 9,867.29 91.68 4.19 3,899.73 6,045.15 -869.713,839.54 6,015,482.48 550,777.69 2.27 5,907.84 3_MWD+IFR2+MS+Sag (7) 9,930.80 92.61 4.47 3,897.35 6,108.44 -864.923,837.16 6,015,545.78 550,782.04 1.53 5,971.26 3_MWD+IFR2+MS+Sag (7) 9,995.02 92.24 3.99 3,894.63 6,172.42 -860.193,834.44 6,015,609.80 550,786.33 0.94 6,035.37 3_MWD+IFR2+MS+Sag (7) 10,058.23 91.87 4.49 3,892.36 6,235.42 -855.523,832.17 6,015,672.82 550,790.56 0.98 6,098.49 3_MWD+IFR2+MS+Sag (7) 10,122.49 90.82 4.93 3,890.86 6,299.45 -850.243,830.67 6,015,736.87 550,795.39 1.77 6,162.70 3_MWD+IFR2+MS+Sag (7) 10,185.24 90.76 6.07 3,889.99 6,361.90 -844.233,829.80 6,015,799.36 550,800.97 1.82 6,225.43 3_MWD+IFR2+MS+Sag (7) 10,249.54 89.89 7.09 3,889.63 6,425.77 -836.863,829.44 6,015,863.28 550,807.90 2.08 6,289.73 3_MWD+IFR2+MS+Sag (7) 10,313.26 90.33 8.12 3,889.50 6,488.93 -828.433,829.31 6,015,926.49 550,815.89 1.76 6,353.44 3_MWD+IFR2+MS+Sag (7) 10,376.97 88.53 7.96 3,890.14 6,552.01 -819.523,829.95 6,015,989.62 550,824.36 2.84 6,417.12 3_MWD+IFR2+MS+Sag (7) 10,440.27 88.97 7.41 3,891.52 6,614.73 -811.063,831.33 6,016,052.38 550,832.39 1.11 6,480.39 3_MWD+IFR2+MS+Sag (7) 10,504.91 89.21 6.98 3,892.55 6,678.85 -802.963,832.36 6,016,116.56 550,840.04 0.76 6,545.02 3_MWD+IFR2+MS+Sag (7) 10,568.88 88.84 5.96 3,893.63 6,742.40 -795.753,833.44 6,016,180.15 550,846.81 1.70 6,608.98 3_MWD+IFR2+MS+Sag (7) 6/8/2020 5:33:11PM COMPASS 5000.15 Build 91E Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 10,632.51 89.03 5.71 3,894.82 6,805.69 -789.293,834.63 6,016,243.48 550,852.83 0.49 6,672.59 3_MWD+IFR2+MS+Sag (7) 10,696.18 89.15 5.54 3,895.83 6,869.05 -783.053,835.64 6,016,306.87 550,858.64 0.33 6,736.25 3_MWD+IFR2+MS+Sag (7) 10,758.14 89.15 5.59 3,896.75 6,930.71 -777.043,836.56 6,016,368.56 550,864.21 0.08 6,798.19 3_MWD+IFR2+MS+Sag (7) 10,821.31 89.02 4.83 3,897.76 6,993.61 -771.303,837.57 6,016,431.50 550,869.51 1.22 6,861.34 3_MWD+IFR2+MS+Sag (7) 10,886.15 89.21 4.78 3,898.76 7,058.21 -765.873,838.57 6,016,496.13 550,874.50 0.30 6,926.14 3_MWD+IFR2+MS+Sag (7) 10,950.14 89.27 4.64 3,899.61 7,121.98 -760.623,839.42 6,016,559.93 550,879.31 0.24 6,990.09 3_MWD+IFR2+MS+Sag (7) 11,013.35 89.52 4.46 3,900.27 7,184.99 -755.603,840.08 6,016,622.96 550,883.88 0.49 7,053.26 3_MWD+IFR2+MS+Sag (7) 11,077.03 88.84 6.00 3,901.18 7,248.39 -749.803,840.99 6,016,686.40 550,889.25 2.64 7,116.92 3_MWD+IFR2+MS+Sag (7) 11,140.48 89.09 6.88 3,902.33 7,311.43 -742.683,842.14 6,016,749.48 550,895.93 1.44 7,180.36 3_MWD+IFR2+MS+Sag (7) 11,204.20 88.22 6.69 3,903.83 7,374.69 -735.163,843.64 6,016,812.78 550,903.01 1.40 7,244.06 3_MWD+IFR2+MS+Sag (7) 11,267.80 88.47 6.56 3,905.66 7,437.84 -727.823,845.47 6,016,875.97 550,909.91 0.44 7,307.63 3_MWD+IFR2+MS+Sag (7) 11,330.81 88.53 6.04 3,907.31 7,500.44 -720.913,847.12 6,016,938.62 550,916.39 0.83 7,370.62 3_MWD+IFR2+MS+Sag (7) 11,394.46 88.72 5.74 3,908.84 7,563.74 -714.383,848.65 6,017,001.95 550,922.48 0.56 7,434.25 3_MWD+IFR2+MS+Sag (7) 11,458.15 88.28 4.33 3,910.51 7,627.16 -708.793,850.32 6,017,065.41 550,927.62 2.32 7,497.89 3_MWD+IFR2+MS+Sag (7) 11,522.50 87.11 0.21 3,913.10 7,691.39 -706.253,852.91 6,017,129.65 550,929.73 6.65 7,562.00 3_MWD+IFR2+MS+Sag (7) 11,586.11 88.60 359.78 3,915.48 7,754.96 -706.253,855.29 6,017,193.20 550,929.28 2.44 7,625.16 3_MWD+IFR2+MS+Sag (7) 11,649.84 88.59 1.91 3,917.04 7,818.66 -705.313,856.85 6,017,256.90 550,929.78 3.34 7,688.55 3_MWD+IFR2+MS+Sag (7) 11,712.36 88.72 5.11 3,918.51 7,881.03 -701.493,858.32 6,017,319.30 550,933.17 5.12 7,750.96 3_MWD+IFR2+MS+Sag (7) 11,775.96 88.29 7.90 3,920.17 7,944.20 -694.293,859.98 6,017,382.50 550,939.93 4.44 7,814.54 3_MWD+IFR2+MS+Sag (7) 11,838.66 89.28 8.85 3,921.50 8,006.21 -685.163,861.31 6,017,444.58 550,948.63 2.19 7,877.19 3_MWD+IFR2+MS+Sag (7) 11,903.02 89.65 8.69 3,922.10 8,069.82 -675.343,861.91 6,017,508.24 550,958.00 0.63 7,941.49 3_MWD+IFR2+MS+Sag (7) 11,967.04 89.40 6.67 3,922.63 8,133.26 -666.793,862.44 6,017,571.73 550,966.12 3.18 8,005.49 3_MWD+IFR2+MS+Sag (7) 12,031.03 88.53 5.02 3,923.78 8,196.90 -660.273,863.59 6,017,635.41 550,972.19 2.91 8,069.47 3_MWD+IFR2+MS+Sag (7) 12,093.19 88.22 4.19 3,925.55 8,258.84 -655.283,865.36 6,017,697.38 550,976.75 1.42 8,131.57 3_MWD+IFR2+MS+Sag (7) 12,156.42 88.29 4.66 3,927.47 8,321.85 -650.413,867.28 6,017,760.41 550,981.19 0.75 8,194.73 3_MWD+IFR2+MS+Sag (7) 12,221.38 88.60 6.28 3,929.24 8,386.49 -644.223,869.05 6,017,825.09 550,986.93 2.54 8,259.65 3_MWD+IFR2+MS+Sag (7) 12,284.67 89.83 6.20 3,930.10 8,449.39 -637.343,869.91 6,017,888.03 550,993.37 1.95 8,322.93 3_MWD+IFR2+MS+Sag (7) 12,348.45 89.40 6.23 3,930.53 8,512.80 -630.443,870.34 6,017,951.48 550,999.84 0.68 8,386.71 3_MWD+IFR2+MS+Sag (7) 12,412.05 89.58 6.79 3,931.10 8,575.98 -623.223,870.91 6,018,014.71 551,006.61 0.92 8,450.31 3_MWD+IFR2+MS+Sag (7) 12,475.17 89.71 7.47 3,931.49 8,638.61 -615.393,871.30 6,018,077.38 551,014.01 1.10 8,513.42 3_MWD+IFR2+MS+Sag (7) 12,538.67 89.71 7.68 3,931.81 8,701.56 -607.023,871.62 6,018,140.38 551,021.94 0.33 8,576.91 3_MWD+IFR2+MS+Sag (7) 12,602.65 88.71 6.12 3,932.69 8,765.07 -599.333,872.50 6,018,203.93 551,029.18 2.90 8,640.88 3_MWD+IFR2+MS+Sag (7) 12,665.97 88.97 7.98 3,933.97 8,827.89 -591.563,873.78 6,018,266.81 551,036.52 2.97 8,704.18 3_MWD+IFR2+MS+Sag (7) 12,729.15 88.10 7.26 3,935.59 8,890.49 -583.193,875.40 6,018,329.46 551,044.46 1.79 8,767.33 3_MWD+IFR2+MS+Sag (7) 12,793.00 89.03 7.07 3,937.19 8,953.82 -575.233,877.00 6,018,392.83 551,051.98 1.49 8,831.15 3_MWD+IFR2+MS+Sag (7) 12,856.65 88.59 8.40 3,938.51 9,016.88 -566.663,878.32 6,018,455.94 551,060.11 2.20 8,894.77 3_MWD+IFR2+MS+Sag (7) 12,920.23 89.03 10.16 3,939.83 9,079.61 -556.413,879.64 6,018,518.74 551,069.92 2.85 8,958.26 3_MWD+IFR2+MS+Sag (7) 12,983.88 87.85 13.29 3,941.56 9,141.90 -543.493,881.37 6,018,581.11 551,082.42 5.25 9,021.61 3_MWD+IFR2+MS+Sag (7) 13,046.62 87.17 14.39 3,944.29 9,202.76 -528.493,884.10 6,018,642.07 551,096.98 2.06 9,083.78 3_MWD+IFR2+MS+Sag (7) 13,110.45 87.85 15.62 3,947.06 9,264.36 -511.983,886.87 6,018,703.77 551,113.07 2.20 9,146.84 3_MWD+IFR2+MS+Sag (7) 6/8/2020 5:33:11PM COMPASS 5000.15 Build 91E Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 13,174.14 89.09 15.88 3,948.76 9,325.63 -494.703,888.57 6,018,765.15 551,129.92 1.99 9,209.68 3_MWD+IFR2+MS+Sag (7) 13,237.79 88.90 15.92 3,949.88 9,386.84 -477.273,889.69 6,018,826.47 551,146.93 0.31 9,272.47 3_MWD+IFR2+MS+Sag (7) 13,301.53 90.21 15.94 3,950.38 9,448.13 -459.773,890.19 6,018,887.88 551,164.00 2.06 9,335.34 3_MWD+IFR2+MS+Sag (7) 13,365.08 89.89 15.14 3,950.32 9,509.35 -442.753,890.13 6,018,949.21 551,180.60 1.36 9,398.10 3_MWD+IFR2+MS+Sag (7) 13,428.54 90.14 14.09 3,950.30 9,570.76 -426.743,890.11 6,019,010.72 551,196.18 1.70 9,460.93 3_MWD+IFR2+MS+Sag (7) 13,491.95 90.02 13.50 3,950.21 9,632.34 -411.623,890.02 6,019,072.40 551,210.87 0.95 9,523.82 3_MWD+IFR2+MS+Sag (7) 13,555.21 89.21 12.89 3,950.64 9,693.93 -397.183,890.45 6,019,134.08 551,224.88 1.60 9,586.65 3_MWD+IFR2+MS+Sag (7) 13,618.70 87.11 12.89 3,952.68 9,755.78 -383.023,892.49 6,019,196.03 551,238.61 3.31 9,649.71 3_MWD+IFR2+MS+Sag (7) 13,681.64 88.66 12.28 3,955.00 9,817.16 -369.323,894.81 6,019,257.50 551,251.88 2.65 9,712.25 3_MWD+IFR2+MS+Sag (7) 13,745.74 88.72 12.30 3,956.47 9,879.78 -355.683,896.28 6,019,320.20 551,265.09 0.10 9,776.01 3_MWD+IFR2+MS+Sag (7) 13,809.60 88.66 12.31 3,957.93 9,942.16 -342.073,897.74 6,019,382.66 551,278.26 0.10 9,839.52 3_MWD+IFR2+MS+Sag (7) 13,873.09 88.59 12.20 3,959.45 10,004.18 -328.603,899.26 6,019,444.77 551,291.30 0.21 9,902.67 3_MWD+IFR2+MS+Sag (7) 13,937.09 88.41 10.75 3,961.13 10,066.88 -315.873,900.94 6,019,507.55 551,303.59 2.28 9,966.41 3_MWD+IFR2+MS+Sag (7) 14,000.33 89.15 10.61 3,962.47 10,129.01 -304.153,902.28 6,019,569.76 551,314.88 1.19 10,029.47 3_MWD+IFR2+MS+Sag (7) 14,063.78 90.95 9.91 3,962.42 10,191.44 -292.853,902.23 6,019,632.26 551,325.75 3.04 10,092.78 3_MWD+IFR2+MS+Sag (7) 14,127.76 91.25 10.02 3,961.19 10,254.44 -281.783,901.00 6,019,695.33 551,336.38 0.50 10,156.63 3_MWD+IFR2+MS+Sag (7) 14,195.54 91.25 9.71 3,959.71 10,321.21 -270.173,899.52 6,019,762.16 551,347.52 0.46 10,224.28 3_MWD+IFR2+MS+Sag (7) 14,265.00 91.25 9.71 3,958.19 10,389.65 -258.463,898.00 6,019,830.69 551,358.76 0.00 10,293.61 PROJECTED to TD Approved By:Checked By:Date: 6/8/2020 5:33:11PM COMPASS 5000.15 Build 91E Page 8 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.07.09 12:33:19 -08'00' Monty M Myers 08 June, 2020 Milne Point M Pt I Pad MPU I-36PB1 500292367770 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36PB1 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36PB1 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: MPU I-36, Slot I-26 usft usft 0.00 0.00 6,009,444.08 551,689.19 33.60Wellhead Elevation:33.60 usft0.50 70° 26' 11.572 N 149° 34' 42.850 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-36PB1 Model NameMagnetics IFR 6/1/2020 15.96 80.87 57,384.00000000 Phase:Version: Audit Notes: Design MPU I-36PB1 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:26.59 6.500.000.0026.59 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 6/3/2020 Survey Date 3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing100.00 951.00 MPU I-36PB1 E-Line gyro (1) (MPU I-36P 05/18/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa1,015.18 1,142.57 MPU I-36PB1 MWD+IFR2+MS+Sag (1) (05/18/2020 3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing1,207.00 1,588.00 MPU I-36PB1 E-Line gyro (2) (MPU I-36P 05/18/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa1,651.17 5,234.71 MPU I-36PB1 MWD+IFR2+MS+Sag (2) (05/26/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa5,287.70 10,232.45 MPU I-36PB1 MWD+IFR2+MS+Sag (3) (06/01/2020 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 26.59 0.00 0.00 26.59 0.00 0.00-33.60 6,009,444.08 551,689.19 0.00 0.00 UNDEFINED 100.00 0.09 93.95 100.00 0.00 0.0639.81 6,009,444.08 551,689.25 0.12 0.00 3_Gyro-GC_Csg (1) 134.00 0.30 210.44 134.00 -0.08 0.0473.81 6,009,444.00 551,689.23 1.03 -0.08 3_Gyro-GC_Csg (1) 198.00 0.32 263.84 198.00 -0.25 -0.22137.81 6,009,443.83 551,688.97 0.44 -0.27 3_Gyro-GC_Csg (1) 258.00 0.27 341.36 258.00 -0.13 -0.44197.81 6,009,443.95 551,688.76 0.62 -0.18 3_Gyro-GC_Csg (1) 320.00 1.34 342.11 319.99 0.70 -0.70259.80 6,009,444.77 551,688.48 1.73 0.61 3_Gyro-GC_Csg (1) 383.00 2.49 332.26 382.96 2.61 -1.57322.77 6,009,446.68 551,687.60 1.89 2.42 3_Gyro-GC_Csg (1) 446.00 2.91 327.90 445.89 5.18 -3.05385.70 6,009,449.23 551,686.10 0.74 4.80 3_Gyro-GC_Csg (1) 509.00 2.58 323.81 508.81 7.68 -4.74448.62 6,009,451.72 551,684.40 0.61 7.09 3_Gyro-GC_Csg (1) 571.00 2.24 307.24 570.76 9.53 -6.53510.57 6,009,453.57 551,682.59 1.24 8.73 3_Gyro-GC_Csg (1) 6/8/2020 5:28:54PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36PB1 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36PB1 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 633.00 2.01 296.37 632.72 10.75 -8.47572.53 6,009,454.77 551,680.65 0.75 9.72 3_Gyro-GC_Csg (1) 697.00 2.06 281.35 696.68 11.48 -10.60636.49 6,009,455.48 551,678.51 0.83 10.20 3_Gyro-GC_Csg (1) 761.00 3.44 261.49 760.60 11.42 -13.63700.41 6,009,455.40 551,675.48 2.59 9.80 3_Gyro-GC_Csg (1) 824.00 4.70 248.27 823.44 10.18 -17.90763.25 6,009,454.14 551,671.22 2.48 8.09 3_Gyro-GC_Csg (1) 888.00 6.29 240.57 887.15 7.49 -23.39826.96 6,009,451.41 551,665.75 2.73 4.79 3_Gyro-GC_Csg (1) 951.00 7.59 232.77 949.69 3.28 -29.71889.50 6,009,447.15 551,659.47 2.54 -0.11 3_Gyro-GC_Csg (1) 1,015.18 9.12 234.54 1,013.18 -2.24 -37.22952.99 6,009,441.58 551,651.99 2.42 -6.44 3_MWD+IFR2+MS+Sag (2) 1,078.44 10.56 232.07 1,075.51 -8.71 -45.881,015.32 6,009,435.05 551,643.38 2.37 -13.85 3_MWD+IFR2+MS+Sag (2) 1,142.57 11.51 238.22 1,138.46 -15.69 -55.951,078.27 6,009,428.00 551,633.35 2.36 -21.93 3_MWD+IFR2+MS+Sag (2) 1,207.00 12.45 235.14 1,201.48 -23.05 -67.121,141.29 6,009,420.57 551,622.24 1.76 -30.50 3_Gyro-GC_Csg (3) 1,270.00 13.12 234.68 1,262.92 -31.06 -78.521,202.73 6,009,412.47 551,610.89 1.08 -39.75 3_Gyro-GC_Csg (3) 1,333.00 14.49 240.80 1,324.10 -39.04 -91.241,263.91 6,009,404.41 551,598.23 3.18 -49.12 3_Gyro-GC_Csg (3) 1,396.00 16.11 244.83 1,384.87 -46.61 -106.031,324.68 6,009,396.74 551,583.49 3.07 -58.31 3_Gyro-GC_Csg (3) 1,462.00 18.22 243.34 1,447.93 -55.13 -123.541,387.74 6,009,388.10 551,566.04 3.27 -68.76 3_Gyro-GC_Csg (3) 1,526.00 18.84 242.71 1,508.61 -64.36 -141.671,448.42 6,009,378.75 551,547.98 1.02 -79.98 3_Gyro-GC_Csg (3) 1,588.00 21.89 241.04 1,566.73 -74.55 -160.681,506.54 6,009,368.43 551,529.04 5.01 -92.26 3_Gyro-GC_Csg (3) 1,651.17 23.72 240.78 1,624.96 -86.45 -182.081,564.77 6,009,356.37 551,507.74 2.90 -106.51 3_MWD+IFR2+MS+Sag (4) 1,715.52 24.91 242.99 1,683.60 -98.93 -205.451,623.41 6,009,343.74 551,484.45 2.33 -121.55 3_MWD+IFR2+MS+Sag (4) 1,778.74 27.19 244.68 1,740.39 -111.15 -230.371,680.20 6,009,331.34 551,459.62 3.79 -136.52 3_MWD+IFR2+MS+Sag (4) 1,841.94 31.04 245.69 1,795.60 -124.04 -258.281,735.41 6,009,318.26 551,431.80 6.14 -152.48 3_MWD+IFR2+MS+Sag (4) 1,905.18 33.50 246.09 1,849.07 -137.83 -289.101,788.88 6,009,304.26 551,401.08 3.90 -169.67 3_MWD+IFR2+MS+Sag (4) 1,968.43 33.50 247.53 1,901.81 -151.58 -321.191,841.62 6,009,290.30 551,369.09 1.26 -186.96 3_MWD+IFR2+MS+Sag (4) 2,032.25 34.34 247.87 1,954.77 -165.09 -354.141,894.58 6,009,276.56 551,336.24 1.35 -204.12 3_MWD+IFR2+MS+Sag (4) 2,095.61 34.07 248.38 2,007.17 -178.36 -387.191,946.98 6,009,263.06 551,303.28 0.62 -221.04 3_MWD+IFR2+MS+Sag (4) 2,159.62 34.29 248.80 2,060.12 -191.49 -420.671,999.93 6,009,249.70 551,269.90 0.50 -237.88 3_MWD+IFR2+MS+Sag (4) 2,223.28 34.49 247.89 2,112.66 -204.75 -454.092,052.47 6,009,236.20 551,236.58 0.87 -254.84 3_MWD+IFR2+MS+Sag (4) 2,287.07 34.39 247.55 2,165.27 -218.43 -487.472,105.08 6,009,222.30 551,203.29 0.34 -272.21 3_MWD+IFR2+MS+Sag (4) 2,351.14 33.70 248.66 2,218.35 -231.81 -520.752,158.16 6,009,208.69 551,170.11 1.45 -289.27 3_MWD+IFR2+MS+Sag (4) 2,414.81 34.22 252.54 2,271.17 -243.61 -554.282,210.98 6,009,196.66 551,136.66 3.50 -304.79 3_MWD+IFR2+MS+Sag (4) 2,478.53 34.17 256.81 2,323.88 -253.07 -588.802,263.69 6,009,186.96 551,102.21 3.77 -318.10 3_MWD+IFR2+MS+Sag (4) 2,541.98 34.10 258.92 2,376.40 -260.56 -623.612,316.21 6,009,179.23 551,067.46 1.87 -329.47 3_MWD+IFR2+MS+Sag (4) 2,605.73 31.91 262.13 2,429.87 -266.30 -657.842,369.68 6,009,173.26 551,033.27 4.39 -339.06 3_MWD+IFR2+MS+Sag (4) 2,669.90 30.49 265.38 2,484.76 -269.93 -690.872,424.57 6,009,169.39 551,000.27 3.43 -346.41 3_MWD+IFR2+MS+Sag (4) 2,732.94 29.82 269.83 2,539.27 -271.27 -722.492,479.08 6,009,167.84 550,968.67 3.70 -351.31 3_MWD+IFR2+MS+Sag (4) 2,796.95 30.07 274.78 2,594.75 -269.98 -754.392,534.56 6,009,168.91 550,936.76 3.88 -353.64 3_MWD+IFR2+MS+Sag (4) 2,860.80 30.66 281.62 2,649.85 -265.36 -786.292,589.66 6,009,173.30 550,904.84 5.49 -352.67 3_MWD+IFR2+MS+Sag (4) 2,924.72 32.36 288.10 2,704.36 -256.76 -818.522,644.17 6,009,181.68 550,872.55 5.93 -347.77 3_MWD+IFR2+MS+Sag (4) 2,988.20 33.08 292.34 2,757.78 -244.90 -850.702,697.59 6,009,193.32 550,840.29 3.78 -339.63 3_MWD+IFR2+MS+Sag (4) 3,051.62 33.27 296.39 2,810.87 -230.59 -882.292,750.68 6,009,207.41 550,808.60 3.51 -328.98 3_MWD+IFR2+MS+Sag (4) 3,115.64 33.39 302.54 2,864.37 -213.30 -912.882,804.18 6,009,224.48 550,777.89 5.28 -315.27 3_MWD+IFR2+MS+Sag (4) 6/8/2020 5:28:54PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36PB1 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36PB1 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,179.02 33.93 307.50 2,917.14 -193.15 -941.632,856.95 6,009,244.43 550,749.02 4.42 -298.50 3_MWD+IFR2+MS+Sag (4) 3,242.65 35.63 311.29 2,969.40 -170.10 -969.652,909.21 6,009,267.28 550,720.84 4.32 -278.78 3_MWD+IFR2+MS+Sag (4) 3,305.89 37.03 314.38 3,020.35 -144.63 -997.102,960.16 6,009,292.56 550,693.21 3.64 -256.57 3_MWD+IFR2+MS+Sag (4) 3,369.25 39.05 319.23 3,070.26 -116.16 -1,023.783,010.07 6,009,320.84 550,666.34 5.69 -231.31 3_MWD+IFR2+MS+Sag (4) 3,432.86 39.96 321.90 3,119.35 -84.90 -1,049.473,059.16 6,009,351.91 550,640.44 3.03 -203.16 3_MWD+IFR2+MS+Sag (4) 3,496.26 40.65 323.91 3,167.70 -52.19 -1,074.203,107.51 6,009,384.45 550,615.48 2.32 -173.46 3_MWD+IFR2+MS+Sag (4) 3,559.87 41.10 325.94 3,215.80 -18.13 -1,098.113,155.61 6,009,418.34 550,591.34 2.20 -142.32 3_MWD+IFR2+MS+Sag (4) 3,623.46 43.42 328.60 3,262.86 17.85 -1,121.213,202.67 6,009,454.16 550,567.99 4.61 -109.19 3_MWD+IFR2+MS+Sag (4) 3,687.36 45.93 330.60 3,308.30 56.60 -1,143.933,248.11 6,009,492.75 550,545.01 4.50 -73.26 3_MWD+IFR2+MS+Sag (4) 3,751.01 48.36 333.01 3,351.59 97.72 -1,165.953,291.40 6,009,533.71 550,522.70 4.72 -34.89 3_MWD+IFR2+MS+Sag (4) 3,814.61 50.62 334.54 3,392.90 141.10 -1,187.313,332.71 6,009,576.94 550,501.05 4.00 5.79 3_MWD+IFR2+MS+Sag (4) 3,878.33 53.08 337.37 3,432.27 186.86 -1,207.703,372.08 6,009,622.55 550,480.34 5.21 48.94 3_MWD+IFR2+MS+Sag (4) 3,942.08 53.73 340.20 3,470.27 234.57 -1,226.213,410.08 6,009,670.12 550,461.50 3.71 94.25 3_MWD+IFR2+MS+Sag (4) 4,005.70 55.71 342.91 3,507.02 283.83 -1,242.633,446.83 6,009,719.26 550,444.75 4.67 141.34 3_MWD+IFR2+MS+Sag (4) 4,068.79 58.34 345.42 3,541.36 334.74 -1,257.053,481.17 6,009,770.07 550,429.97 5.34 190.29 3_MWD+IFR2+MS+Sag (4) 4,132.17 58.87 347.23 3,574.38 387.31 -1,269.843,514.19 6,009,822.54 550,416.82 2.58 241.07 3_MWD+IFR2+MS+Sag (4) 4,196.17 59.31 347.63 3,607.26 440.90 -1,281.793,547.07 6,009,876.04 550,404.50 0.87 292.96 3_MWD+IFR2+MS+Sag (4) 4,259.52 60.51 348.41 3,639.02 494.52 -1,293.163,578.83 6,009,929.58 550,392.76 2.17 344.95 3_MWD+IFR2+MS+Sag (4) 4,322.71 66.27 348.87 3,667.31 549.88 -1,304.283,607.12 6,009,984.86 550,381.26 9.14 398.70 3_MWD+IFR2+MS+Sag (4) 4,386.86 70.42 350.37 3,690.98 608.52 -1,315.013,630.79 6,010,043.41 550,370.13 6.82 455.74 3_MWD+IFR2+MS+Sag (4) 4,449.92 72.89 351.55 3,710.82 667.63 -1,324.413,650.63 6,010,102.45 550,360.32 4.30 513.41 3_MWD+IFR2+MS+Sag (4) 4,513.38 74.22 354.14 3,728.79 728.01 -1,331.983,668.60 6,010,162.77 550,352.32 4.44 572.54 3_MWD+IFR2+MS+Sag (4) 4,576.91 76.55 356.26 3,744.82 789.26 -1,337.123,684.63 6,010,223.98 550,346.76 4.89 632.82 3_MWD+IFR2+MS+Sag (4) 4,640.54 78.38 358.01 3,758.63 851.29 -1,340.223,698.44 6,010,285.98 550,343.23 3.93 694.10 3_MWD+IFR2+MS+Sag (4) 4,703.10 81.90 359.52 3,769.35 912.90 -1,341.543,709.16 6,010,347.57 550,341.48 6.11 755.16 3_MWD+IFR2+MS+Sag (4) 4,767.79 85.16 1.94 3,776.63 977.16 -1,340.723,716.44 6,010,411.83 550,341.86 6.26 819.10 3_MWD+IFR2+MS+Sag (4) 4,831.29 85.55 4.01 3,781.78 1,040.36 -1,337.443,721.59 6,010,475.05 550,344.71 3.31 882.27 3_MWD+IFR2+MS+Sag (4) 4,894.64 84.88 3.99 3,787.06 1,103.34 -1,333.033,726.87 6,010,538.05 550,348.67 1.06 945.34 3_MWD+IFR2+MS+Sag (4) 4,958.06 84.37 4.43 3,793.00 1,166.31 -1,328.403,732.81 6,010,601.04 550,352.87 1.06 1,008.43 3_MWD+IFR2+MS+Sag (4) 5,021.50 84.05 4.32 3,799.40 1,229.24 -1,323.583,739.21 6,010,664.00 550,357.25 0.53 1,071.50 3_MWD+IFR2+MS+Sag (4) 5,085.41 84.26 2.84 3,805.91 1,292.69 -1,319.613,745.72 6,010,727.47 550,360.78 2.33 1,135.00 3_MWD+IFR2+MS+Sag (4) 5,148.97 83.95 3.45 3,812.44 1,355.82 -1,316.143,752.25 6,010,790.61 550,363.81 1.07 1,198.11 3_MWD+IFR2+MS+Sag (4) 5,212.10 88.53 2.58 3,816.58 1,418.71 -1,312.833,756.39 6,010,853.52 550,366.68 7.38 1,260.97 3_MWD+IFR2+MS+Sag (4) 5,234.71 90.53 3.17 3,816.76 1,441.29 -1,311.703,756.57 6,010,876.10 550,367.66 9.22 1,283.54 3_MWD+IFR2+MS+Sag (4) 5,287.70 90.45 2.94 3,816.31 1,494.20 -1,308.873,756.12 6,010,929.03 550,370.12 0.46 1,336.43 3_MWD+IFR2+MS+Sag (5) 5,351.13 89.40 1.74 3,816.39 1,557.58 -1,306.283,756.20 6,010,992.42 550,372.27 2.51 1,399.69 3_MWD+IFR2+MS+Sag (5) 5,414.70 87.66 1.44 3,818.02 1,621.10 -1,304.523,757.83 6,011,055.94 550,373.59 2.78 1,463.00 3_MWD+IFR2+MS+Sag (5) 5,478.71 88.23 1.14 3,820.32 1,685.05 -1,303.083,760.13 6,011,119.90 550,374.59 1.01 1,526.71 3_MWD+IFR2+MS+Sag (5) 5,542.31 89.71 2.37 3,821.46 1,748.61 -1,301.133,761.27 6,011,183.46 550,376.10 3.03 1,590.08 3_MWD+IFR2+MS+Sag (5) 5,605.80 89.77 3.63 3,821.75 1,812.01 -1,297.813,761.56 6,011,246.88 550,378.98 1.99 1,653.44 3_MWD+IFR2+MS+Sag (5) 6/8/2020 5:28:54PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36PB1 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36PB1 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 5,669.61 90.57 3.88 3,821.56 1,875.68 -1,293.633,761.37 6,011,310.57 550,382.72 1.31 1,717.18 3_MWD+IFR2+MS+Sag (5) 5,733.18 91.19 1.97 3,820.59 1,939.16 -1,290.393,760.40 6,011,374.06 550,385.52 3.16 1,780.62 3_MWD+IFR2+MS+Sag (5) 5,796.98 90.82 2.00 3,819.47 2,002.91 -1,288.183,759.28 6,011,437.82 550,387.29 0.58 1,844.21 3_MWD+IFR2+MS+Sag (5) 5,860.64 90.14 1.86 3,818.93 2,066.53 -1,286.043,758.74 6,011,501.45 550,388.99 1.09 1,907.66 3_MWD+IFR2+MS+Sag (5) 5,924.04 90.51 1.81 3,818.57 2,129.90 -1,284.013,758.38 6,011,564.82 550,390.58 0.59 1,970.85 3_MWD+IFR2+MS+Sag (5) 5,988.06 90.39 1.22 3,818.07 2,193.89 -1,282.313,757.88 6,011,628.82 550,391.83 0.94 2,034.63 3_MWD+IFR2+MS+Sag (5) 6,052.27 90.45 359.73 3,817.60 2,258.10 -1,281.783,757.41 6,011,693.02 550,391.92 2.32 2,098.48 3_MWD+IFR2+MS+Sag (5) 6,115.77 89.95 359.60 3,817.38 2,321.59 -1,282.153,757.19 6,011,756.51 550,391.10 0.81 2,161.53 3_MWD+IFR2+MS+Sag (5) 6,178.80 89.64 0.86 3,817.60 2,384.62 -1,281.903,757.41 6,011,819.53 550,390.92 2.06 2,224.18 3_MWD+IFR2+MS+Sag (5) 6,242.73 90.63 2.85 3,817.45 2,448.52 -1,279.833,757.26 6,011,883.43 550,392.55 3.48 2,287.89 3_MWD+IFR2+MS+Sag (5) 6,306.50 90.57 4.89 3,816.79 2,512.13 -1,275.533,756.60 6,011,947.07 550,396.41 3.20 2,351.59 3_MWD+IFR2+MS+Sag (5) 6,369.94 90.32 4.91 3,816.29 2,575.34 -1,270.113,756.10 6,012,010.31 550,401.39 0.40 2,415.00 3_MWD+IFR2+MS+Sag (5) 6,433.14 89.89 5.15 3,816.18 2,638.30 -1,264.573,755.99 6,012,073.29 550,406.49 0.78 2,478.18 3_MWD+IFR2+MS+Sag (5) 6,496.32 89.77 4.56 3,816.36 2,701.25 -1,259.223,756.17 6,012,136.27 550,411.40 0.95 2,541.34 3_MWD+IFR2+MS+Sag (5) 6,560.22 88.59 4.70 3,817.28 2,764.93 -1,254.063,757.09 6,012,199.99 550,416.12 1.86 2,605.19 3_MWD+IFR2+MS+Sag (5) 6,623.80 88.78 4.81 3,818.74 2,828.28 -1,248.793,758.55 6,012,263.36 550,420.95 0.35 2,668.73 3_MWD+IFR2+MS+Sag (5) 6,684.94 88.66 4.72 3,820.10 2,889.19 -1,243.713,759.91 6,012,324.30 550,425.60 0.25 2,729.83 3_MWD+IFR2+MS+Sag (5) 6,750.74 87.91 5.03 3,822.07 2,954.72 -1,238.133,761.88 6,012,389.86 550,430.74 1.23 2,795.57 3_MWD+IFR2+MS+Sag (5) 6,814.12 87.85 5.73 3,824.42 3,017.78 -1,232.193,764.23 6,012,452.95 550,436.24 1.11 2,858.89 3_MWD+IFR2+MS+Sag (5) 6,877.92 89.84 7.33 3,825.70 3,081.15 -1,224.933,765.51 6,012,516.37 550,443.05 4.00 2,922.67 3_MWD+IFR2+MS+Sag (5) 6,941.27 90.57 7.78 3,825.48 3,143.95 -1,216.603,765.29 6,012,579.21 550,450.94 1.35 2,986.01 3_MWD+IFR2+MS+Sag (5) 7,004.97 90.26 6.97 3,825.02 3,207.12 -1,208.433,764.83 6,012,642.43 550,458.68 1.36 3,049.70 3_MWD+IFR2+MS+Sag (5) 7,068.83 90.32 6.34 3,824.69 3,270.55 -1,201.033,764.50 6,012,705.91 550,465.64 0.99 3,113.56 3_MWD+IFR2+MS+Sag (5) 7,132.54 90.57 5.72 3,824.20 3,333.90 -1,194.333,764.01 6,012,769.30 550,471.90 1.05 3,177.27 3_MWD+IFR2+MS+Sag (5) 7,195.63 89.27 5.87 3,824.29 3,396.67 -1,187.963,764.10 6,012,832.10 550,477.83 2.07 3,240.35 3_MWD+IFR2+MS+Sag (5) 7,257.84 89.21 5.54 3,825.11 3,458.56 -1,181.783,764.92 6,012,894.03 550,483.58 0.54 3,302.55 3_MWD+IFR2+MS+Sag (5) 7,322.46 89.15 5.23 3,826.04 3,522.89 -1,175.723,765.85 6,012,958.40 550,489.20 0.49 3,367.15 3_MWD+IFR2+MS+Sag (5) 7,386.52 88.84 5.33 3,827.16 3,586.67 -1,169.823,766.97 6,013,022.21 550,494.65 0.51 3,431.19 3_MWD+IFR2+MS+Sag (5) 7,450.42 88.97 5.11 3,828.38 3,650.29 -1,164.013,768.19 6,013,085.86 550,500.02 0.40 3,495.06 3_MWD+IFR2+MS+Sag (5) 7,513.79 88.84 4.97 3,829.59 3,713.41 -1,158.443,769.40 6,013,149.01 550,505.15 0.30 3,558.40 3_MWD+IFR2+MS+Sag (5) 7,577.60 88.97 5.28 3,830.81 3,776.95 -1,152.753,770.62 6,013,212.58 550,510.41 0.53 3,622.18 3_MWD+IFR2+MS+Sag (5) 7,640.82 89.22 5.58 3,831.81 3,839.88 -1,146.763,771.62 6,013,275.55 550,515.95 0.62 3,685.38 3_MWD+IFR2+MS+Sag (5) 7,704.41 89.27 5.90 3,832.65 3,903.14 -1,140.403,772.46 6,013,338.85 550,521.87 0.51 3,748.96 3_MWD+IFR2+MS+Sag (5) 7,768.20 89.15 6.72 3,833.53 3,966.54 -1,133.393,773.34 6,013,402.29 550,528.44 1.30 3,812.74 3_MWD+IFR2+MS+Sag (5) 7,831.75 88.84 7.25 3,834.64 4,029.61 -1,125.673,774.45 6,013,465.40 550,535.73 0.97 3,876.28 3_MWD+IFR2+MS+Sag (5) 7,895.34 88.91 6.72 3,835.89 4,092.71 -1,117.943,775.70 6,013,528.55 550,543.03 0.84 3,939.85 3_MWD+IFR2+MS+Sag (5) 7,959.12 88.10 6.35 3,837.55 4,156.06 -1,110.683,777.36 6,013,591.94 550,549.84 1.40 4,003.61 3_MWD+IFR2+MS+Sag (5) 8,022.59 87.73 5.51 3,839.86 4,219.15 -1,104.133,779.67 6,013,655.06 550,555.96 1.45 4,067.03 3_MWD+IFR2+MS+Sag (5) 8,085.96 85.56 5.06 3,843.57 4,282.13 -1,098.303,783.38 6,013,718.08 550,561.35 3.50 4,130.28 3_MWD+IFR2+MS+Sag (5) 8,149.61 83.71 5.21 3,849.52 4,345.25 -1,092.633,789.33 6,013,781.23 550,566.58 2.92 4,193.63 3_MWD+IFR2+MS+Sag (5) 6/8/2020 5:28:54PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36PB1 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36PB1 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,213.37 84.45 5.97 3,856.10 4,408.37 -1,086.453,795.91 6,013,844.38 550,572.32 1.66 4,257.04 3_MWD+IFR2+MS+Sag (5) 8,277.18 83.70 6.56 3,862.69 4,471.45 -1,079.523,802.50 6,013,907.51 550,578.81 1.49 4,320.51 3_MWD+IFR2+MS+Sag (5) 8,340.79 84.02 7.60 3,869.49 4,534.22 -1,071.733,809.30 6,013,970.32 550,586.17 1.70 4,383.75 3_MWD+IFR2+MS+Sag (5) 8,404.46 83.71 8.41 3,876.29 4,596.90 -1,062.913,816.10 6,014,033.06 550,594.55 1.36 4,447.03 3_MWD+IFR2+MS+Sag (5) 8,468.17 84.01 8.83 3,883.11 4,659.53 -1,053.423,822.92 6,014,095.75 550,603.61 0.81 4,510.33 3_MWD+IFR2+MS+Sag (5) 8,531.96 85.08 8.85 3,889.17 4,722.28 -1,043.663,828.98 6,014,158.56 550,612.93 1.68 4,573.78 3_MWD+IFR2+MS+Sag (5) 8,595.55 87.05 7.66 3,893.54 4,785.06 -1,034.553,833.35 6,014,221.39 550,621.60 3.62 4,637.18 3_MWD+IFR2+MS+Sag (5) 8,659.41 89.90 6.22 3,895.24 4,848.42 -1,026.843,835.05 6,014,284.80 550,628.87 5.00 4,701.01 3_MWD+IFR2+MS+Sag (5) 8,722.74 92.62 5.35 3,893.84 4,911.41 -1,020.463,833.65 6,014,347.82 550,634.82 4.51 4,764.31 3_MWD+IFR2+MS+Sag (5) 8,786.57 93.10 5.30 3,890.66 4,974.88 -1,014.543,830.47 6,014,411.33 550,640.29 0.76 4,828.05 3_MWD+IFR2+MS+Sag (5) 8,850.05 92.24 5.53 3,887.70 5,038.01 -1,008.563,827.51 6,014,474.49 550,645.84 1.40 4,891.45 3_MWD+IFR2+MS+Sag (5) 8,913.79 90.38 5.46 3,886.24 5,101.44 -1,002.463,826.05 6,014,537.95 550,651.50 2.92 4,955.16 3_MWD+IFR2+MS+Sag (5) 8,977.35 88.22 5.51 3,887.02 5,164.70 -996.383,826.83 6,014,601.25 550,657.14 3.40 5,018.70 3_MWD+IFR2+MS+Sag (5) 9,040.85 88.47 6.32 3,888.85 5,227.83 -989.843,828.66 6,014,664.42 550,663.24 1.33 5,082.17 3_MWD+IFR2+MS+Sag (5) 9,104.36 88.16 6.69 3,890.72 5,290.90 -982.653,830.53 6,014,727.53 550,669.99 0.76 5,145.65 3_MWD+IFR2+MS+Sag (5) 9,168.04 88.04 6.65 3,892.83 5,354.12 -975.263,832.64 6,014,790.79 550,676.95 0.20 5,209.30 3_MWD+IFR2+MS+Sag (5) 9,231.76 87.54 6.78 3,895.29 5,417.35 -967.813,835.10 6,014,854.07 550,683.95 0.81 5,272.97 3_MWD+IFR2+MS+Sag (5) 9,295.48 87.67 7.43 3,897.95 5,480.53 -959.943,837.76 6,014,917.29 550,691.39 1.04 5,336.63 3_MWD+IFR2+MS+Sag (5) 9,359.29 86.86 8.65 3,901.00 5,543.64 -951.023,840.81 6,014,980.46 550,699.86 2.29 5,400.34 3_MWD+IFR2+MS+Sag (5) 9,422.48 87.17 8.37 3,904.29 5,606.05 -941.693,844.10 6,015,042.92 550,708.77 0.66 5,463.41 3_MWD+IFR2+MS+Sag (5) 9,485.88 86.80 9.34 3,907.62 5,668.60 -931.943,847.43 6,015,105.54 550,718.08 1.64 5,526.67 3_MWD+IFR2+MS+Sag (5) 9,549.18 88.60 8.41 3,910.16 5,731.09 -922.183,849.97 6,015,168.09 550,727.40 3.20 5,589.86 3_MWD+IFR2+MS+Sag (5) 9,612.26 90.64 6.49 3,910.58 5,793.63 -914.003,850.39 6,015,230.68 550,735.14 4.44 5,652.92 3_MWD+IFR2+MS+Sag (5) 9,675.83 91.62 5.53 3,909.33 5,856.84 -907.353,849.14 6,015,293.92 550,741.36 2.16 5,716.48 3_MWD+IFR2+MS+Sag (5) 9,738.63 93.29 5.29 3,906.64 5,919.30 -901.443,846.45 6,015,356.42 550,746.84 2.69 5,779.21 3_MWD+IFR2+MS+Sag (5) 9,803.06 92.85 4.90 3,903.19 5,983.38 -895.723,843.00 6,015,420.53 550,752.11 0.91 5,843.52 3_MWD+IFR2+MS+Sag (5) 9,866.38 90.26 4.16 3,901.47 6,046.48 -890.723,841.28 6,015,483.65 550,756.67 4.25 5,906.78 3_MWD+IFR2+MS+Sag (5) 9,930.44 88.77 4.43 3,902.01 6,110.35 -885.933,841.82 6,015,547.55 550,761.03 2.36 5,970.79 3_MWD+IFR2+MS+Sag (5) 9,993.76 90.76 6.44 3,902.27 6,173.38 -879.933,842.08 6,015,610.62 550,766.59 4.47 6,034.09 3_MWD+IFR2+MS+Sag (5) 10,057.57 92.80 8.01 3,900.29 6,236.65 -871.913,840.10 6,015,673.93 550,774.17 4.03 6,097.86 3_MWD+IFR2+MS+Sag (5) 10,122.16 93.79 8.74 3,896.58 6,300.44 -862.523,836.39 6,015,737.78 550,783.11 1.90 6,162.30 3_MWD+IFR2+MS+Sag (5) 10,186.41 92.73 9.04 3,892.92 6,363.82 -852.603,832.73 6,015,801.22 550,792.59 1.71 6,226.39 3_MWD+IFR2+MS+Sag (5) 10,232.45 91.24 9.04 3,891.33 6,409.26 -845.373,831.14 6,015,846.70 550,799.50 3.24 6,272.36 3_MWD+IFR2+MS+Sag (5) 10,300.00 91.24 9.04 3,889.87 6,475.95 -834.763,829.68 6,015,913.46 550,809.65 0.00 6,339.83 PROJECTED to TD Approved By:Checked By:Date: 6/8/2020 5:28:54PM COMPASS 5000.15 Build 91E Page 6 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.07.09 12:33:19 -08'00' Monty M Myers 08 June, 2020 Milne Point M Pt I Pad MPU I-36PB2 500292367771 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36PB2 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36PB2 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: MPU I-36, Slot I-26 usft usft 0.00 0.00 6,009,444.08 551,689.19 33.60Wellhead Elevation:33.60 usft0.50 70° 26' 11.572 N 149° 34' 42.850 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-36PB2 Model NameMagnetics IFR 6/1/2020 15.96 80.87 57,384.00000000 Phase:Version: Audit Notes: Design MPU I-36PB2 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:8,722.74 6.500.000.0026.59 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 6/5/2020 Survey Date 3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing100.00 951.00 MPU I-36PB1 E-Line gyro (1) (MPU I-36P 05/18/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa1,015.18 1,142.57 MPU I-36PB1 MWD+IFR2+MS+Sag (1) (05/18/2020 3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing1,207.00 1,588.00 MPU I-36PB1 E-Line gyro (2) (MPU I-36P 05/18/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa1,651.17 5,234.71 MPU I-36PB1 MWD+IFR2+MS+Sag (2) (05/26/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa5,287.70 8,722.74 MPU I-36PB1 MWD+IFR2+MS+Sag (3) (06/01/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa8,780.00 10,093.49 MPU I-36PB2 MWD+IFR2+MS+Sag (4) (06/03/2020 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 26.59 0.00 0.00 26.59 0.00 0.00-33.60 6,009,444.08 551,689.19 0.00 0.00 UNDEFINED 100.00 0.09 93.95 100.00 0.00 0.0639.81 6,009,444.08 551,689.25 0.12 0.00 3_Gyro-GC_Csg (1) 134.00 0.30 210.44 134.00 -0.08 0.0473.81 6,009,444.00 551,689.23 1.03 -0.08 3_Gyro-GC_Csg (1) 198.00 0.32 263.84 198.00 -0.25 -0.22137.81 6,009,443.83 551,688.97 0.44 -0.27 3_Gyro-GC_Csg (1) 258.00 0.27 341.36 258.00 -0.13 -0.44197.81 6,009,443.95 551,688.76 0.62 -0.18 3_Gyro-GC_Csg (1) 320.00 1.34 342.11 319.99 0.70 -0.70259.80 6,009,444.77 551,688.48 1.73 0.61 3_Gyro-GC_Csg (1) 383.00 2.49 332.26 382.96 2.61 -1.57322.77 6,009,446.68 551,687.60 1.89 2.42 3_Gyro-GC_Csg (1) 446.00 2.91 327.90 445.89 5.18 -3.05385.70 6,009,449.23 551,686.10 0.74 4.80 3_Gyro-GC_Csg (1) 509.00 2.58 323.81 508.81 7.68 -4.74448.62 6,009,451.72 551,684.40 0.61 7.09 3_Gyro-GC_Csg (1) 571.00 2.24 307.24 570.76 9.53 -6.53510.57 6,009,453.57 551,682.59 1.24 8.73 3_Gyro-GC_Csg (1) 6/8/2020 5:32:27PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36PB2 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36PB2 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 633.00 2.01 296.37 632.72 10.75 -8.47572.53 6,009,454.77 551,680.65 0.75 9.72 3_Gyro-GC_Csg (1) 697.00 2.06 281.35 696.68 11.48 -10.60636.49 6,009,455.48 551,678.51 0.83 10.20 3_Gyro-GC_Csg (1) 761.00 3.44 261.49 760.60 11.42 -13.63700.41 6,009,455.40 551,675.48 2.59 9.80 3_Gyro-GC_Csg (1) 824.00 4.70 248.27 823.44 10.18 -17.90763.25 6,009,454.14 551,671.22 2.48 8.09 3_Gyro-GC_Csg (1) 888.00 6.29 240.57 887.15 7.49 -23.39826.96 6,009,451.41 551,665.75 2.73 4.79 3_Gyro-GC_Csg (1) 951.00 7.59 232.77 949.69 3.28 -29.71889.50 6,009,447.15 551,659.47 2.54 -0.11 3_Gyro-GC_Csg (1) 1,015.18 9.12 234.54 1,013.18 -2.24 -37.22952.99 6,009,441.58 551,651.99 2.42 -6.44 3_MWD+IFR2+MS+Sag (2) 1,078.44 10.56 232.07 1,075.51 -8.71 -45.881,015.32 6,009,435.05 551,643.38 2.37 -13.85 3_MWD+IFR2+MS+Sag (2) 1,142.57 11.51 238.22 1,138.46 -15.69 -55.951,078.27 6,009,428.00 551,633.35 2.36 -21.93 3_MWD+IFR2+MS+Sag (2) 1,207.00 12.45 235.14 1,201.48 -23.05 -67.121,141.29 6,009,420.57 551,622.24 1.76 -30.50 3_Gyro-GC_Csg (3) 1,270.00 13.12 234.68 1,262.92 -31.06 -78.521,202.73 6,009,412.47 551,610.89 1.08 -39.75 3_Gyro-GC_Csg (3) 1,333.00 14.49 240.80 1,324.10 -39.04 -91.241,263.91 6,009,404.41 551,598.23 3.18 -49.12 3_Gyro-GC_Csg (3) 1,396.00 16.11 244.83 1,384.87 -46.61 -106.031,324.68 6,009,396.74 551,583.49 3.07 -58.31 3_Gyro-GC_Csg (3) 1,462.00 18.22 243.34 1,447.93 -55.13 -123.541,387.74 6,009,388.10 551,566.04 3.27 -68.76 3_Gyro-GC_Csg (3) 1,526.00 18.84 242.71 1,508.61 -64.36 -141.671,448.42 6,009,378.75 551,547.98 1.02 -79.98 3_Gyro-GC_Csg (3) 1,588.00 21.89 241.04 1,566.73 -74.55 -160.681,506.54 6,009,368.43 551,529.04 5.01 -92.26 3_Gyro-GC_Csg (3) 1,651.17 23.72 240.78 1,624.96 -86.45 -182.081,564.77 6,009,356.37 551,507.74 2.90 -106.51 3_MWD+IFR2+MS+Sag (4) 1,715.52 24.91 242.99 1,683.60 -98.93 -205.451,623.41 6,009,343.74 551,484.45 2.33 -121.55 3_MWD+IFR2+MS+Sag (4) 1,778.74 27.19 244.68 1,740.39 -111.15 -230.371,680.20 6,009,331.34 551,459.62 3.79 -136.52 3_MWD+IFR2+MS+Sag (4) 1,841.94 31.04 245.69 1,795.60 -124.04 -258.281,735.41 6,009,318.26 551,431.80 6.14 -152.48 3_MWD+IFR2+MS+Sag (4) 1,905.18 33.50 246.09 1,849.07 -137.83 -289.101,788.88 6,009,304.26 551,401.08 3.90 -169.67 3_MWD+IFR2+MS+Sag (4) 1,968.43 33.50 247.53 1,901.81 -151.58 -321.191,841.62 6,009,290.30 551,369.09 1.26 -186.96 3_MWD+IFR2+MS+Sag (4) 2,032.25 34.34 247.87 1,954.77 -165.09 -354.141,894.58 6,009,276.56 551,336.24 1.35 -204.12 3_MWD+IFR2+MS+Sag (4) 2,095.61 34.07 248.38 2,007.17 -178.36 -387.191,946.98 6,009,263.06 551,303.28 0.62 -221.04 3_MWD+IFR2+MS+Sag (4) 2,159.62 34.29 248.80 2,060.12 -191.49 -420.671,999.93 6,009,249.70 551,269.90 0.50 -237.88 3_MWD+IFR2+MS+Sag (4) 2,223.28 34.49 247.89 2,112.66 -204.75 -454.092,052.47 6,009,236.20 551,236.58 0.87 -254.84 3_MWD+IFR2+MS+Sag (4) 2,287.07 34.39 247.55 2,165.27 -218.43 -487.472,105.08 6,009,222.30 551,203.29 0.34 -272.21 3_MWD+IFR2+MS+Sag (4) 2,351.14 33.70 248.66 2,218.35 -231.81 -520.752,158.16 6,009,208.69 551,170.11 1.45 -289.27 3_MWD+IFR2+MS+Sag (4) 2,414.81 34.22 252.54 2,271.17 -243.61 -554.282,210.98 6,009,196.66 551,136.66 3.50 -304.79 3_MWD+IFR2+MS+Sag (4) 2,478.53 34.17 256.81 2,323.88 -253.07 -588.802,263.69 6,009,186.96 551,102.21 3.77 -318.10 3_MWD+IFR2+MS+Sag (4) 2,541.98 34.10 258.92 2,376.40 -260.56 -623.612,316.21 6,009,179.23 551,067.46 1.87 -329.47 3_MWD+IFR2+MS+Sag (4) 2,605.73 31.91 262.13 2,429.87 -266.30 -657.842,369.68 6,009,173.26 551,033.27 4.39 -339.06 3_MWD+IFR2+MS+Sag (4) 2,669.90 30.49 265.38 2,484.76 -269.93 -690.872,424.57 6,009,169.39 551,000.27 3.43 -346.41 3_MWD+IFR2+MS+Sag (4) 2,732.94 29.82 269.83 2,539.27 -271.27 -722.492,479.08 6,009,167.84 550,968.67 3.70 -351.31 3_MWD+IFR2+MS+Sag (4) 2,796.95 30.07 274.78 2,594.75 -269.98 -754.392,534.56 6,009,168.91 550,936.76 3.88 -353.64 3_MWD+IFR2+MS+Sag (4) 2,860.80 30.66 281.62 2,649.85 -265.36 -786.292,589.66 6,009,173.30 550,904.84 5.49 -352.67 3_MWD+IFR2+MS+Sag (4) 2,924.72 32.36 288.10 2,704.36 -256.76 -818.522,644.17 6,009,181.68 550,872.55 5.93 -347.77 3_MWD+IFR2+MS+Sag (4) 2,988.20 33.08 292.34 2,757.78 -244.90 -850.702,697.59 6,009,193.32 550,840.29 3.78 -339.63 3_MWD+IFR2+MS+Sag (4) 3,051.62 33.27 296.39 2,810.87 -230.59 -882.292,750.68 6,009,207.41 550,808.60 3.51 -328.98 3_MWD+IFR2+MS+Sag (4) 3,115.64 33.39 302.54 2,864.37 -213.30 -912.882,804.18 6,009,224.48 550,777.89 5.28 -315.27 3_MWD+IFR2+MS+Sag (4) 6/8/2020 5:32:27PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36PB2 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36PB2 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,179.02 33.93 307.50 2,917.14 -193.15 -941.632,856.95 6,009,244.43 550,749.02 4.42 -298.50 3_MWD+IFR2+MS+Sag (4) 3,242.65 35.63 311.29 2,969.40 -170.10 -969.652,909.21 6,009,267.28 550,720.84 4.32 -278.78 3_MWD+IFR2+MS+Sag (4) 3,305.89 37.03 314.38 3,020.35 -144.63 -997.102,960.16 6,009,292.56 550,693.21 3.64 -256.57 3_MWD+IFR2+MS+Sag (4) 3,369.25 39.05 319.23 3,070.26 -116.16 -1,023.783,010.07 6,009,320.84 550,666.34 5.69 -231.31 3_MWD+IFR2+MS+Sag (4) 3,432.86 39.96 321.90 3,119.35 -84.90 -1,049.473,059.16 6,009,351.91 550,640.44 3.03 -203.16 3_MWD+IFR2+MS+Sag (4) 3,496.26 40.65 323.91 3,167.70 -52.19 -1,074.203,107.51 6,009,384.45 550,615.48 2.32 -173.46 3_MWD+IFR2+MS+Sag (4) 3,559.87 41.10 325.94 3,215.80 -18.13 -1,098.113,155.61 6,009,418.34 550,591.34 2.20 -142.32 3_MWD+IFR2+MS+Sag (4) 3,623.46 43.42 328.60 3,262.86 17.85 -1,121.213,202.67 6,009,454.16 550,567.99 4.61 -109.19 3_MWD+IFR2+MS+Sag (4) 3,687.36 45.93 330.60 3,308.30 56.60 -1,143.933,248.11 6,009,492.75 550,545.01 4.50 -73.26 3_MWD+IFR2+MS+Sag (4) 3,751.01 48.36 333.01 3,351.59 97.72 -1,165.953,291.40 6,009,533.71 550,522.70 4.72 -34.89 3_MWD+IFR2+MS+Sag (4) 3,814.61 50.62 334.54 3,392.90 141.10 -1,187.313,332.71 6,009,576.94 550,501.05 4.00 5.79 3_MWD+IFR2+MS+Sag (4) 3,878.33 53.08 337.37 3,432.27 186.86 -1,207.703,372.08 6,009,622.55 550,480.34 5.21 48.94 3_MWD+IFR2+MS+Sag (4) 3,942.08 53.73 340.20 3,470.27 234.57 -1,226.213,410.08 6,009,670.12 550,461.50 3.71 94.25 3_MWD+IFR2+MS+Sag (4) 4,005.70 55.71 342.91 3,507.02 283.83 -1,242.633,446.83 6,009,719.26 550,444.75 4.67 141.34 3_MWD+IFR2+MS+Sag (4) 4,068.79 58.34 345.42 3,541.36 334.74 -1,257.053,481.17 6,009,770.07 550,429.97 5.34 190.29 3_MWD+IFR2+MS+Sag (4) 4,132.17 58.87 347.23 3,574.38 387.31 -1,269.843,514.19 6,009,822.54 550,416.82 2.58 241.07 3_MWD+IFR2+MS+Sag (4) 4,196.17 59.31 347.63 3,607.26 440.90 -1,281.793,547.07 6,009,876.04 550,404.50 0.87 292.96 3_MWD+IFR2+MS+Sag (4) 4,259.52 60.51 348.41 3,639.02 494.52 -1,293.163,578.83 6,009,929.58 550,392.76 2.17 344.95 3_MWD+IFR2+MS+Sag (4) 4,322.71 66.27 348.87 3,667.31 549.88 -1,304.283,607.12 6,009,984.86 550,381.26 9.14 398.70 3_MWD+IFR2+MS+Sag (4) 4,386.86 70.42 350.37 3,690.98 608.52 -1,315.013,630.79 6,010,043.41 550,370.13 6.82 455.74 3_MWD+IFR2+MS+Sag (4) 4,449.92 72.89 351.55 3,710.82 667.63 -1,324.413,650.63 6,010,102.45 550,360.32 4.30 513.41 3_MWD+IFR2+MS+Sag (4) 4,513.38 74.22 354.14 3,728.79 728.01 -1,331.983,668.60 6,010,162.77 550,352.32 4.44 572.54 3_MWD+IFR2+MS+Sag (4) 4,576.91 76.55 356.26 3,744.82 789.26 -1,337.123,684.63 6,010,223.98 550,346.76 4.89 632.82 3_MWD+IFR2+MS+Sag (4) 4,640.54 78.38 358.01 3,758.63 851.29 -1,340.223,698.44 6,010,285.98 550,343.23 3.93 694.10 3_MWD+IFR2+MS+Sag (4) 4,703.10 81.90 359.52 3,769.35 912.90 -1,341.543,709.16 6,010,347.57 550,341.48 6.11 755.16 3_MWD+IFR2+MS+Sag (4) 4,767.79 85.16 1.94 3,776.63 977.16 -1,340.723,716.44 6,010,411.83 550,341.86 6.26 819.10 3_MWD+IFR2+MS+Sag (4) 4,831.29 85.55 4.01 3,781.78 1,040.36 -1,337.443,721.59 6,010,475.05 550,344.71 3.31 882.27 3_MWD+IFR2+MS+Sag (4) 4,894.64 84.88 3.99 3,787.06 1,103.34 -1,333.033,726.87 6,010,538.05 550,348.67 1.06 945.34 3_MWD+IFR2+MS+Sag (4) 4,958.06 84.37 4.43 3,793.00 1,166.31 -1,328.403,732.81 6,010,601.04 550,352.87 1.06 1,008.43 3_MWD+IFR2+MS+Sag (4) 5,021.50 84.05 4.32 3,799.40 1,229.24 -1,323.583,739.21 6,010,664.00 550,357.25 0.53 1,071.50 3_MWD+IFR2+MS+Sag (4) 5,085.41 84.26 2.84 3,805.91 1,292.69 -1,319.613,745.72 6,010,727.47 550,360.78 2.33 1,135.00 3_MWD+IFR2+MS+Sag (4) 5,148.97 83.95 3.45 3,812.44 1,355.82 -1,316.143,752.25 6,010,790.61 550,363.81 1.07 1,198.11 3_MWD+IFR2+MS+Sag (4) 5,212.10 88.53 2.58 3,816.58 1,418.71 -1,312.833,756.39 6,010,853.52 550,366.68 7.38 1,260.97 3_MWD+IFR2+MS+Sag (4) 5,234.71 90.53 3.17 3,816.76 1,441.29 -1,311.703,756.57 6,010,876.10 550,367.66 9.22 1,283.54 3_MWD+IFR2+MS+Sag (4) 5,287.70 90.45 2.94 3,816.31 1,494.20 -1,308.873,756.12 6,010,929.03 550,370.12 0.46 1,336.43 3_MWD+IFR2+MS+Sag (5) 5,351.13 89.40 1.74 3,816.39 1,557.58 -1,306.283,756.20 6,010,992.42 550,372.27 2.51 1,399.69 3_MWD+IFR2+MS+Sag (5) 5,414.70 87.66 1.44 3,818.02 1,621.10 -1,304.523,757.83 6,011,055.94 550,373.59 2.78 1,463.00 3_MWD+IFR2+MS+Sag (5) 5,478.71 88.23 1.14 3,820.32 1,685.05 -1,303.083,760.13 6,011,119.90 550,374.59 1.01 1,526.71 3_MWD+IFR2+MS+Sag (5) 5,542.31 89.71 2.37 3,821.46 1,748.61 -1,301.133,761.27 6,011,183.46 550,376.10 3.03 1,590.08 3_MWD+IFR2+MS+Sag (5) 5,605.80 89.77 3.63 3,821.75 1,812.01 -1,297.813,761.56 6,011,246.88 550,378.98 1.99 1,653.44 3_MWD+IFR2+MS+Sag (5) 6/8/2020 5:32:27PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36PB2 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36PB2 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 5,669.61 90.57 3.88 3,821.56 1,875.68 -1,293.633,761.37 6,011,310.57 550,382.72 1.31 1,717.18 3_MWD+IFR2+MS+Sag (5) 5,733.18 91.19 1.97 3,820.59 1,939.16 -1,290.393,760.40 6,011,374.06 550,385.52 3.16 1,780.62 3_MWD+IFR2+MS+Sag (5) 5,796.98 90.82 2.00 3,819.47 2,002.91 -1,288.183,759.28 6,011,437.82 550,387.29 0.58 1,844.21 3_MWD+IFR2+MS+Sag (5) 5,860.64 90.14 1.86 3,818.93 2,066.53 -1,286.043,758.74 6,011,501.45 550,388.99 1.09 1,907.66 3_MWD+IFR2+MS+Sag (5) 5,924.04 90.51 1.81 3,818.57 2,129.90 -1,284.013,758.38 6,011,564.82 550,390.58 0.59 1,970.85 3_MWD+IFR2+MS+Sag (5) 5,988.06 90.39 1.22 3,818.07 2,193.89 -1,282.313,757.88 6,011,628.82 550,391.83 0.94 2,034.63 3_MWD+IFR2+MS+Sag (5) 6,052.27 90.45 359.73 3,817.60 2,258.10 -1,281.783,757.41 6,011,693.02 550,391.92 2.32 2,098.48 3_MWD+IFR2+MS+Sag (5) 6,115.77 89.95 359.60 3,817.38 2,321.59 -1,282.153,757.19 6,011,756.51 550,391.10 0.81 2,161.53 3_MWD+IFR2+MS+Sag (5) 6,178.80 89.64 0.86 3,817.60 2,384.62 -1,281.903,757.41 6,011,819.53 550,390.92 2.06 2,224.18 3_MWD+IFR2+MS+Sag (5) 6,242.73 90.63 2.85 3,817.45 2,448.52 -1,279.833,757.26 6,011,883.43 550,392.55 3.48 2,287.89 3_MWD+IFR2+MS+Sag (5) 6,306.50 90.57 4.89 3,816.79 2,512.13 -1,275.533,756.60 6,011,947.07 550,396.41 3.20 2,351.59 3_MWD+IFR2+MS+Sag (5) 6,369.94 90.32 4.91 3,816.29 2,575.34 -1,270.113,756.10 6,012,010.31 550,401.39 0.40 2,415.00 3_MWD+IFR2+MS+Sag (5) 6,433.14 89.89 5.15 3,816.18 2,638.30 -1,264.573,755.99 6,012,073.29 550,406.49 0.78 2,478.18 3_MWD+IFR2+MS+Sag (5) 6,496.32 89.77 4.56 3,816.36 2,701.25 -1,259.223,756.17 6,012,136.27 550,411.40 0.95 2,541.34 3_MWD+IFR2+MS+Sag (5) 6,560.22 88.59 4.70 3,817.28 2,764.93 -1,254.063,757.09 6,012,199.99 550,416.12 1.86 2,605.19 3_MWD+IFR2+MS+Sag (5) 6,623.80 88.78 4.81 3,818.74 2,828.28 -1,248.793,758.55 6,012,263.36 550,420.95 0.35 2,668.73 3_MWD+IFR2+MS+Sag (5) 6,684.94 88.66 4.72 3,820.10 2,889.19 -1,243.713,759.91 6,012,324.30 550,425.60 0.25 2,729.83 3_MWD+IFR2+MS+Sag (5) 6,750.74 87.91 5.03 3,822.07 2,954.72 -1,238.133,761.88 6,012,389.86 550,430.74 1.23 2,795.57 3_MWD+IFR2+MS+Sag (5) 6,814.12 87.85 5.73 3,824.42 3,017.78 -1,232.193,764.23 6,012,452.95 550,436.24 1.11 2,858.89 3_MWD+IFR2+MS+Sag (5) 6,877.92 89.84 7.33 3,825.70 3,081.15 -1,224.933,765.51 6,012,516.37 550,443.05 4.00 2,922.67 3_MWD+IFR2+MS+Sag (5) 6,941.27 90.57 7.78 3,825.48 3,143.95 -1,216.603,765.29 6,012,579.21 550,450.94 1.35 2,986.01 3_MWD+IFR2+MS+Sag (5) 7,004.97 90.26 6.97 3,825.02 3,207.12 -1,208.433,764.83 6,012,642.43 550,458.68 1.36 3,049.70 3_MWD+IFR2+MS+Sag (5) 7,068.83 90.32 6.34 3,824.69 3,270.55 -1,201.033,764.50 6,012,705.91 550,465.64 0.99 3,113.56 3_MWD+IFR2+MS+Sag (5) 7,132.54 90.57 5.72 3,824.20 3,333.90 -1,194.333,764.01 6,012,769.30 550,471.90 1.05 3,177.27 3_MWD+IFR2+MS+Sag (5) 7,195.63 89.27 5.87 3,824.29 3,396.67 -1,187.963,764.10 6,012,832.10 550,477.83 2.07 3,240.35 3_MWD+IFR2+MS+Sag (5) 7,257.84 89.21 5.54 3,825.11 3,458.56 -1,181.783,764.92 6,012,894.03 550,483.58 0.54 3,302.55 3_MWD+IFR2+MS+Sag (5) 7,322.46 89.15 5.23 3,826.04 3,522.89 -1,175.723,765.85 6,012,958.40 550,489.20 0.49 3,367.15 3_MWD+IFR2+MS+Sag (5) 7,386.52 88.84 5.33 3,827.16 3,586.67 -1,169.823,766.97 6,013,022.21 550,494.65 0.51 3,431.19 3_MWD+IFR2+MS+Sag (5) 7,450.42 88.97 5.11 3,828.38 3,650.29 -1,164.013,768.19 6,013,085.86 550,500.02 0.40 3,495.06 3_MWD+IFR2+MS+Sag (5) 7,513.79 88.84 4.97 3,829.59 3,713.41 -1,158.443,769.40 6,013,149.01 550,505.15 0.30 3,558.40 3_MWD+IFR2+MS+Sag (5) 7,577.60 88.97 5.28 3,830.81 3,776.95 -1,152.753,770.62 6,013,212.58 550,510.41 0.53 3,622.18 3_MWD+IFR2+MS+Sag (5) 7,640.82 89.22 5.58 3,831.81 3,839.88 -1,146.763,771.62 6,013,275.55 550,515.95 0.62 3,685.38 3_MWD+IFR2+MS+Sag (5) 7,704.41 89.27 5.90 3,832.65 3,903.14 -1,140.403,772.46 6,013,338.85 550,521.87 0.51 3,748.96 3_MWD+IFR2+MS+Sag (5) 7,768.20 89.15 6.72 3,833.53 3,966.54 -1,133.393,773.34 6,013,402.29 550,528.44 1.30 3,812.74 3_MWD+IFR2+MS+Sag (5) 7,831.75 88.84 7.25 3,834.64 4,029.61 -1,125.673,774.45 6,013,465.40 550,535.73 0.97 3,876.28 3_MWD+IFR2+MS+Sag (5) 7,895.34 88.91 6.72 3,835.89 4,092.71 -1,117.943,775.70 6,013,528.55 550,543.03 0.84 3,939.85 3_MWD+IFR2+MS+Sag (5) 7,959.12 88.10 6.35 3,837.55 4,156.06 -1,110.683,777.36 6,013,591.94 550,549.84 1.40 4,003.61 3_MWD+IFR2+MS+Sag (5) 8,022.59 87.73 5.51 3,839.86 4,219.15 -1,104.133,779.67 6,013,655.06 550,555.96 1.45 4,067.03 3_MWD+IFR2+MS+Sag (5) 8,085.96 85.56 5.06 3,843.57 4,282.13 -1,098.303,783.38 6,013,718.08 550,561.35 3.50 4,130.28 3_MWD+IFR2+MS+Sag (5) 8,149.61 83.71 5.21 3,849.52 4,345.25 -1,092.633,789.33 6,013,781.23 550,566.58 2.92 4,193.63 3_MWD+IFR2+MS+Sag (5) 6/8/2020 5:32:27PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-36 MPU I-36PB2 Survey Calculation Method:Minimum Curvature MPU I-36 Actual RKB @ 60.19usft Design:MPU I-36PB2 Database:NORTH US + CANADA MD Reference:MPU I-36 Actual RKB @ 60.19usft North Reference: Well MPU I-36 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,213.37 84.45 5.97 3,856.10 4,408.37 -1,086.453,795.91 6,013,844.38 550,572.32 1.66 4,257.04 3_MWD+IFR2+MS+Sag (5) 8,277.18 83.70 6.56 3,862.69 4,471.45 -1,079.523,802.50 6,013,907.51 550,578.81 1.49 4,320.51 3_MWD+IFR2+MS+Sag (5) 8,340.79 84.02 7.60 3,869.49 4,534.22 -1,071.733,809.30 6,013,970.32 550,586.17 1.70 4,383.75 3_MWD+IFR2+MS+Sag (5) 8,404.46 83.71 8.41 3,876.29 4,596.90 -1,062.913,816.10 6,014,033.06 550,594.55 1.36 4,447.03 3_MWD+IFR2+MS+Sag (5) 8,468.17 84.01 8.83 3,883.11 4,659.53 -1,053.423,822.92 6,014,095.75 550,603.61 0.81 4,510.33 3_MWD+IFR2+MS+Sag (5) 8,531.96 85.08 8.85 3,889.17 4,722.28 -1,043.663,828.98 6,014,158.56 550,612.93 1.68 4,573.78 3_MWD+IFR2+MS+Sag (5) 8,595.55 87.05 7.66 3,893.54 4,785.06 -1,034.553,833.35 6,014,221.39 550,621.60 3.62 4,637.18 3_MWD+IFR2+MS+Sag (5) 8,659.41 89.90 6.22 3,895.24 4,848.42 -1,026.843,835.05 6,014,284.80 550,628.87 5.00 4,701.01 3_MWD+IFR2+MS+Sag (5) 8,722.74 92.62 5.35 3,893.84 4,911.41 -1,020.463,833.65 6,014,347.82 550,634.82 4.51 4,764.31 3_MWD+IFR2+MS+Sag (5) 8,780.00 93.05 5.31 3,891.01 4,968.35 -1,015.153,830.82 6,014,404.79 550,639.73 0.75 4,821.49 3_MWD+IFR2+MS+Sag (6) 8,850.86 89.76 6.19 3,889.27 5,038.82 -1,008.053,829.08 6,014,475.30 550,646.34 4.81 4,892.31 3_MWD+IFR2+MS+Sag (6) 8,914.52 88.96 7.52 3,889.98 5,102.02 -1,000.453,829.79 6,014,538.55 550,653.50 2.44 4,955.97 3_MWD+IFR2+MS+Sag (6) 8,978.08 89.03 8.64 3,891.10 5,164.94 -991.523,830.91 6,014,601.52 550,661.99 1.77 5,019.49 3_MWD+IFR2+MS+Sag (6) 9,041.28 89.09 9.08 3,892.14 5,227.37 -981.793,831.95 6,014,664.02 550,671.29 0.70 5,082.63 3_MWD+IFR2+MS+Sag (6) 9,104.83 88.28 9.45 3,893.59 5,290.08 -971.563,833.40 6,014,726.79 550,681.09 1.40 5,146.09 3_MWD+IFR2+MS+Sag (6) 9,168.22 87.98 8.80 3,895.66 5,352.63 -961.513,835.47 6,014,789.40 550,690.70 1.13 5,209.38 3_MWD+IFR2+MS+Sag (6) 9,232.03 88.23 10.20 3,897.77 5,415.53 -950.993,837.58 6,014,852.37 550,700.79 2.23 5,273.06 3_MWD+IFR2+MS+Sag (6) 9,296.01 89.09 9.89 3,899.27 5,478.51 -939.833,839.08 6,014,915.42 550,711.51 1.43 5,336.90 3_MWD+IFR2+MS+Sag (6) 9,359.81 90.82 8.98 3,899.32 5,541.45 -929.373,839.13 6,014,978.42 550,721.53 3.06 5,400.62 3_MWD+IFR2+MS+Sag (6) 9,422.89 90.14 8.25 3,898.79 5,603.81 -919.923,838.60 6,015,040.84 550,730.54 1.58 5,463.65 3_MWD+IFR2+MS+Sag (6) 9,486.10 91.56 6.67 3,897.85 5,666.48 -911.723,837.66 6,015,103.55 550,738.31 3.36 5,526.84 3_MWD+IFR2+MS+Sag (6) 9,549.32 91.19 6.74 3,896.34 5,729.25 -904.343,836.15 6,015,166.37 550,745.26 0.60 5,590.04 3_MWD+IFR2+MS+Sag (6) 9,611.59 92.74 7.00 3,894.20 5,791.03 -896.893,834.01 6,015,228.19 550,752.27 2.52 5,652.27 3_MWD+IFR2+MS+Sag (6) 9,675.97 91.86 7.28 3,891.62 5,854.86 -888.903,831.43 6,015,292.07 550,759.82 1.43 5,716.60 3_MWD+IFR2+MS+Sag (6) 9,739.48 92.99 6.53 3,888.93 5,917.85 -881.273,828.74 6,015,355.11 550,767.01 2.13 5,780.05 3_MWD+IFR2+MS+Sag (6) 9,803.23 92.92 6.87 3,885.64 5,981.08 -873.843,825.45 6,015,418.38 550,774.00 0.54 5,843.71 3_MWD+IFR2+MS+Sag (6) 9,867.16 92.61 7.48 3,882.56 6,044.44 -865.873,822.37 6,015,481.78 550,781.54 1.07 5,907.56 3_MWD+IFR2+MS+Sag (6) 9,930.58 93.29 7.75 3,879.30 6,107.21 -857.473,819.11 6,015,544.61 550,789.50 1.15 5,970.89 3_MWD+IFR2+MS+Sag (6) 9,994.37 92.80 7.30 3,875.91 6,170.36 -849.133,815.72 6,015,607.81 550,797.40 1.04 6,034.57 3_MWD+IFR2+MS+Sag (6) 10,058.09 93.10 5.97 3,872.63 6,233.57 -841.783,812.44 6,015,671.06 550,804.31 2.14 6,098.21 3_MWD+IFR2+MS+Sag (6) 10,093.49 93.66 5.73 3,870.54 6,268.73 -838.183,810.35 6,015,706.24 550,807.67 1.72 6,133.54 3_MWD+IFR2+MS+Sag (6) 10,163.00 93.66 5.73 3,866.10 6,337.75 -831.253,805.91 6,015,775.30 550,814.12 0.00 6,202.91 PROJECTED to TD Approved By:Checked By:Date: 6/8/2020 5:32:27PM COMPASS 5000.15 Build 91E Page 6 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.07.09 12:33:19 -08'00' Monty M Myers TD Shoe Depth: PBTD: No. Jts. Returned Jts. 2 1 3 46 X Yes No X Yes No 50 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated?X Yes No Reciprocated?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): 1.17 Spud Mud Type I/II 450 2.35 Class G 400 1.16 4 1,920.74 Casing 9 5/8 47.0 L-80 TXP BTC Tenaris 1,883.02 1,920.74 37.72 1,938.16 1,935.32 Pup Joint 9 5/8 40.0 L-80 TXP BTC Tenaris 14.58 1,935.32 14.98 1,953.14 1,938.16 ES cementer 10 3/4 L-80 TXP BTC HES 2.84 Pup Joint 9 5/8 40.0 L-80 TXP BTC Tenaris 5,141.08 Casing 9 5/8 47.0 L-80 TXP BTC Tenaris 3,187.94 5,141.08 1,953.14 5,181.30 5,142.53 Baffle Adapter 10 3/4 40.0 L-80 TXP BTC HES 1.45 5,142.53 1.34 5,182.72 5,181.38 Casing 9 5/8 40.0 L-80 TXP BTC Tenaris 38.85 Float Collar 10 3/4 40.0 L-80 BTC Innovex 2 on shoe joint, 1 every joint to 4265', 1 every other joint to 3234', 1 every third joint to 2155', 1 every joint to 1511' (5 before, 10 after ES cementer), 1 every third joint to 160'. Casing 9 5/8 40.0 L-80 TXP BTC Tenaris 79.66 5,262.38 5,182.72 4208.34Water 4 No. Jts. Delivered 130 No. Jts. Run 130 Type of Shoe:Bullnose Casing Crew:Weatherford 12 188 Water ES cementer Closure OK 6208.34 56 ArcticCem Type Class G 270 Tuned Spacer 525 2.94 Stage Collar @ 60 5,264.005,274.00 CEMENTING REPORT Csg Wt. On Slips:115,000 Spud mud 11:30 5/28/2020 1,935 1935 15.8 82 Bump press Returns after opening stage tool Bump Plug? Yes 4.2 9.3 7 121.1/122 368.1/364.8 1300 80 rigFIRST STAGE10Tuned Spacer 60 15.8 9.3 3 10 10.7 275 4 100 690 Csg Wt. On Hook:218,000 Type Float Collar:Conventional No. Hrs to Run:13.5 9 5/8 47.0 L-80 TXP BTC Tenaris BTC Innovex 1.62 5,264.00 5,262.38 11.59 37.72 26.13 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.MP I-36 Date Run 27-May-20 CASING RECORD County State Alaska Supv.S Barber/ C Montague 5,181.00 Floats Held Spud Mud Rotate Csg Recip Csg Ft. Min. PPG9.3 Shoe @ 5264 FC @ Top of Liner #N/A SECOND STAGECasing (Or Liner) Detail Shoe Cut Joint 10 3/4 L-80 FCP (psi): Pump used for disp:X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: 5/28/2020 26 www.wellez.net WellEz Information Management LLC ver_04818br Bump press 100 245 650 2140Bump Plug? 323.77 601 325 276 Rig 22:10 Returns 287.57 239.8 -17 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/02/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-36 (220-047) Halliburton LWD FINAL 14 JUN 2020 MPU I-36 ROP AGR ABG DGR EWR ADR MD/TVD MPU I-36 PB1 ROP AGR ABG DGR EWR ADR MD/TVD MPU I-36 PB2 ROP AGR ABG DGR EWR ADR MD/TVD Please include current contact information if different from above. Received by the AOGCC 07/03/2020 PTD: 2200470 E-Set: 33472 Abby Bell 07/06/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/02/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-36 (220-047) Halliburton LWD FINAL 14 JUN 2020 MPU I-36 ROP AGR ABG DGR EWR ADR MD/TVD MPU I-36 PB1 ROP AGR ABG DGR EWR ADR MD/TVD MPU I-36 PB2 ROP AGR ABG DGR EWR ADR MD/TVD Please include current contact information if different from above. Received by the AOGCC 07/03/2020 PTD: 2200470 E-Set: 33473 Abby Bell 07/06/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/02/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-36 (220-047) Halliburton LWD FINAL 14 JUN 2020 MPU I-36 ROP AGR ABG DGR EWR ADR MD/TVD MPU I-36 PB1 ROP AGR ABG DGR EWR ADR MD/TVD MPU I-36 PB2 ROP AGR ABG DGR EWR ADR MD/TVD Please include current contact information if different from above. Received by the AOGCC 07/03/2020 PTD: 2200470 E-Set: 33474 Abby Bell 07/06/2020 ATE OF ALASKA Reviewed By: OIL AN t, 6AS CONSERVATION COMMISSION P.[. Supry�E�`� &(c Z�ZZ�J DIVERTER Test Report for: MILNE PT UNIT I-36 / Comm Contractor/Rig No.: Hilcorp Innovation' PTD#: 2200470 - DATE: 5/22/2020. Inspector Bob Noble - Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Oliver Amend Rig Rep: Allen Lesley Inspector Well Class: DEV Inspection No: divRCN200523185354 Related Insp No: MISC. INSPECTIONS: GAS DETECTORS: Visual Alarm Methane: P P Hydrogen Sulfide: P- P Gas Detectors Misc: NA NA TEST DATA MUD SYSTEM: P/F Location Gen.: P - Housekeeping: P ' Warning Sign P " 24 hr Notice: P " Well Sign: P Drlg. Rig. P _ Misc: NA GAS DETECTORS: Visual Alarm Methane: P P Hydrogen Sulfide: P- P Gas Detectors Misc: NA NA TEST DATA MUD SYSTEM: P/F Visual Alarm Trip Tank: P - P' Mud Pits: P P " Flow Monitor: P P Mud System Misc: -NA_ NA ACCUMULATOR SYSTEM: P/F Time/Pressure P/F Systems Pressure: 2800 P Pressure After Closure: 1900 " P ' 200 psi Recharge Time: 17-'_ P Full Recharge Time: 60 P Nitrogen Bottles (Number of): 6 P Z Avg. Pressure: 2308 P , Accumulator Misc: o NA DIVERTER SYSTEM: Size P/F Designed to Avoid Freeze-up? _ P Remote Operated Diverter? P No Threaded Connections? P " Vent line Below Diverter? P Diverter Size: 13.625 P ' Hole Size: 12.25 P ' Vent Line(s) Size: 16 P ' Vent Line(s) Length: 177___' P " Closest Ignition Source: 80 P " Outlet from Rig Substructure: 165 P Vent Line(s) Anchored: P ' Turns Targeted / Long Radius: NA Divert Valve(s) Full Opening: P Valve(s) Auto & Simultaneous: Annular Closed Time: 7 P Knife Valve Open Time: 6 P Diverter Misc: 0 NA Number of Failures: 0 ✓ Test Time: 1 Remarks: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU I-36 Hilcorp Alaska, LLC Permit to Drill Number: 220-047 Surface Location:2328’ FSL, 3682’ FEL, SEC. 33, T13N, R10E, UM, AK Bottomhole Location:1950’ FNL, 1625’ FWL, SEC. 21, T13N, R10E, UM, AK Dear Mr. Myers: 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, Jeremy M. Price Chair DATED this ___ day of May, 2020. y, JMPi 20 1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:6. Proposed Depth: 12. Field/Pool(s): MD: 15,463' TVD: 3,990' 4a. Location of Well (Governmental Section):7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date: Total Depth:9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 60.1 15. Distance to Nearest Well Open Surface: x-551689 y- 6009444 Zone-4 33.6 to Same Pool: 120' to MPI-19L1 16. Deviated wells:Kickoff depth: 280 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD Cond 20" 129.5# X-56 Weld 169' Surface Surface 169' 169' 8-1/2" 4-1/2" 13.5# L-80 Hyd 625 10,430' 5,033' 3,817' 15,463' 3,990' Tieback 7-5/8" 29.7# L-80 Hyd 521 5,033' Surface Surface 5,033' 3,817' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned?Yes No 20. Attachments:Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Contact Email: Contact Phone: Date: Permit to Drill API Number: Permit Approval Number:50- Date: 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: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Sr Pet Eng Sr Pet Geo Sr Res Eng 3724' to nearest unit boundary 5/22/2020 Authorized Name: Monty Myers Authorized Title: Drilling Manager Joe Engel jengel@hilcorp.com 777-8395 18. Casing Program:Top - Setting Depth - BottomSpecifications MPU I-36 Milne Point Field Schrader Bluff Oil Pool 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp Alaska, LLC 2328' FSL, 3682' FEL, Sec 33, T13N, R10E, UM, AK ADL025906, ADL315848 022224484 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Stg 2 L - 1937 ft3 / T - 314 ft3 1341 1556' FNL, 283' FWL, Sec 33, T13N, R10E, UM, AK 1950' FNL, 1625' FWL, Sec 21, T13N, R10E, UM, AK LONS 88-004 3840 1686 Total Depth MD (ft):Total Depth TVD (ft): Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) Driven Stg 1 L - 685 ft3 / T - 458 ft3 Effect. Depth TVD (ft): Conductor/Structural LengthCasing Intermediate Cementless Screen Liner Tieback Assembly Effect. Depth MD (ft): Authorized Signature: Production Liner Commission Use Only See cover letter for other requirements. Perforation Depth MD (ft): 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): 5/14/2020 12-1/4"9-5/8"5,183'3,830'47# L-80 TXP 5,183'Surface Surface es N ype of W L l R L 1b S Class: os N es No s N o D s s s D 84 o : well is p G S S 20 S S S es No s No S G E S es No s Form 10-401 Revised 3/2020 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.05.14 16:39:21 -08'00' Monty M Myers By Samantha Carlisle at 7:38 pm, May 14, 2020 X 029-23677-00-00220-047 X X X DSR-5/15/2020 X X X DLB 05/18/2020 (Nb sand) *3000 psi BOP test Development - Oil gls 5/20/20 S00 5/20/2020 Milne Point Unit (MPU) I-36 Drilling Program Version 1 5/14/2020 Table of Contents 1.0 Well Summary ........................................................................................................................... 2 2.0 Management of Change Information ........................................................................................ 3 3.0 Tubular Program:...................................................................................................................... 4 4.0 Drill Pipe Information: .............................................................................................................. 4 5.0 Internal Reporting Requirements ............................................................................................. 5 6.0 Planned Wellbore Schematic ..................................................................................................... 6 7.0 Drilling / Completion Summary ................................................................................................ 7 8.0 Mandatory Regulatory Compliance / Notifications .................................................................. 8 9.0 R/U and Preparatory Work ..................................................................................................... 10 10.0 N/U 13-5/8” 5M Diverter System ............................................................................................. 11 11.0 Drill 12-1/4” Hole Section ........................................................................................................ 13 12.0 Run 9-5/8” Surface Casing ...................................................................................................... 16 13.0 Cement 9-5/8” Surface Casing ................................................................................................. 22 14.0 ND Diverter, NU BOPE, & Test .............................................................................................. 27 15.0 Drill 8-1/2” Hole Section .......................................................................................................... 28 16.0 Run 4-1/2” Screen Liner .......................................................................................................... 33 17.0 Run 7-5/8” Tieback .................................................................................................................. 37 18.0 Run Upper Completion - ESP ................................................................................................. 40 19.0 Innovation Rig Diverter Schematic ......................................................................................... 42 20.0 Innovation Rig BOP Schematic ............................................................................................... 43 21.0 Wellhead Schematic ................................................................................................................. 44 22.0 Days Vs Depth .......................................................................................................................... 45 23.0 Formation Tops & Information............................................................................................... 46 24.0 Anticipated Drilling Hazards .................................................................................................. 47 25.0 Innovation Rig Layout ............................................................................................................. 51 26.0 FIT Procedure .......................................................................................................................... 52 27.0 Innovation Rig Choke Manifold Schematic ............................................................................ 53 28.0 Casing Design ........................................................................................................................... 54 29.0 8-1/2” Hole Section MASP ....................................................................................................... 55 30.0 Spider Plot (NAD 27) (Governmental Sections) ...................................................................... 56 31.0 Surface Plat (As Built) (NAD 27) ............................................................................................. 57 Page 2 Milne Point Unit I-36 SB NB Producer Drilling Procedure 1.0 Well Summary Well MPU I-36 Pad Milne Point “I” Pad Planned Completion Type ESP on 3-1/2 tubing Target Reservoir(s) Schrader Bluff NB Sand Planned Well TD, MD / TVD 15,462’ MD / 3,990’ TVD PBTD, MD / TVD 15,452’ MD / 3,990’ TVD Surface Location (Governmental) 2328' FSL, 3682' FEL, Sec 33, T13N, R10E, UM, AK Surface Location (NAD 27) X= 551689, Y= 6009444 Top of Productive Horizon (Governmental) 1556' FNL, 283' FWL, Sec 33, T13N, R10E, UM, AK TPH Location (NAD 27) X= 550360 Y= 6010830 BHL (Governmental) 1950' FNL, 1625' FWL, Sec 21, T13N, R10E, UM, AK BHL (NAD 27) X= 551605, Y= 6021004 AFE Number 2011148 AFE Drilling Days 20 AFE Completion Days 4 AFE Drilling Amount $3,630,471 AFE Completion Amount $2,545,618 AFE Facility Amount $391,000 Maximum Anticipated Pressure (Surface) 1341 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1686 psig Work String 5” 19.5# S-135 NC 50 Innovation KB Elevation above MSL: 26.5 ft + 33.6 ft = 60.1 ft GL Elevation above MSL: 33.6 ft BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams Page 3 Milne Point Unit I-36 SB NB Producer Drilling Procedure 2.0 Management of Change Information Page 4 Milne Point Unit I-36 SB NB Producer Drilling Procedure 3.0 Tubular Program: Hole Section OD (in) ID (in) Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) Cond 20” 19.25” - - - X-52 Weld 12-1/4” 9-5/8” 8.835” 8.679” 10.625” 40 L-80 TXP 5,750 3,090 916 9-5/8” 8.681” 8.525” 10.625” 47 L-80 TXP 6,870 4,750 1,086 Tieback 7-5/8” 6.875” 6.75” 8.5” 29.7 L-80 HYD 563 6,890 4,790 683 8-1/2” 4-1/2” Screens 3.920 3.795 4.714 13.5 L-80 Hydril 625 9,020 8,540 279 4.0 Drill Pipe Information: Hole Section OD (in) ID (in) TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn M/U (Min) M/U (Max) Tension (k-lbs) Surface & Production 5” 4.276” 3.25” 6.625” 19.5 S-135 DS50 36,100 43,100 560klb 5” 4.276” 3.25” 6.625” 19.5 S-135 NC50 30,730 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 5 Milne Point Unit I-36 SB NB Producer Drilling Procedure 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on WellEz. x Report covers operations from 6am to 6am x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area – this will not save the data entered, and will navigate to another data entry. x Ensure time entry adds up to 24 hours total. x Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. x Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates x Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorp, jengel@hilcorp.com and cdinger@hilcorp.com 5.3 Intranet Home Page Morning Update x Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 5.4 EHS Incident Reporting x Health and Safety: Notify EHS field coordinator. x Environmental: Drilling Environmental Coordinator x Notify Drilling Manager & Drilling Engineer on all incidents x Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally x Send final “As-Run” Casing tally to mmyers@hilcorp,com jengel@hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cement report x Send casing and cement report for each string of casing to mmyers@hilcorp.com jengel@hilcorp.com and cdinger@hilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 jengel@hilcorp.com Completion Engineer Ian Toomey 907.777.8434 907.903-3987 itoomey@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com Drilling Env. Coordinator Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 cajones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 6 Milne Point Unit I-36 SB NB Producer Drilling Procedure 6.0 Planned Wellbore Schematic (40# below 2000') ES Note: top 2000' 9 5/8" is 47# Page 7 Milne Point Unit I-36 SB NB Producer Drilling Procedure 7.0 Drilling / Completion Summary MPU I-36 is a grassroots producer planned to be drilled in the Schrader Bluff Nb sand. I-36 is part of a multi well program targeting the Schrader Bluff sand on I-Pad The directional plan is a catenary well path build, 12.25” hole with 9-5/8” surface casing set into the top of the Schrader Bluff Nb sand. An 8.5” lateral section will then be drilled. A 4-1/2” screen liner will be run in the open hole section and the well produced with an ESP assembly. The Innovation Rig will be used to drill and complete the wellbore Drilling operations are expected to commence approximately May 22, 2020, pending rig schedule. Surface casing will be run to 5,182’ MD / 3,830’ TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point “B” pad G&I facility. General sequence of operations: 1. MIRU Innovation Rig to well site 2. N/U & Test 13-5/8” Diverter and 16” diverter line 3. Drill 12-1/4” hole to TD of surface hole section. Run and c ement 9-5/8” surface casing 4. N/D diverter, N/U wellhead, NU 13-5/8” 5M BOP & Test 5. Drill 8-1/2” lateral to well TD. 6. Run 6-5/8” production liner 7. Run 7” tieback 8. Run Upper Completion 9. N/D BOP, N/U Tree, RDMO Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res 2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering) MPU I-36 is a grassroots producer planned to be drilled in the Schrader Bluff Nb sand. Page 8 Milne Point Unit I-36 SB NB Producer Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the all applicable AOGCC regulations, specific regulations are listed below. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x BOPs shall be tested at (2) week intervals during the drilling and completion of MPU I-36. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. x The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. x If the BOP is used to shut in on the well in a well control situation or control fluid flow from the well bore, AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program and drilling fluid system”. x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements”. o Ensure the diverter vent line is at least 75’ away from potential ignition sources x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: No variances are requested at this time. The initial test of BOP equipment will be to 250/3000 psi & Page 9 Milne Point Unit I-36 SB NB Producer Drilling Procedure Summary of Innovation BOP Equipment & Test Requirements Hole Section Equipment Test Pressure (psi) 12 1/4” x 13-5/8” 5M CTI Annular BOP w/ 16” diverter line Function Test Only 8-1/2” x 13-5/8” x 5M Control Technology Inc Annular BOP x 13-5/8” x 5M Control Technology Inc Double Gate o Blind ram in btm cavity x Mud cross w/ 3” x 5M side outlets x 13-5/8” x 5M Control Technology Single ram x 3-1/8” x 5M Choke Line x 3-1/8” x 5M Kill line x 3-1/8” x 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/3000 Subsequent Tests: 250/3000 Primary closing unit: Control Technology Inc. (CTI), 6 station, 3000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: x Well control event (BOPs utilized to shut in the well to control influx of formation fluids). x 24 hours notice prior to spud. x 24 hours notice prior to testing BOPs. x 24 hours notice prior to casing running & cement operations. x Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email: jim.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (O): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email: Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Email: melvin.rixse@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 10 Milne Point Unit I-36 SB NB Producer Drilling Procedure 9.0 R/U and Preparatory Work 9.1 I-36 will utilize a newly set 20” conductor on I-Pad. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4” nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and R/U. 9.6 Rig mat footprint of rig. 9.7 MIRU Innovation. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on either hole section. 9.9 Mix spud mud for 12-1/4” surface hole section. Ensure mud temperatures are cool (<80qF). 9.10 Ensure 5” liners in mud pumps. x White Star Quattro 1300 Hp mud pumps are rated at 4097 psi, 381 gpm @ 140 spm @ 96.5% volumetric efficiency. MIRU Innovation. Page 11 Milne Point Unit I-36 SB NB Producer Drilling Procedure 10.0 N/U 13-5/8” 5M Diverter System 10.1 N/U 13-5/8” CTI BOP stack in diverter configuration (Diverter Schematic attached to program). x N/U 20” x 13-5/8” DSA x N/U 13 5/8”, 5M diverter “T”. x NU Knife gate & 16” diverter line. x Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). x Diverter line must be 75 ft from nearest ignition source x Place drip berm at the end of diverter line. x Utilized extensions if needed. 10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked “warning zone” is established on each side and ahead of the vent line tip. “Warning Zone” must include: x A prohibition on vehicle parking x A prohibition on ignition sources or running equipment x A prohibition on staged equipment or materials x Restriction of traffic to essential foot or vehicle traffic only. Page 12 Milne Point Unit I-36 SB NB Producer Drilling Procedure 10.4 Rig & Diverter Orientation: x May change on location Page 13 Milne Point Unit I-36 SB NB Producer Drilling Procedure 11.0 Drill 12-1/4” Hole Section 11.1 P/U 12-1/4” directional drilling assembly: x Ensure BHA components have been inspected previously. x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Be sure to run a UBHO sub for wireline gyro x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Drill string will be 5” 19.5# S-135. x Run a solid float in the surface hole section. 11.2 Begin drilling out from 20” conductor at reduced flow rates to avoid broaching the conductor. x Consider using a trash bit to clean out conductor to mitigate potential damage from debris in conductor. 11.3 Drill 12-1/4” hole section to section TD, in the Schrader NB sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. x Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. x Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6 deg / 100. x Hold a safety meeting with rig crews to discuss: x Conductor broaching ops and mitigation procedures. x Well control procedures and rig evacuation x Flow rates, hole cleaning, mud cooling, etc. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Keep mud as cool as possible to keep from washing out permafrost. x Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. x Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen x Slow in/out of slips and while tripping to keep swab and surge pressures low x Ensure shakers are functioning properly. Check for holes in screens on connections. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. x Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 minimum at TD (pending MW increase due to hydrates). x Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. x Be prepared for gas hydrates. In MPU they have been encountered typically around 2100- 2400’ TVD (just below permafrost). Be prepared for hydrates: Drill 12-1/4” ho le section to section TD, in the Schrader NB sand. Page 14 Milne Point Unit I-36 SB NB Producer Drilling Procedure x Gas hydrates can be identified by the gas detector and a decrease in MW or ECD x Monitor returns for hydrates, checking pressurized & non-pressurized scales x Do not stop to circulate out gas hydrates – this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 fph MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. x Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well. MW will not control gas hydrates, but will affect how gas breaks out at surface. x Surface Hole AC: x There are no wells with a clearance factor of <1.0 11.4 12-1/4” hole mud program summary: x Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ ppg. Depth Interval MW (ppg) Surface – Base Permafrost 8.9+ Base Permafrost - TD 9.2+ (For Hydrates if need based on offset wells) MW can be cut once ~500’ below hydrate zone x PVT System: PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. x Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. x Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. x Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 – 9.0 range with caustic soda. Daily additions of ALDACIDE G / X- CIDE 207 MUST be made to control bacterial action. x Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). g p y ( ) ppg We will start with a simple gel + FW spud mud at 8.8 ppg and gp TD with 9.2+ ppg.ppg Depth Interval Page 15 Milne Point Unit I-36 SB NB Producer Drilling Procedure System Type: 8.8 – 9.2 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Section Density Viscosity Plastic Viscosity Yield Point API FL pH Temp Surface 8.8 – 9.8 75-175 20 - 40 25-45 <10 8.5 – 9.0 70 F System Formulation: Gel + FW spud mud Product Concentration Fresh Water soda Ash AQUAGEL caustic soda BARAZAN D+ BAROID 41 PAC-L /DEXTRID LT ALDACIDE G 0.905 bbl 0.5 ppb 15 - 20 ppb 0.1 ppb (8.5 – 9.0 pH) as needed as required for 8.8 – 9.2 ppg if required for <10 FL 0.1 ppb 11.5 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity. 11.6 RIH t/ bottom, proceed to BROOH t/ HWDP x Pump at full drill rate (400-600 gpm), and maximize rotation. x Pull slowly, 5 – 10 ft / minute, adjust as dictated by hole conditions x Monitor well for any signs of packing off or losses. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. x If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.7 TOOH and LD BHA 11.8 No open hole logging program planned. 8.8 – 9.8 Page 16 Milne Point Unit I-36 SB NB Producer Drilling Procedure 12.0 Run 9-5/8” Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 9-5/8” casing running equipment (CRT & Tongs) x Ensure 9-5/8” TXP x DS50 XO on rig floor and M/U to FOSV. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x R/U of CRT if hole conditions require. x R/U a fill up tool to fill casing while running if the CRT is not used. x Ensure all casing has been drifted to 8.75” on the location prior to running. x Top 2000’ of casing 47# drift 8.525” x Be sure to count the total # of joints on the location before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking 120’ shoe track assembly consisting of: 9-5/8” Float Shoe 1 joint – 9-5/8” TXP, 2 Centralizers 10’ from each end w/ stop rings 1 joint – 9-5/8” TXP, 1 Centralizer mid joint w/ stop ring 9-5/8” Float Collar w/ Stage Cementer Bypass Baffle ‘Top Hat’ 1 joint – 9-5/8” TXP, 1 Centralizer mid joint with stop ring 9-5/8” HES Baffle Adaptor x Ensure bypass baffle is correctly installed on top of float collar. x Ensure proper operation of float equipment while picking up. x Ensure to record S/N’s of all float equipment and stage tool components. This end up. Bypass Baffle g Top 2000’ of casing 47# drift 8.525”(lower at 40#?) Page 17 Milne Point Unit I-36 SB NB Producer Drilling Procedure 12.5 Float equipment and Stage tool equipment drawings: 2500 ft Page 18 Milne Point Unit I-36 SB NB Producer Drilling Procedure 12.6 Continue running 9-5/8” surface casing x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: x 1 centralizer every joint t/ ~ 1000’ MD from shoe x 1 centralizer every 2 joints to ~2,000’ above shoe (Top of Lowest Ugnu) x Verify depth of lowest Ugnu water sand for isolation with Geologist x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. x Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cement returns to surface. 12.7 Install the Halliburton Type H ES-II Stage tool so that it is positioned at least 100’ TVD below the permafrost (~ 2,500’ MD). (Halliburton ESIPC with packer element may be used). x Install centralizers over couplings on 5 joints below and 5 joints above stage tool. x Do not place tongs on ES cementer, this can cause damaged to the tool. x Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. x ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at ~ 2080 psi, and the tool to open at ~ 3000 psi. Reference ESIPC Procedure. 9-5/8” 40# L-80 TXP Make Up Torques: Casing OD Minimum Optimum Maximum 9-5/8” 18,860 ft-lbs 20,960 ft-lbs 23,060 ft-lbs 9-5/8” 47# L-80 TXP MUT: Casing OD Minimum Optimum Maximum 9-5/8” 21,440 ft-lbs 2,3820 ft-lbs 26,200 ft-lbs Install the Halliburton Type H ES-II Stage tool so that it is positioned at least 100’ TVD belowyp the permafrost (~ 2,500’ MD) Page 19 Milne Point Unit I-36 SB NB Producer Drilling Procedure Page 20 Milne Point Unit I-36 SB NB Producer Drilling Procedure 12.8 Continue running 9-5/8” surface casing x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: o 1 centralizer every 2 joints to base of conductor 12.9 The last 2000’ of 9-5/8” will be 47#, from 2000’ to Surface x Ensure drifted to 8.525” 12.10 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. The last 2000’ of 9-5/8” will be 47#, from 2000’ to Surface Page 21 Milne Point Unit I-36 SB NB Producer Drilling Procedure 12.11 Slow in and out of slips. 12.12 P/U landing joint and M/U to casing string. Position the casing shoe +/- 10’ from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 12.13 Lower casing to setting depth. Confirm measurements. 12.14 Have slips staged in cellar, along with necessary equipment for the operation. 12.15 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 22 Milne Point Unit I-36 SB NB Producer Drilling Procedure 13.0 Cement 9-5/8” Surface Casing 13.1 Hold a pre-job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. x How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. x Which pumps will be utilized for displacement, and how fluid will be fed to displacement pump. x Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. x Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses x Review test reports and ensure pump times are acceptable. x Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) – HEC rep to witness. Mix and pump cement per below calculations for the 1st stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated 1st Stage Total Cement Volume: Section Calculation Vol (bbl) Vol (ft3) 12-1/4" OH x 9-5/8" Casing (4,182' - 2500') x .0558 bpf x 1.3 = 122 685 Total Lead 122 685 12-1/4" OH x 9-5/8" Casing (5,182' - 4,182') x .0558 bpf x 1.3 = 72.5 407 9-5/8" Shoe Track 120' x .0758 bpf = 9.1 51.09 Total Tail 81.6 458LeadTail 291 sx 375 sx Page 23 Milne Point Unit I-36 SB NB Producer Drilling Procedure Cement Slurry Design (1st Stage Cement Job): 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets “sticky”, cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. x Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5” liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: 5062’ x .0758 bpf = 383.7bbls 80 bbls of tuned spacer to be left behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, ±4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until Lead Slurry Tail Slurry Density 12.0 lb/gal 15.8 lb/gal Yield 2.35 ft3/sk 1.16 ft3/sk Mixed Water 13.92 gal/sk 4.98 gal/sk p 5062’ x .0758 bpf = 383.7bbls left behind stage tool p 80 bbls of tuned spacer to be Page 24 Milne Point Unit I-36 SB NB Producer Drilling Procedure cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. 13.16 Increase pressure to 3300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. 13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have black water available and vac trucks ready to assist. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. Increase pressure to 3300 psi to open circulating ports in stage collar. Page 25 Milne Point Unit I-36 SB NB Producer Drilling Procedure Second Stage Surface Cement Job: 13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. Try to maintain flow rate through stage tool until 2nd stage is ready. Hold pre-job safety meeting. x Past wells have seen pressure increase while circulating through stage tool after reduced rate 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. Estimated 2nd Stage Total Cement Volume: Section Calculation Vol (bbl) Vol (ft3) 20" Conductor x 9-5/8" Casing (110') x .26 bpf x 1 = 28.6 161 12-1/4" OH x 9-5/8" Casing (2000' - 110') x .0558 bpf x 3 = 316.4 1776.3 Total Lead 345 1937 12-1/4" OH x 9-5/8" Casing (2500' - 2000') x .0558 bpf x 2 = 55.8 314 Total Tail 55.8 314LeadTail Cement Slurry Design (2nd stage cement job): Lead Slurry Tail Slurry System Permafrost L Density 10.7 lb/gal 15.8 lb/gal Yield 4.41 ft3/sk 1.17 ft3/sk Mixed Water 22.02 gal/sk 5.08 gal/sk 439 sx 268 sx Estimated 2nd Stage Total Cement Volume: Page 26 Milne Point Unit I-36 SB NB Producer Drilling Procedure 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement calculation: 2500’ x .0758 bpf = 190 bbls mud 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. 13.29 Land closing plug on stage collar and pressure up to 1000 – 1500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips 13.30 Make initial cut on 9-5/8” final joint. L/D cut joint. Make final cut on 9-5/8”. Dress off stump. Install 9-5/8” wellhead. If transition nipple is welded on, allow to cool as per schedule. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface & volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to jengel@hilcorp.com and cdinger@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 27 Milne Point Unit I-36 SB NB Producer Drilling Procedure 14.0 ND Diverter, NU BOPE, & Test 14.1 ND the diverter T, knife gate, diverter line & NU 11” x 13-5/8” 5M casing spool. 14.2 NU 13-5/8” x 5M BOP as follows: x BOP configuration from top down: 13-5/8” x 5M annular / 13-5/8” x 5M double gate / 13- 5/8” x 5M mud cross / 13-5/8” x 5M single gate x Double gate ram should be dressed with 3-1/2” x 5” VBRs in top cavity, blind ram in bottom cavity. x Single ram can be dressed with 3-1/2” x 5” VBRs or 7-5/8” solid body rams x NU bell nipple, install flowline. x Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). x Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve 14.3 RU MPD RCD and related equipment 14.4 Run 5” BOP test plug 14.5 Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. x Test 5” test joints x Confirm test pressures with PTD x Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug x Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 14.6 RD BOP test equipment 14.7 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.8 Mix 8.9 ppg Baradrill-N fluid for production hole. 14.9 Set wearbushing in wellhead. 14.10 If needed, rack back as much 5” DP in derrick as possible to be used while drilling the hole section. 14.11 Ensure 5” liners in mud pumps. BOPE Test Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. Page 28 Milne Point Unit I-36 SB NB Producer Drilling Procedure 15.0 Drill 8-1/2” Hole Section 15.1 MU 8.5” Cleanout BHA (Milltooth Bit & 1.22° PDM) x Consider drilling out stage tool with RSS BHA 15.2 TIH w/ 8-1/2” cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool. 15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.4 RU and test casing to 2500 psi / 30 min. Ensure to record volume / pressure (every ¼ bbl) and plot on FIT graph. AOGCC reg is 50% of burst = 5750 / 2 = ~2875 psi, but max test pressure on the well is 2,500 psi as per AOGCC. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.5 Drill out shoe track and 20’ of new formation. 15.6 CBU and condition mud for FIT. 15.7 Conduct FIT to 12.0 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT. Document incremental volume pumped (and subsequent pressure) and volume returned. 15.8 POOH and LD cleanout BHA 15.9 PU 8-1/2” directional BHA. x Ensure BHA components have been inspected previously. x Drift and caliper all components before MU. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Ensure MWD is RU and operational. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Drill string will be 5” 19.5# S-135 DS50 & NC50. x Run a ported float in the production hole section. 15.10 8-1/2” hole section mud program summary: x Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. CBU and condition mud for FIT. 15.7 Conduct FIT to 12.0 ppg EMW. Chart RU and test casing to 2500 psi / 30 min. 9 5/8" casing test 12 ppg FIT Page 29 Milne Point Unit I-36 SB NB Producer Drilling Procedure x Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. x Rheology: Keep viscosifier additions to an absolute minimum (N-VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleaning x Run the centrifuge continuously while drilling the production hole, this will help with solids removal. x Dump and dilute as necessary to keep drilled solids to an absolute minimum. x MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, & Toolpusher office. System Type: 8.9 – 9.5 ppg Baradrill-N drilling fluid Properties: Interval Density PV YP LSYP Total Solids MBT HPHT Hardness Production 8.9-9.5 15-25 - ALAP 15 - 30 4-6 <10% <8 <11.0 <100 System Formulation: Product Concentration Water KCL KOH N-VIS DEXTRID LT BARACARB 5 BARACARB 25 BARACARB 50 BARACOR 700 BARASCAV D X-CIDE 207 0.955 bbl 11 ppb 0.1 ppb 1.0 – 1.5 ppb 5 ppb 4 ppb 4 ppb 2 ppb 1.0 ppb 0.5 ppb 0.015 ppb 8.9-9.5 Page 30 Milne Point Unit I-36 SB NB Producer Drilling Procedure 15.11 TIH with 8-1/2” directional assembly to bottom 15.12 Install MPD RCD 15.13 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid 15.14 Begin drilling 8-1/2” hole section, on-bottom staging technique: x Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8K. x Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations x If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to PU off bottom and restart on bottom staging technique. If stick slip continues, consider adding .5% lubes 15.14 Drill 8-1/2” hole section to section TD per Geologist and Drilling Engineer. x Flow Rate: 350-550 GPM, target min. AV’s 200 ft/min, 385 GPM x RPM: 120+ x Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. x Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low x Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection x Monitor Torque and Drag with pumps on every 5 stands x Monitor ECD, pump pressure & hookload trends for hole cleaning indication x Surveys can be taken more frequently if deemed necessary. x Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. x Use ADR to stay in section. Reservoir plan is to stay in OB sand. x Limit maximum instantaneous ROP to < 250 FPH. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. x Target ROP is as fast as we can clean the hole without having to backream connections x Schrader Bluff NB Concretions: 4-6% Historically x Anticipate similar concentrations in NE x MPD will be utilized to monitor pressure build up on connections. x 8-1/2” Lateral A/C: x J-08 – is a cemented and abandoned NB lateral producer. The only risk is damage to the bit x J-08A - is a shut in OB producer. Geologically there is no risk. x J-16 – is a long term shut in Kuparuk injector. We will control drill past and watch for magnetic interference. The directional plan will be updated to increase separation with J-16 to CF >1.0. An update will be sent out. x J-25/J-25PB1 – is currently an active NB produer. I-36 will be replacing J-25 in the development. J-25 will be filled with cement. There will be TVD separation when I- Install MPD RCD Collision notes...... MPD will be utilized to monitor pressure build up on connections. Page 31 Milne Point Unit I-36 SB NB Producer Drilling Procedure 36 drills under J-25. J-25 does not enter the NB sand until ~350’ to the west of where I-36 is in the NB. Geologically there is minimal risk. 15.15 Reference: Open hole sidetracking practice: x If a known fault is coming up, put a slight “kick-off ramp” in wellbore ahead of the fault so we have a nice place to low side. x Attempt to lowside in a fast drilling interval where the wellbore is headed up. x Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for ~30 min. x Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ GPM) and rotation (120+ RPM). Pump tandem sweeps if needed x Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary x If seepage losses are seen while drilling, consider reducing MW at TD to 9.0 ppg minimum 15.17 Mix and pump 40 bbl 10 ppb SAPP pill. Line up to a closed loop system and circulate three SAP pills with 50 bbl in between. Displace out SAP pills. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. Losses during the cleanup of the wellbore are a good indication that the mud filter cake is being removed, including an increase in the loss rate. 15.18 Displace 1.5 OH + liner volume with viscosified brine. x Proposed brine blend (same as used on M-16, aiming for an 8 on the 6 RPM reading) - KCl: 7.1bbp for 2% NaCl: 60.9ppg for 9.4ppg Lotorq: 1.5% Lube 776: 1.5% Soda Ash: as needed for 9.5pH Busan 1060: 0.42ppb Flo-Vis Plus: 1.25ppb x Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if further discussion needed prior to BROOH. 15.19 BROOH with the drilling assembly to the 9-5/8” casing shoe Page 32 Milne Point Unit I-36 SB NB Producer Drilling Procedure x Circulate at full drill rate (less if losses are seen, 350 GPM minimum). x Rotate at maximum RPM that can be sustained. x Pulling speed 5 – 10 min/stand (slip to slip time, not including connections), adjust as dictated by hole conditions x If backreaming operations are commenced, continue backreaming to the shoe 15.20 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while BROOH. 15.21 CBU minimum two times at 9-5/8” shoe and clean casing with high vis sweeps. 15.22 Monitor well for flow/pressure build up with MPD. Increase fluid weight if necessary. x Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to determine if the well is breathing, treat all flow as an influx until proven otherwise. 15.23 POOH and LD BHA. 15.24 Continue to POOH and stand back BHA if possible. Rabbit DP on TOOH, ensure rabbit diameter is sufficient for future ball drops. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 33 Milne Point Unit I-36 SB NB Producer Drilling Procedure 16.0 Run 4-1/2” Screen Liner 16.1 Confirm VBR’s have been tested on 4-1/2” and 5” test joints to 250/3,000 psi. 16.2 Well control preparedness: In the event of an influx of formation fluids while running the 4- 1/2” production screens, the following well control response procedure will be followed: x PU & MU the 5” safety joint (with 4-1/2” crossover installed on bottom, TIW valve in open position on top, 4-1/2” handling joint above TIW). This joint shall be fully MU and available prior to running the first joint of 4-1/2” screen. x Slack off and position the 5” DP across the BOP, shut in ram or annular on 5” DP. Close TIW valve. x Proceed with well kill operations. 16.3 If an inner string is ran, Well control preparedness: In the event of an influx of formation fluids while running the 2-3/8” inner string inside the 4-1/2” production screens: x PU & MU the 5” safety joint (with 4-1/2” x 2-3/8” triple connect crossover installed on bottom, TIW valve in open position on top, 2-3/8” handling joint above TIW). MU 2-3/8” and then 4-1/2” to triple connect. x This joint shall be fully MU with crossovers prior to running the first joint of wash pipe. x Slack off and position the 5” DP across the BOP, shut in ram or annular on 5” DP. Close TIW valve. Proceed with well kill operations. 16.4 RU 4-1/2” screen running equipment. x Ensure 4-1/2” x NC-50 crossover is on rig floor and MU to FOSV. x Ensure all casing has been drifted on the deck prior to running. x Be sure to count the total # of joints on the deck before running. x Keep hole covered while RU casing tools. x Record OD’s, ID’s, lengths, SN’s of all components w/ vendor & model info. 16.5 Run 4-1/2” screen production liner – Reference screen handling and running procedure. x Use Best O Life 2000 AG thread compound. Dope pin end only with paint brush. Wipe off excess. Thread compound will plug the screens. x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Run packoff and float shoe on bottom. x 4-1/2” Screens should auto –fill, top off with completion brine if needed x Swell packers will not be required on this completion unless the well is drilled out of zone x If needed, install swell packers as per the lower completion tally. x Remove protective packaging on swell packers just prior to picking up x Do not place tongs or slips on the packer element Page 34 Milne Point Unit I-36 SB NB Producer Drilling Procedure 4-1/2”, 13.5 #, L-80, Hydril 625 Torque OD Minimum Optimum Operating Torque 4-1/2” 8,000 ft-lbs 9,600 ft-lbs 12,800 ft-lbs Page 35 Milne Point Unit I-36 SB NB Producer Drilling Procedure 16.6. Ensure to run enough liner to provide for approx 150’ overlap inside 9-5/8” casing. Ensure hanger/packer will not be set in a 9-5/8” connection. x AOGCC regulations require a minimum 100’ overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Do not place liner hanger/packer across 9-5/8” connection. 16.7. Before picking up Baker SLZXP liner hanger / packer assembly, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.8. MU Baker SLZXP liner top packer to 4-1/2” liner. 16.9. Inner string may or not be ran, depending on out of zone excursion and condition of lateral. Have 2-3/8” inner string available if needed. 16.10. Note: PU, SO, ROT and torque of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.11. RIH with liner on ALL 5” HWDP no faster than 30 ft/min – this is to prevent buckling the liner and drill string and weight transfer to get liner to bottom with minimal rotation. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. x Ensure 5” HWDP has been drifted x There is no inner string planned to be run, as opposed to previous wells. The DP should auto fill. Monitor FL and if filling is required due to losses/surging. 16.12. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + SO depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.13. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, & 20 RPM. 16.14. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.15. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.16. Rig up to pump down the work string with the rig pumps. Page 36 Milne Point Unit I-36 SB NB Producer Drilling Procedure 16.17. Break circulation. Begin circulating at ~1 BPM and monitor pump pressures. Do not exceed 1,600 psi while circulating. Pusher tool is set at 2,100 psi with 5% shear screws but it should be discussed before exceeding 1,600 psi. Note all losses. Confirm all pressures with Baker. 16.18. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 16.19. Shut down pumps. Drop setting ball (ball seat now located in HRDE setting tool and not at the WIV) down the workstring and pump slowly (1-2 BPM). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 16.20. Continue pressuring up to 2,700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the SZXP liner hanger/packer to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4,500 psi to release the HRDE running tool. 16.21. Bleed DP pressure to 0 psi. Pick up to expose rotating dog sub and set down 50K without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 RPM and set down 50K again. 16.22. PU to neutral weight, close BOP and test annulus to 1,500 psi for 10 minutes charted. 16.23. Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.24. PU pulling running tool free of the packer and displace with at max rate to wash the liner top. Pump sweeps as needed. 16.25. POOH. LD and inspect running tools. If setting of liner hanger/packer proceeded as planned, LD DP on the TOOH. Note: Once running tool is LD, swap to the completion AFE. 16.26. MU 3-1/2” wash tool and RIH with remaining DP out of derrick to liner top. 16.27. Wash through liner top at max rate and circulate hole clean. Pump sweeps around. Displace well to clean filtered brine after no solids are returned. 16.28. POOH and LD remaining 5” HWDP Page 37 Milne Point Unit I-36 SB NB Producer Drilling Procedure 17.0 Run 7-5/8” Tieback 17.1 RU and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie-back space out calculation. Install 7-5/8” solid body casing rams in the upper ram cavity. RU testing equipment. PT to 250/3,000 psi with 7” test joint. RD testing equipment. 17.2 RU 7-5/8” casing handling equipment. x Ensure XO to DP made up to FOSV and ready on rig floor. x Rig up computer torque monitoring service. x String should stay full while running, RU fill up line and check as appropriate. 17.3 PU 7-5/8” tieback seal assembly and set in rotary table. Ensure 7-5/8” seal assembly has (4) 1” holes above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8” x 7- 5/8” annulus. 17.4 MU first joint of 7-5/8” to seal assy. 17.6 Run 7-5/8”, 29.7#, L-80 HYD 563 tieback to position seal assembly two joints above tieback sleeve. Record PU and SO weights. 7-5/8”, 29.7#, L-80, Hyd 563 = Casing OD Torque (Min) Torque (Max) Torque (Yield) 7-5/8” 8,600 ft-lbs 15,100 ft-lbs 45,000 ft-lbs Page 38 Milne Point Unit I-36 SB NB Producer Drilling Procedure 17.7 MU 7-5/8” to DP crossover. 17.8 MU stand of DP to string, and MU top drive. 17.9 Break circulation at 1 BPM and begin lowering string. Page 39 Milne Point Unit I-36 SB NB Producer Drilling Procedure 17.10 Note seal assembly entering tieback sleeve with a pressure increase, stop pumping and bleed off pressure. Leave standpipe bleed off valve open. 17.11 Continue lowering string and land out on no-go. Set down 5 – 10K and mark the pipe as “NO- GO DEPTH”. 17.12 PU string & remove unnecessary 7-5/8” joints. 17.13 Space out with pups as needed to leave the no-go 1 ft above fully no-go position when the casing hanger is landed. Ensure one full joint is below the casing hanger. 17.14 PU and MU the 7-5/8” casing hanger. 17.15 Ensure circulation is possible through 7-5/8” string. 17.16 RU and circulation corrosion inhibited brine in the 9-5/8” x 7-5/8” annulus. 17.17 With seals stabbed into tieback sleeve, spot diesel freeze protection from 2,500’ TVD to surface in 9-5/8” x 7-5/8”annulus by reverse circulating through the holes in the seal assembly. Ensure annular pressure are limited to prevent collapse of the 7-5/8” casing (verify collapse pressure of 7-5/8” tieback seal assembly). 17.18 SO and land hanger. Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning report. 17.19 Back out the landing joint. MU packoff running tool and install packoff on bottom of landing joint. Set casing hanger packoff and RILDS. PT void to 3,000 psi for 10 minutes. 17.20 RD casing running tools. 17.21 PT 9-5/8” x 7-5/8” annulus to 1,000 psi for 30 minutes charted. Page 40 Milne Point Unit I-36 SB NB Producer Drilling Procedure 18.0 Run Upper Completion - ESP 18.1 RU spooler with ESP power cable and heat trace. 18.2 Verify the ESP components as per Centrilift. Verify that the length of the motor lead flat cable will place the splice between the discharge head and the 10’ handling pup collar. A Centrilift rep shall be on the rig floor at all times during the running of the ESP. 18.3 Makeup new ESP assembly with new motor lead extension, seal section and motor. 18.4 Run the 3-1/2” ESP Completion as noted below. The completion includes two 3/8” capillary tube from surface to the centralizer on the motor. The capillary tube will be secured to the tubing with Cannon clamps. Function test the capillary tube every ~2,000’ by pumping ~2 gallons of hydraulic oil through the check valves. Record the pressure at each testing point 18.5 M/U ESP assy and RIH to setting depth. Confirm tally with Operations Engineer i. Ensure appropriate well control crossovers on rig floor and ready. ii. Monitor displacement from wellbore while RIH. x Centrilift ESP Assembly with bottom of assembly @ predetermined depth x 10’ 3-1/2” 9.3#, L-80 Pup Joint x 1 joint 3-1/2” 9.3#, L-80 EUE 8rd tubing x 3-1/2” “XN” nipple (2.813” packing bore / 2.75” No -Go ID) x 3 joints 3-1/2” 9.3#, L-80 EUE 8rd tubing x 10’ 3-1/2” 9.3#, L-80 Pup Joint x GLM 3-1/2” x 1” GLM w/ dummy installed x 10’ 3-1/2” 9.3#, L-80 Pup Joint x 3-1/2” 9.3#, L-80 EUE 8rd tubing x 10’ 3-1/2” 9.3#, L-80 Pup Joint x GLM 3-1/2” x 1” w/ SO @ ~140’ MD x 10’ 3-1/2” 9.3#, L-80 Pup Joint x 3 joints 3-1/2” 9.3#, L-80 EUE 8rd tubing x Tubing Hanger o Check the conductivity of electric cable every 2,000’ and every new splice while running in hole. o Use Cannon clamps on every joint to secure the capillary tube. o The make up torque values for 3-1/2” L-80 9.3# EUE 8rd tubing are: Page 41 Milne Point Unit I-36 SB NB Producer Drilling Procedure Minimum: 2350 ft-lb, Optimum: 3100 ft-lb, and maximum: 3910 ft-lb. o The 3-1/2” L-80 9.3# EUE 8rd tubing performance properties are: Body Yield: 159,000#, Burst: 10,160 psi, Collapse: 10, psi. 18.6 Fill tubing while splicing cable, mid-cable splices and tubing hanger splices. After tubing is full, break circulation by pumping 10 bbls down the tubing to clear any debris. 18.7 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 18.8 MU tubing hanger and landing joint. Splice ESP power cable and terminate control lines. Test cable. Install a brass-shipping cap on the ESP penetrator. 18.9 Land tubing with extreme care to minimize damaging the ESP penetrator, pigtail and alignment pin. 18.10 RILDS and test hanger. LD landing joint. 18.11 Install BPV and N/D BOP. 18.12 N/U tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. Terminate the cap strings. 18.13 Circulate diesel freeze protection down 3-1/2” x 7-5/8” annulus (Volume should equal capacity of tubing to 2500’ + tubing annulus to 2500’). Connect IA to tree and allow diesel freeze protect to “U-tube” into position. Note – this may be done post-rig. 18.14 Pull BPV. Set TWC. Test tree to 250 psi low / 5000 psi high. Pull TWC. Set BPV. 18.15 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 18.16 RDMO Innovation Page 42 Milne Point Unit I-36 SB NB Producer Drilling Procedure 19.0 Innovation Rig Diverter Schematic Page 43 Milne Point Unit I-36 SB NB Producer Drilling Procedure 20.0 Innovation Rig BOP Schematic Page 44 Milne Point Unit I-36 SB NB Producer Drilling Procedure 21.0 Wellhead Schematic Page 45 Milne Point Unit I-36 SB NB Producer Drilling Procedure 22.0 Days Vs Depth Page 46 Milne Point Unit I-36 SB NB Producer Drilling Procedure 23.0 Formation Tops & Information Note EMW estimates based on previous MPU Schrader Bluff wells. DLB Page 47 Milne Point Unit I-36 SB NB Producer Drilling Procedure 24.0 Anticipated Drilling Hazards 12-1/4” Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Gas hyrates have not been seen on Moose pad. However, be prepared for them. Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates, but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non-pressurized mud scale. The non-pressurized scale will reflect the actual mud cut weight. Add 1.0 – 2.0 ppb Lecithin to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti-Collison: There are no known wells with a clearance factory <1.0. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Well Specific A/C: x There are no wells with a clearance factor of <1.0 Page 48 Milne Point Unit I-36 SB NB Producer Drilling Procedure Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 49 Milne Point Unit I-36 SB NB Producer Drilling Procedure 8-1/2” Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of > 300 gpm Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a “ramp” in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed, we’ll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: Reservoir pressures are expected to be normal. Abnormal (offset injection) pressure has been seen on M- Pad. Utilize MPD to mitigate any abnormal pressure seen. Page 50 Milne Point Unit I-36 SB NB Producer Drilling Procedure Anti-Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Reference A/C report in directional plan. Well Specific AC: x J-08 – is a cemented and abandoned NB lateral producer. The only risk is damage to the bit x J-08A - is a shut in OB producer. Geologically there is no risk. x J-16 – is a long term shut in Kuparuk injector. We will control drill past and watch for magnetic interference. The directional plan will be updated to increase separation with J-16 to CF >1.0. An update will be sent out. x J-25/J-25PB1 – is currently an active NB produer. I-36 will be replacing J-25 in the development. J-25 will be filled with cement. There will be TVD separation when I- 36 drills under J-25. J-25 does not enter the NB sand until ~350’ to the west of where I-36 is in the NB. Geologically there is minimal risk. Anti-Collision Notes: Anti-Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitoryy, y y y drilling parameters for signs of magnetic interference with another well. Reference A/C report in gp directional plan. p Well Specific AC: x J-08 – is a cemented and abandoned NB lateral producer. The only risk is damage to– the bit x J-08A - is a shut in OB producer. Geologically there is no risk. x pgy J-16 – is a long term shut in Kuparuk injector. We will control drill past and watch –gpj p for magnetic interference. The directional plan will be updated to increase separation gp with J-16 to CF >1.0. An update will be sent out. x p J-25/J-25PB1 – is currently an active NB produer. I-36 will be replacing J-25 in the–yp pg development. J-25 will be filled with cement. There will be TVD separation when I-pp 36 drills under J-25. J-25 does not enter the NB sand until ~350’ to the west of where I-36 is in the NB. Geologically there is minimal risk. Page 51 Milne Point Unit I-36 SB NB Producer Drilling Procedure 25.0 Innovation Rig Layout Page 52 Milne Point Unit I-36 SB NB Producer Drilling Procedure 26.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental volume pumped and returned during test. Page 53 Milne Point Unit I-36 SB NB Producer Drilling Procedure 27.0 Innovation Rig Choke Manifold Schematic Page 54 Milne Point Unit I-36 SB NB Producer Drilling Procedure 28.0 Casing Design 12-1/4"Mud Density:9.2 ppg 8-1/2"Mud Density:9.2 ppg Mud Density: 1341 psi (see attached MASP determination & calculation) 1341 psi (see attached M ASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress 1234 9-5/8"4-1/2" 0 5,212 0 3,830 5,182 15,462 3,830 3,990 5,182 10,250 40 12.6 L-80 L-80 DWC H625 207,280 129,150 207,280 129,150 916 279 4.42 2.16 1,892 1,971 3,090 8,540 1.63 4.33 1,341 1,341 5,750 9,020 4.29 6.73 Weight w/o Bouyancy Factor (lbs) Min strength Tension (1000 lbs) DESIGN BY: Joe Engel Hole Size Casing Section Collapse Resistance w/o tension (Psi) Worst case safety factor (Burst) MASP: Production Mode Minimum Yield (psi) Weight (ppf) MASP (psi) Worst Case Safety Factor (Tension) Collapse Pressure at bottom (Psi) Worst Case Safety Factor (Collapse) Length Top (TVD) Tension at Top of Section (lbs) Design Criteria: Hole Size Grade Connection Calculation & Casing Design Factors Calculation/Specification Casing OD Bottom (MD) Bottom (TVD) Top (MD) MASP: Drilling Mode MASP: Hole Size DATE: 5.14.2020 WELL: MPU I-36 Page 55 Milne Point Unit I-36 SB NB Producer Drilling Procedure 29.0 8-1/2” Hole Section MASP MD TVD Planned Top: 5182 3830 Planned TD: 15462 3990 Anticipated Formations and Pressures: Formation TVD TVDss Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff NB Sand 3,830 3,788 1685 Oil 8.46 0.440 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date MPU L-52 8.8-9.35 Surface 3952 2017 MPU L-51 8.9-9.3 Surface 3930 2017 MPU L-53 9-9.25 Surface 3891 2017 MPU J-27 9-9.3 Surface 3666 2015 MPU J-28 9-9.3 Surface 3617 2015 MPI - 19 9 - 9.3 ppg Surface 4,079 2004 MPI - 18 9 - 10 ppg Surface 3,848 2011 MPI - 17 9 - 9.5 ppg Surface 3,864 2004 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 3830 (ft) x 0.78(psi/ft)= 2987.4 2987(psi) - [0.1(psi/ft)*3830(ft)]= 2604 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff NB sand) 3830 (ft) x 0.45(psi/ft)= 1723.5 psi 1723.5(psi) - 0.1(psi/ft)*3830(ft) 1341.0 psi Summary: 1. MASP while drilling 8-1/2" production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.1 psi/ft. 2. Maximum planned mud density for the 8-1/2" hole section is 9.5 ppg. Maximum Anticipated Surface Pressure Calculation 8-1/2" Hole Section MPU I-36 Milne Point Unit Note: EMW pressure calculations. DLB Page 56 Milne Point Unit I-36 SB NB Producer Drilling Procedure 30.0 Spider Plot (NAD 27) (Governmental Sections) Page 57 Milne Point Unit I-36 SB NB Producer Drilling Procedure 31.0 Surface Plat (As Built) (NAD 27) Page 58 Milne Point Unit I-36 SB NB Producer Drilling Procedure 06 May, 2020 Plan: MPU I-36 wp06 Milne Point M Pt I Pad Plan: MPU I-36 MPU I-36 -750075015002250300037504500True Vertical Depth (1500 usft/in)-1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750Vertical Section at 6.50° (1500 usft/in)MPU I-36 (Chantilly) wp02 HeelMPU I-36 (Chantilly) wp02 CP1MPU I-36 (Chantilly) wp02 CP2MPU I-36 (Chantilly) wp02 CP3MPU I-36 (Chantilly) wp02 CP4MPU I-36 (Chantilly) wp02 Toe9 5/8" X 12 1/4"6 5/8" X 8 1/2"500100015002000250030003500400045005000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11 500 12000 125 00 13 000 1350014000145001500015463MPU I-36 wp06Start Dir 3º/100' : 280' MD, 280'TVDStart Dir 4º/100' : 450' MD, 449.78'TVDStart Dir 2º/100' : 577.5' MD, 577.11'TVDStart Dir 4º/100' : 1577.5' MD, 1556.92'TVDEnd Dir : 1941' MD, 1879.81' TVDStart Dir 4º/100' : 2390.55' MD, 2251.74'TVDEndDir :4882.52' MD, 3803.94'TVDStartDir4º/100':5182.52'MD, 3830.09'TVDEndDir :5336.58' MD, 3835.25'TVDStartDir3º/100':6602.44'MD, 3809.63'TVDEndDir : 6755.88' MD, 3810.1'TVDStartDir3º/100':8630.66'MD, 3859.43'TVDEndDir:8667.11'MD,3860.11'TVDStartDir3º/100':11166.61'MD,3888.82'TVDEnd Dir :11251.8' MD,3890.09' TVDStartDir3º/100':13980.33'MD,3940.09'TVDEndDir : 14030.87'MD,3941.41'TVDTotal Depth:15462.67'MD,3990.1'TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Pedal CurveWarning Method: Error RatioWELL DETAILS: Plan: MPU I-3633.60+N/-S +E/-WNorthingEastingLatittudeLongitude0.000.006009444.08551689.19 70° 26' 11.572 N 149° 34' 42.850 WSURVEY PROGRAMDate: 2020-03-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool26.50 2000.00 MPU I-36 wp06 (MPU I-36) 3_Gyro-GC_Csg2000.00 5182.52 MPU I-36 wp06 (MPU I-36) 3_MWD+IFR2+MS+Sag5182.52 15462.67 MPU I-36 wp06 (MPU I-36) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSNo formation data is availableREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-36, True NorthVertical (TVD) Reference:MPU I-36 Planned RKB @ 60.10usftMeasured Depth Reference:MPU I-36 Planned RKB @ 60.10usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt I PadWell:Plan: MPU I-36Wellbore:MPU I-36Design:MPU I-36 wp06CASING DETAILSTVD TVDSS MD SizeName3830.09 3769.99 5182.52 9-5/8 9 5/8" X 12 1/4"3990.10 3930.00 15462.67 6-5/8 6 5/8" X 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.002 280.00 0.00 0.00 280.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 280' MD, 280'TVD3 450.00 5.10 340.00 449.78 7.11 -2.59 3.00 340.00 6.77 Start Dir 4º/100' : 450' MD, 449.78'TVD4 577.50 0.00 0.00 577.11 12.43 -4.53 4.00 180.00 11.84 Start Dir 2º/100' : 577.5' MD, 577.11'TVD5 1177.50 12.00 240.00 1172.73 -18.87 -58.74 2.00 240.00 -25.406 1577.50 20.00 240.00 1556.92 -73.95 -154.15 2.00 0.00 -90.92 Start Dir 4º/100' : 1577.5' MD, 1556.92'TVD7 1941.00 34.18 247.35 1879.81 -144.73 -303.00 4.00 16.63 -178.10 End Dir : 1941' MD, 1879.81' TVD8 2390.55 34.18 247.35 2251.74 -241.99 -536.04 0.00 0.00 -301.12 Start Dir 4º/100' : 2390.55' MD, 2251.74'TVD9 4882.52 85.00 2.77 3803.94 1079.72 -1334.24 4.00 114.12 921.74 End Dir : 4882.52' MD, 3803.94' TVD10 5182.52 85.00 2.77 3830.09 1378.23 -1319.80 0.00 0.00 1219.97 MPU I-36 (Chantilly) wp02 Heel Start Dir 4º/100' : 5182.52' MD, 3830.09'TVD11 5336.58 91.16 2.57 3835.25 1531.97 -1312.62 4.00 -1.82 1373.53 End Dir : 5336.58' MD, 3835.25' TVD12 6602.44 91.16 2.57 3809.63 2796.29 -1255.77 0.00 0.00 2636.16 Start Dir 3º/100' : 6602.44' MD, 3809.63'TVD13 6755.55 88.50 6.32 3810.09 2948.90 -1243.90 3.00 125.37 2789.13 MPU I-36 (Chantilly) wp02 CP1 End Dir : 6755.88' MD, 3810.1' TVD14 6755.88 88.49 6.31 3810.10 2949.22 -1243.87 3.00 -142.80 2789.45 End Dir : 6755.88' MD, 3810.1' TVD15 8630.66 88.49 6.31 3859.43 4811.98 -1037.75 0.00 0.00 4663.57 Start Dir 3º/100' : 8630.66' MD, 3859.43'TVD16 8665.58 89.34 6.93 3860.09 4846.67 -1033.73 3.00 36.00 4698.49 MPU I-36 (Chantilly) wp02 CP217 8667.11 89.34 6.88 3860.11 4848.19 -1033.54 3.00 -87.73 4700.02 End Dir : 8667.11' MD, 3860.11' TVD18 11166.61 89.34 6.88 3888.82 7329.50 -733.97 0.00 0.00 7199.30 Start Dir 3º/100' : 11166.61' MD, 3888.82'TVD19 11251.80 88.95 9.41 3890.09 7413.82 -721.90 3.00 98.84 7284.44 MPU I-36 (Chantilly) wp02 CP3 End Dir : 11251.8' MD, 3890.09' TVD20 13980.33 88.95 9.41 3940.09 10105.17 -275.86 0.00 0.00 10008.99 MPU I-36 (Chantilly) wp02 CP4 Start Dir 3º/100' : 13980.33' MD, 3940.09'TVD21 14030.87 88.05 10.63 3941.41 10154.92 -267.07 3.00 126.37 10059.41 End Dir : 14030.87' MD, 3941.41' TVD22 15462.67 88.05 10.63 3990.10 11561.34 -3.07 0.00 0.00 11486.67 MPU I-36 (Chantilly) wp02 Toe Total Depth : 15462.67' MD, 3990.1' TVD -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 South(-)/North(+) (1500 usft/in)-6000 -5250 -4500 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 West(-)/East(+) (1500 usft/in) MPU I-36 (Chantilly) wp02 Toe MPU I-36 (Chantilly) wp02 CP4 MPU I-36 (Chantilly) wp02 CP3 MPU I-36 (Chantilly) wp02 CP2 MPU I-36 (Chantilly) wp02 CP1 MPU I-36 (Chantilly) wp02 Heel 9 5/8" X 12 1/4" 6 5/8" X 8 1/2"2000250030003 5 0 0 3 7 5 0 3990 MPU I-36 wp06 Start Dir 3º/100' : 280' MD, 280'TVD Start Dir 4º/100' : 450' MD, 449.78'TVD Start Dir 2º/100' : 577.5' MD, 577.11'TVD Start Dir 4º/100' : 1577.5' MD, 1556.92'TVD End Dir : 1941' MD, 1879.81' TVD Start Dir 4º/100' : 2390.55' MD, 2251.74'TVD End Dir : 4882.52' MD, 3803.94' TVD Start Dir 4º/100' : 5182.52' MD, 3830.09'TVD End Dir : 5336.58' MD, 3835.25' TVD Start Dir 3º/100' : 6602.44' MD, 3809.63'TVD End Dir : 6755.88' MD, 3810.1' TVD Start Dir 3º/100' : 8630.66' MD, 3859.43'TVD End Dir : 8667.11' MD, 3860.11' TVD Start Dir 3º/100' : 11166.61' MD, 3888.82'TVD End Dir : 11251.8' MD, 3890.09' TVD Start Dir 3º/100' : 13980.33' MD, 3940.09'TVD End Dir : 14030.87' MD, 3941.41' TVD Total Depth : 15462.67' MD, 3990.1' TVD CASING DETAILS TVD TVDSS MD Size Name 3830.09 3769.99 5182.52 9-5/8 9 5/8" X 12 1/4" 3990.10 3930.00 15462.67 6-5/8 6 5/8" X 8 1/2" Project: Milne Point Site: M Pt I Pad Well: Plan: MPU I-36 Wellbore: MPU I-36 Plan: MPU I-36 wp06 WELL DETAILS: Plan: MPU I-36 33.60+N/-S +E/-W Northing Easting Latittude Longitude0.00 0.00 6009444.08 551689.19 70° 26' 11.572 N 149° 34' 42.850 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPU I-36, True North Vertical (TVD) Reference:MPU I-36 Planned RKB @ 60.10usft Measured Depth Reference:MPU I-36 Planned RKB @ 60.10usft Calculation Method:Minimum Curvature Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp06 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: From: Site Latitude: Longitude: Position Uncertainty: Northing: Easting: Grid Convergence: M Pt I Pad, TR-13-10 usft Map usft usft °0.39Slot Radius:"0 6,008,388.01 550,245.83 0.00 70° 26' 1.282 N 149° 35' 25.422 W Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: Plan: MPU I-36, Slot I-26 usft usft 0.00 0.00 6,009,444.08 551,689.19 33.60Wellhead Elevation:usft0.50 70° 26' 11.572 N 149° 34' 42.850 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-36 Model NameMagnetics BGGM2019 4/23/2020 16.00 80.85 57,377.73369478 Phase:Version: Audit Notes: Design MPU I-36 wp06 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:26.50 6.500.000.0026.50 5/6/2020 2:31:40PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp06 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Inclination (°) Azimuth (°) +E/-W (usft) Tool Face (°) +N/-S (usft) Measured Depth (usft) Vertical Depth (usft) Dogleg Rate (°/100usft) Build Rate (°/100usft) Turn Rate (°/100usft) Plan Sections TVD System usft 0.000.000.000.000.000.0026.500.000.0026.50 -33.60 0.000.000.000.000.000.00280.000.000.00280.00 219.90 340.000.003.003.00-2.597.11449.78340.005.10450.00 389.68 180.000.00-4.004.00-4.5312.43577.110.000.00577.50 517.01 240.000.002.002.00-58.74-18.871,172.73240.0012.001,177.50 1,112.63 0.000.002.002.00-154.15-73.951,556.92240.0020.001,577.50 1,496.82 16.632.023.904.00-303.00-144.731,879.81247.3534.181,941.00 1,819.71 0.000.000.000.00-536.04-241.992,251.74247.3534.182,390.55 2,191.64 114.124.632.044.00-1,334.241,079.723,803.942.7785.004,882.52 3,743.84 0.000.000.000.00-1,319.801,378.233,830.092.7785.005,182.52 3,769.99 -1.82-0.134.004.00-1,312.621,531.973,835.252.5791.165,336.58 3,775.15 0.000.000.000.00-1,255.772,796.293,809.632.5791.166,602.44 3,749.53 125.372.45-1.743.00-1,243.902,948.903,810.096.3288.506,755.55 3,749.99 -142.80-1.81-2.393.00-1,243.872,949.223,810.106.3188.496,755.88 3,750.00 0.000.000.000.00-1,037.754,811.983,859.436.3188.498,630.66 3,799.33 36.001.762.433.00-1,033.734,846.673,860.096.9389.348,665.58 3,799.99 -87.73-3.000.123.00-1,033.544,848.193,860.116.8889.348,667.11 3,800.01 0.000.000.000.00-733.977,329.503,888.826.8889.3411,166.61 3,828.72 98.842.96-0.463.00-721.907,413.823,890.099.4188.9511,251.80 3,829.99 0.000.000.000.00-275.8610,105.173,940.099.4188.9513,980.33 3,879.99 126.372.42-1.783.00-267.0710,154.923,941.4110.6388.0514,030.87 3,881.31 0.000.000.000.00-3.0711,561.343,990.1010.6388.0515,462.67 3,930.00 5/6/2020 2:31:40PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp06 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS -33.60 Vert Section 26.50 0.00 26.50 0.00 0.000.00 551,689.196,009,444.08-33.60 0.00 0.00 100.00 0.00 100.00 0.00 0.000.00 551,689.196,009,444.0839.90 0.00 0.00 200.00 0.00 200.00 0.00 0.000.00 551,689.196,009,444.08139.90 0.00 0.00 280.00 0.00 280.00 0.00 0.000.00 551,689.196,009,444.08219.90 0.00 0.00 Start Dir 3º/100' : 280' MD, 280'TVD 300.00 0.60 300.00 0.10 -0.04340.00 551,689.156,009,444.18239.90 3.00 0.09 400.00 3.60 399.92 3.54 -1.29340.00 551,687.886,009,447.61339.82 3.00 3.37 450.00 5.10 449.78 7.11 -2.59340.00 551,686.566,009,451.17389.68 3.00 6.77 Start Dir 4º/100' : 450' MD, 449.78'TVD 500.00 3.10 499.65 10.46 -3.81340.00 551,685.316,009,454.52439.55 4.00 9.97 577.50 0.00 577.11 12.43 -4.530.00 551,684.586,009,456.48517.01 4.00 11.84 Start Dir 2º/100' : 577.5' MD, 577.11'TVD 600.00 0.45 599.61 12.39 -4.60240.00 551,684.506,009,456.44539.51 2.00 11.79 700.00 2.45 699.57 11.12 -6.79240.00 551,682.326,009,455.16639.47 2.00 10.28 800.00 4.45 799.38 8.12 -12.00240.00 551,677.136,009,452.11739.28 2.00 6.70 900.00 6.45 898.93 3.37 -20.23240.00 551,668.946,009,447.31838.83 2.00 1.06 1,000.00 8.45 998.08 -3.12 -31.46240.00 551,657.766,009,440.75937.98 2.00 -6.66 1,100.00 10.45 1,096.72 -11.32 -45.68240.00 551,643.606,009,432.441,036.62 2.00 -16.42 1,177.50 12.00 1,172.73 -18.87 -58.74240.00 551,630.596,009,424.811,112.63 2.00 -25.40 1,200.00 12.45 1,194.72 -21.25 -62.87240.00 551,626.486,009,422.401,134.62 2.00 -28.23 1,300.00 14.45 1,291.97 -32.88 -83.01240.00 551,606.426,009,410.631,231.87 2.00 -42.06 1,400.00 16.45 1,388.35 -46.20 -106.08240.00 551,583.446,009,397.151,328.25 2.00 -57.91 1,500.00 18.45 1,483.75 -61.19 -132.05240.00 551,557.586,009,381.981,423.65 2.00 -75.75 1,577.50 20.00 1,556.92 -73.95 -154.15240.00 551,535.576,009,369.071,496.82 2.00 -90.92 Start Dir 4º/100' : 1577.5' MD, 1556.92'TVD 1,600.00 20.86 1,578.01 -77.83 -160.97240.72 551,528.776,009,365.141,517.91 4.00 -95.56 1,700.00 24.73 1,670.18 -95.93 -195.22243.35 551,494.666,009,346.811,610.08 4.00 -117.42 1,800.00 28.64 1,759.51 -115.34 -235.70245.30 551,454.326,009,327.121,699.41 4.00 -141.28 1,900.00 32.56 1,845.57 -135.95 -282.23246.82 551,407.946,009,306.191,785.47 4.00 -167.03 1,941.00 34.18 1,879.81 -144.73 -303.00247.35 551,387.236,009,297.261,819.71 4.00 -178.10 End Dir : 1941' MD, 1879.81' TVD 2,000.00 34.18 1,928.62 -157.50 -333.58247.35 551,356.746,009,284.291,868.52 0.00 -194.25 2,100.00 34.18 2,011.36 -179.13 -385.42247.35 551,305.056,009,262.301,951.26 0.00 -221.61 2,200.00 34.18 2,094.09 -200.77 -437.26247.35 551,253.376,009,240.312,033.99 0.00 -248.98 2,300.00 34.18 2,176.82 -222.40 -489.10247.35 551,201.696,009,218.322,116.72 0.00 -276.34 2,390.55 34.18 2,251.73 -241.99 -536.04247.35 551,154.896,009,198.402,191.63 0.00 -301.12 Start Dir 4º/100' : 2390.55' MD, 2251.74'TVD 2,400.00 34.02 2,259.56 -244.01 -540.94247.96 551,150.006,009,196.352,199.46 4.00 -303.67 2,500.00 32.60 2,343.16 -261.58 -592.89254.78 551,098.186,009,178.422,283.06 4.00 -327.02 2,600.00 31.58 2,427.91 -272.28 -644.84262.06 551,046.316,009,167.362,367.81 4.00 -343.53 2,700.00 30.99 2,513.40 -276.04 -696.53269.68 550,994.656,009,163.252,453.30 4.00 -353.12 2,800.00 30.86 2,599.23 -272.85 -747.72277.47 550,943.456,009,166.082,539.13 4.00 -355.74 2,900.00 31.19 2,684.96 -262.72 -798.16285.21 550,892.956,009,175.862,624.86 4.00 -351.39 3,000.00 31.97 2,770.18 -245.71 -847.59292.70 550,843.416,009,192.532,710.08 4.00 -340.08 3,100.00 33.18 2,854.48 -221.89 -895.78299.79 550,795.066,009,216.012,794.38 4.00 -321.86 5/6/2020 2:31:40PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp06 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 2,877.34 Vert Section 3,200.00 34.75 2,937.44 -191.38 -942.49306.37 550,748.146,009,246.192,877.34 4.00 -296.84 3,300.00 36.66 3,018.67 -154.33 -987.50312.40 550,702.876,009,282.932,958.57 4.00 -265.13 3,400.00 38.84 3,097.76 -110.92 -1,030.59317.89 550,659.496,009,326.033,037.66 4.00 -226.87 3,500.00 41.25 3,174.32 -61.36 -1,071.54322.85 550,618.206,009,375.303,114.22 4.00 -182.27 3,600.00 43.86 3,248.00 -5.90 -1,110.17327.34 550,579.206,009,430.493,187.90 4.00 -131.54 3,700.00 46.62 3,318.43 55.20 -1,146.27331.41 550,542.686,009,491.333,258.33 4.00 -74.92 3,800.00 49.52 3,385.26 121.64 -1,179.67335.12 550,508.826,009,557.533,325.16 4.00 -12.69 3,900.00 52.52 3,448.16 193.09 -1,210.21338.52 550,477.786,009,628.763,388.06 4.00 54.85 4,000.00 55.62 3,506.85 269.21 -1,237.75341.65 550,449.726,009,704.683,446.75 4.00 127.36 4,100.00 58.79 3,561.01 349.62 -1,262.14344.55 550,424.786,009,784.923,500.91 4.00 204.50 4,200.00 62.02 3,610.40 433.94 -1,283.27347.27 550,403.066,009,869.083,550.30 4.00 285.88 4,300.00 65.30 3,654.78 521.76 -1,301.04349.82 550,384.696,009,956.763,594.68 4.00 371.12 4,400.00 68.62 3,693.92 612.64 -1,315.36352.24 550,369.746,010,047.533,633.82 4.00 459.80 4,500.00 71.97 3,727.63 706.14 -1,326.16354.56 550,358.306,010,140.943,667.53 4.00 551.48 4,600.00 75.35 3,755.76 801.81 -1,333.38356.79 550,350.426,010,236.553,695.66 4.00 645.71 4,700.00 78.76 3,778.16 899.18 -1,336.99358.95 550,346.136,010,333.893,718.06 4.00 742.05 4,800.00 82.17 3,794.73 997.78 -1,336.981.06 550,345.456,010,432.473,734.63 4.00 840.01 4,882.52 85.00 3,803.94 1,079.72 -1,334.242.77 550,347.636,010,514.433,743.84 4.00 921.74 End Dir : 4882.52' MD, 3803.94' TVD 4,900.00 85.00 3,805.47 1,097.12 -1,333.402.77 550,348.356,010,531.823,745.37 0.00 939.12 5,000.00 85.00 3,814.18 1,196.62 -1,328.592.77 550,352.476,010,631.353,754.08 0.00 1,038.53 5,100.00 85.00 3,822.90 1,296.12 -1,323.772.77 550,356.606,010,730.873,762.80 0.00 1,137.94 5,182.52 85.00 3,830.09 1,378.23 -1,319.802.77 550,360.006,010,813.003,769.99 0.00 1,219.97 Start Dir 4º/100' : 5182.52' MD, 3830.09'TVD - 9 5/8" X 12 1/4" 5,200.00 85.70 3,831.51 1,395.64 -1,318.962.75 550,360.726,010,830.413,771.41 4.00 1,237.35 5,300.00 89.70 3,835.52 1,495.42 -1,314.282.62 550,364.706,010,930.223,775.42 4.00 1,337.03 5,336.58 91.16 3,835.25 1,531.97 -1,312.622.57 550,366.116,010,966.763,775.15 4.00 1,373.52 End Dir : 5336.58' MD, 3835.25' TVD 5,400.00 91.16 3,833.97 1,595.31 -1,309.782.57 550,368.526,011,030.123,773.87 0.00 1,436.78 5,500.00 91.16 3,831.94 1,695.19 -1,305.282.57 550,372.326,011,130.023,771.84 0.00 1,536.53 5,600.00 91.16 3,829.92 1,795.07 -1,300.792.57 550,376.116,011,229.913,769.82 0.00 1,636.27 5,700.00 91.16 3,827.90 1,894.94 -1,296.302.57 550,379.916,011,329.813,767.80 0.00 1,736.02 5,800.00 91.16 3,825.87 1,994.82 -1,291.812.57 550,383.716,011,429.713,765.77 0.00 1,835.76 5,900.00 91.16 3,823.85 2,094.70 -1,287.322.57 550,387.516,011,529.613,763.75 0.00 1,935.51 6,000.00 91.16 3,821.83 2,194.58 -1,282.832.57 550,391.316,011,629.503,761.73 0.00 2,035.25 6,100.00 91.16 3,819.80 2,294.46 -1,278.342.57 550,395.116,011,729.403,759.70 0.00 2,135.00 6,200.00 91.16 3,817.78 2,394.34 -1,273.852.57 550,398.906,011,829.303,757.68 0.00 2,234.74 6,300.00 91.16 3,815.75 2,494.22 -1,269.362.57 550,402.706,011,929.203,755.65 0.00 2,334.49 6,400.00 91.16 3,813.73 2,594.09 -1,264.862.57 550,406.506,012,029.093,753.63 0.00 2,434.23 6,500.00 91.16 3,811.71 2,693.97 -1,260.372.57 550,410.306,012,128.993,751.61 0.00 2,533.98 6,602.44 91.16 3,809.63 2,796.29 -1,255.772.57 550,414.196,012,231.333,749.53 0.00 2,636.16 Start Dir 3º/100' : 6602.44' MD, 3809.63'TVD 6,700.00 89.46 3,809.10 2,893.63 -1,249.364.96 550,419.926,012,328.703,749.00 3.00 2,733.59 6,755.55 88.50 3,810.09 2,948.90 -1,243.906.32 550,425.006,012,384.003,749.99 3.00 2,789.13 5/6/2020 2:31:40PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp06 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 3,750.00 Vert Section 6,755.88 88.49 3,810.10 2,949.22 -1,243.876.31 550,425.036,012,384.333,750.00 2.97 2,789.46 End Dir : 6755.88' MD, 3810.1' TVD 6,800.00 88.49 3,811.26 2,993.06 -1,239.026.31 550,429.586,012,428.193,751.16 0.00 2,833.56 6,900.00 88.49 3,813.89 3,092.42 -1,228.026.31 550,439.886,012,527.623,753.79 0.00 2,933.53 7,000.00 88.49 3,816.52 3,191.78 -1,217.036.31 550,450.196,012,627.043,756.42 0.00 3,033.49 7,100.00 88.49 3,819.15 3,291.14 -1,206.046.31 550,460.496,012,726.463,759.05 0.00 3,133.45 7,200.00 88.49 3,821.78 3,390.50 -1,195.046.31 550,470.806,012,825.883,761.68 0.00 3,233.42 7,300.00 88.49 3,824.42 3,489.86 -1,184.056.31 550,481.106,012,925.313,764.32 0.00 3,333.38 7,400.00 88.49 3,827.05 3,589.21 -1,173.056.31 550,491.416,013,024.733,766.95 0.00 3,433.35 7,500.00 88.49 3,829.68 3,688.57 -1,162.066.31 550,501.716,013,124.153,769.58 0.00 3,533.31 7,600.00 88.49 3,832.31 3,787.93 -1,151.066.31 550,512.016,013,223.583,772.21 0.00 3,633.28 7,700.00 88.49 3,834.94 3,887.29 -1,140.076.31 550,522.326,013,323.003,774.84 0.00 3,733.24 7,800.00 88.49 3,837.57 3,986.65 -1,129.086.31 550,532.626,013,422.423,777.47 0.00 3,833.21 7,900.00 88.49 3,840.20 4,086.01 -1,118.086.31 550,542.936,013,521.853,780.10 0.00 3,933.17 8,000.00 88.49 3,842.83 4,185.37 -1,107.096.31 550,553.236,013,621.273,782.73 0.00 4,033.14 8,100.00 88.49 3,845.47 4,284.73 -1,096.096.31 550,563.536,013,720.693,785.37 0.00 4,133.10 8,200.00 88.49 3,848.10 4,384.09 -1,085.106.31 550,573.846,013,820.123,788.00 0.00 4,233.07 8,300.00 88.49 3,850.73 4,483.45 -1,074.116.31 550,584.146,013,919.543,790.63 0.00 4,333.03 8,400.00 88.49 3,853.36 4,582.80 -1,063.116.31 550,594.456,014,018.963,793.26 0.00 4,433.00 8,500.00 88.49 3,855.99 4,682.16 -1,052.126.31 550,604.756,014,118.393,795.89 0.00 4,532.96 8,600.00 88.49 3,858.62 4,781.52 -1,041.126.31 550,615.056,014,217.813,798.52 0.00 4,632.93 8,630.66 88.49 3,859.43 4,811.99 -1,037.756.31 550,618.216,014,248.293,799.33 0.00 4,663.58 Start Dir 3º/100' : 8630.66' MD, 3859.43'TVD 8,665.58 89.34 3,860.09 4,846.67 -1,033.736.93 550,622.006,014,283.003,799.99 3.00 4,698.49 8,667.11 89.34 3,860.11 4,848.19 -1,033.546.88 550,622.176,014,284.523,800.01 3.00 4,700.02 End Dir : 8667.11' MD, 3860.11' TVD 8,700.00 89.34 3,860.49 4,880.84 -1,029.606.88 550,625.896,014,317.193,800.39 0.00 4,732.91 8,800.00 89.34 3,861.63 4,980.11 -1,017.626.88 550,637.186,014,416.533,801.53 0.00 4,832.90 8,900.00 89.34 3,862.78 5,079.38 -1,005.636.88 550,648.486,014,515.883,802.68 0.00 4,932.89 9,000.00 89.34 3,863.93 5,178.65 -993.656.88 550,659.786,014,615.223,803.83 0.00 5,032.88 9,100.00 89.34 3,865.08 5,277.93 -981.666.88 550,671.076,014,714.563,804.98 0.00 5,132.87 9,200.00 89.34 3,866.23 5,377.20 -969.676.88 550,682.376,014,813.913,806.13 0.00 5,232.86 9,300.00 89.34 3,867.38 5,476.47 -957.696.88 550,693.666,014,913.253,807.28 0.00 5,332.85 9,400.00 89.34 3,868.53 5,575.74 -945.706.88 550,704.966,015,012.603,808.43 0.00 5,432.85 9,500.00 89.34 3,869.68 5,675.02 -933.726.88 550,716.266,015,111.943,809.58 0.00 5,532.84 9,600.00 89.34 3,870.82 5,774.29 -921.736.88 550,727.556,015,211.283,810.72 0.00 5,632.83 9,700.00 89.34 3,871.97 5,873.56 -909.756.88 550,738.856,015,310.633,811.87 0.00 5,732.82 9,800.00 89.34 3,873.12 5,972.83 -897.766.88 550,750.146,015,409.973,813.02 0.00 5,832.81 9,900.00 89.34 3,874.27 6,072.11 -885.786.88 550,761.446,015,509.313,814.17 0.00 5,932.80 10,000.00 89.34 3,875.42 6,171.38 -873.796.88 550,772.746,015,608.663,815.32 0.00 6,032.79 10,100.00 89.34 3,876.57 6,270.65 -861.816.88 550,784.036,015,708.003,816.47 0.00 6,132.78 10,200.00 89.34 3,877.72 6,369.92 -849.826.88 550,795.336,015,807.343,817.62 0.00 6,232.77 10,300.00 89.34 3,878.86 6,469.20 -837.846.88 550,806.626,015,906.693,818.76 0.00 6,332.77 10,400.00 89.34 3,880.01 6,568.47 -825.856.88 550,817.926,016,006.033,819.91 0.00 6,432.76 10,500.00 89.34 3,881.16 6,667.74 -813.866.88 550,829.226,016,105.373,821.06 0.00 6,532.75 5/6/2020 2:31:40PM COMPASS 5000.15 Build 91E Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp06 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 3,822.21 Vert Section 10,600.00 89.34 3,882.31 6,767.01 -801.886.88 550,840.516,016,204.723,822.21 0.00 6,632.74 10,700.00 89.34 3,883.46 6,866.29 -789.896.88 550,851.816,016,304.063,823.36 0.00 6,732.73 10,800.00 89.34 3,884.61 6,965.56 -777.916.88 550,863.106,016,403.403,824.51 0.00 6,832.72 10,900.00 89.34 3,885.76 7,064.83 -765.926.88 550,874.406,016,502.753,825.66 0.00 6,932.71 11,000.00 89.34 3,886.91 7,164.10 -753.946.88 550,885.696,016,602.093,826.81 0.00 7,032.70 11,100.00 89.34 3,888.05 7,263.38 -741.956.88 550,896.996,016,701.443,827.95 0.00 7,132.69 11,166.61 89.34 3,888.82 7,329.50 -733.976.88 550,904.516,016,767.613,828.72 0.00 7,199.30 Start Dir 3º/100' : 11166.61' MD, 3888.82'TVD 11,200.00 89.19 3,889.25 7,362.61 -729.687.87 550,908.576,016,800.743,829.15 3.00 7,232.68 11,251.80 88.95 3,890.09 7,413.82 -721.909.41 550,916.006,016,852.003,829.99 3.00 7,284.44 End Dir : 11251.8' MD, 3890.09' TVD 11,300.00 88.95 3,890.97 7,461.36 -714.029.41 550,923.556,016,899.593,830.87 0.00 7,332.57 11,400.00 88.95 3,892.81 7,560.00 -697.679.41 550,939.216,016,998.333,832.71 0.00 7,432.42 11,500.00 88.95 3,894.64 7,658.63 -681.339.41 550,954.876,017,097.073,834.54 0.00 7,532.28 11,600.00 88.95 3,896.47 7,757.27 -664.989.41 550,970.536,017,195.813,836.37 0.00 7,632.13 11,700.00 88.95 3,898.30 7,855.91 -648.639.41 550,986.196,017,294.543,838.20 0.00 7,731.98 11,800.00 88.95 3,900.14 7,954.55 -632.289.41 551,001.866,017,393.283,840.04 0.00 7,831.84 11,900.00 88.95 3,901.97 8,053.19 -615.949.41 551,017.526,017,492.023,841.87 0.00 7,931.69 12,000.00 88.95 3,903.80 8,151.82 -599.599.41 551,033.186,017,590.763,843.70 0.00 8,031.55 12,100.00 88.95 3,905.63 8,250.46 -583.249.41 551,048.846,017,689.503,845.53 0.00 8,131.40 12,200.00 88.95 3,907.47 8,349.10 -566.909.41 551,064.506,017,788.243,847.37 0.00 8,231.26 12,300.00 88.95 3,909.30 8,447.74 -550.559.41 551,080.166,017,886.983,849.20 0.00 8,331.11 12,400.00 88.95 3,911.13 8,546.37 -534.209.41 551,095.826,017,985.723,851.03 0.00 8,430.96 12,500.00 88.95 3,912.96 8,645.01 -517.869.41 551,111.496,018,084.463,852.86 0.00 8,530.82 12,600.00 88.95 3,914.80 8,743.65 -501.519.41 551,127.156,018,183.203,854.70 0.00 8,630.67 12,700.00 88.95 3,916.63 8,842.29 -485.169.41 551,142.816,018,281.943,856.53 0.00 8,730.53 12,800.00 88.95 3,918.46 8,940.93 -468.819.41 551,158.476,018,380.683,858.36 0.00 8,830.38 12,900.00 88.95 3,920.29 9,039.56 -452.479.41 551,174.136,018,479.413,860.19 0.00 8,930.24 13,000.00 88.95 3,922.13 9,138.20 -436.129.41 551,189.796,018,578.153,862.03 0.00 9,030.09 13,100.00 88.95 3,923.96 9,236.84 -419.779.41 551,205.466,018,676.893,863.86 0.00 9,129.94 13,200.00 88.95 3,925.79 9,335.48 -403.439.41 551,221.126,018,775.633,865.69 0.00 9,229.80 13,300.00 88.95 3,927.62 9,434.11 -387.089.41 551,236.786,018,874.373,867.52 0.00 9,329.65 13,400.00 88.95 3,929.46 9,532.75 -370.739.41 551,252.446,018,973.113,869.36 0.00 9,429.51 13,500.00 88.95 3,931.29 9,631.39 -354.389.41 551,268.106,019,071.853,871.19 0.00 9,529.36 13,600.00 88.95 3,933.12 9,730.03 -338.049.41 551,283.766,019,170.593,873.02 0.00 9,629.22 13,700.00 88.95 3,934.95 9,828.67 -321.699.41 551,299.426,019,269.333,874.85 0.00 9,729.07 13,800.00 88.95 3,936.79 9,927.30 -305.349.41 551,315.096,019,368.073,876.69 0.00 9,828.92 13,900.00 88.95 3,938.62 10,025.94 -289.009.41 551,330.756,019,466.813,878.52 0.00 9,928.78 13,980.33 88.95 3,940.09 10,105.18 -275.869.41 551,343.336,019,546.123,879.99 0.00 10,008.99 Start Dir 3º/100' : 13980.33' MD, 3940.09'TVD 14,000.00 88.60 3,940.51 10,124.56 -272.579.89 551,346.496,019,565.533,880.41 3.00 10,028.63 14,030.87 88.05 3,941.41 10,154.93 -267.0710.63 551,351.776,019,595.933,881.31 3.00 10,059.42 End Dir : 14030.87' MD, 3941.41' TVD 14,100.00 88.05 3,943.76 10,222.83 -254.3310.63 551,364.056,019,663.913,883.66 0.00 10,128.33 14,200.00 88.05 3,947.16 10,321.06 -235.8910.63 551,381.806,019,762.263,887.06 0.00 10,228.01 5/6/2020 2:31:40PM COMPASS 5000.15 Build 91E Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp06 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 3,890.46 Vert Section 14,300.00 88.05 3,950.56 10,419.29 -217.4510.63 551,399.566,019,860.603,890.46 0.00 10,327.69 14,400.00 88.05 3,953.96 10,517.51 -199.0110.63 551,417.326,019,958.943,893.86 0.00 10,427.37 14,500.00 88.05 3,957.36 10,615.74 -180.5710.63 551,435.076,020,057.283,897.26 0.00 10,527.06 14,600.00 88.05 3,960.77 10,713.96 -162.1310.63 551,452.836,020,155.623,900.67 0.00 10,626.74 14,700.00 88.05 3,964.17 10,812.19 -143.7010.63 551,470.586,020,253.973,904.07 0.00 10,726.42 14,800.00 88.05 3,967.57 10,910.42 -125.2610.63 551,488.346,020,352.313,907.47 0.00 10,826.10 14,900.00 88.05 3,970.97 11,008.64 -106.8210.63 551,506.096,020,450.653,910.87 0.00 10,925.79 15,000.00 88.05 3,974.37 11,106.87 -88.3810.63 551,523.856,020,548.993,914.27 0.00 11,025.47 15,100.00 88.05 3,977.77 11,205.10 -69.9410.63 551,541.606,020,647.343,917.67 0.00 11,125.15 15,200.00 88.05 3,981.17 11,303.32 -51.5010.63 551,559.366,020,745.683,921.07 0.00 11,224.83 15,300.00 88.05 3,984.57 11,401.55 -33.0610.63 551,577.126,020,844.023,924.47 0.00 11,324.52 15,400.00 88.05 3,987.97 11,499.78 -14.6210.63 551,594.876,020,942.363,927.87 0.00 11,424.20 15,462.67 88.05 3,990.10 11,561.34 -3.0710.63 551,606.006,021,004.003,930.00 0.00 11,486.67 Total Depth : 15462.67' MD, 3990.1' TVD - 6 5/8" X 8 1/2" Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Tar gets Dip Angle (°) Dip Dir. (°) MPU I-36 (Chantilly) wp02 Heel 3,830.09 6,010,813.00 550,360.001,378.23 -1,319.800.00 0.00 -plan hits target center - Circle (radius 30.00) MPU I-36 (Chantilly) wp02 CP2 3,860.09 6,014,283.00 550,622.004,846.67 -1,033.730.00 0.00 -plan hits target center - Point MPU I-36 (Chantilly) wp02 CP4 3,940.09 6,019,537.00 551,342.0010,096.06 -277.260.00 0.00 -plan misses target center by 0.21usft at 13971.11usft MD (3939.92 TVD, 10096.09 N, -277.37 E) - Point MPU I-36 (Chantilly) wp02 Toe 3,990.10 6,021,004.00 551,606.0011,561.34 -3.070.00 0.00 -plan hits target center - Point MPU I-36 (Chantilly) wp02 CP1 3,810.09 6,012,384.00 550,425.002,948.90 -1,243.900.00 0.00 -plan hits target center - Point MPU I-36 (Chantilly) wp02 CP3 3,890.09 6,016,852.00 550,916.007,413.82 -721.900.00 0.00 -plan hits target center - Point Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 9 5/8" X 12 1/4"3,830.095,182.52 9-5/8 12-1/4 6 5/8" X 8 1/2"3,990.1015,462.67 6-5/8 8-1/2 5/6/2020 2:31:40PM COMPASS 5000.15 Build 91E Page 8 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp06 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 280.00 280.00 0.00 0.00 Start Dir 3º/100' : 280' MD, 280'TVD 450.00 449.78 7.11 -2.59 Start Dir 4º/100' : 450' MD, 449.78'TVD 577.50 577.11 12.43 -4.53 Start Dir 2º/100' : 577.5' MD, 577.11'TVD 1,577.50 1,556.92 -73.95 -154.15 Start Dir 4º/100' : 1577.5' MD, 1556.92'TVD 1,941.00 1,879.81 -144.73 -303.00 End Dir : 1941' MD, 1879.81' TVD 2,390.55 2,251.73 -241.99 -536.04 Start Dir 4º/100' : 2390.55' MD, 2251.74'TVD 4,882.52 3,803.94 1,079.72 -1,334.24 End Dir : 4882.52' MD, 3803.94' TVD 5,182.52 3,830.09 1,378.23 -1,319.80 Start Dir 4º/100' : 5182.52' MD, 3830.09'TVD 5,336.58 3,835.25 1,531.97 -1,312.62 End Dir : 5336.58' MD, 3835.25' TVD 6,602.44 3,809.63 2,796.29 -1,255.77 Start Dir 3º/100' : 6602.44' MD, 3809.63'TVD 6,755.88 3,810.10 2,949.22 -1,243.87 End Dir : 6755.88' MD, 3810.1' TVD 8,630.66 3,859.43 4,811.99 -1,037.75 Start Dir 3º/100' : 8630.66' MD, 3859.43'TVD 8,667.11 3,860.11 4,848.19 -1,033.54 End Dir : 8667.11' MD, 3860.11' TVD 11,166.61 3,888.82 7,329.50 -733.97 Start Dir 3º/100' : 11166.61' MD, 3888.82'TVD 11,251.80 3,890.09 7,413.82 -721.90 End Dir : 11251.8' MD, 3890.09' TVD 13,980.33 3,940.09 10,105.18 -275.86 Start Dir 3º/100' : 13980.33' MD, 3940.09'TVD 14,030.87 3,941.41 10,154.93 -267.07 End Dir : 14030.87' MD, 3941.41' TVD 15,462.67 3,990.10 11,561.34 -3.07 Total Depth : 15462.67' MD, 3990.1' TVD 5/6/2020 2:31:40PM COMPASS 5000.15 Build 91E Page 9 06 May, 2020Milne PointM Pt I PadPlan: MPU I-36MPU I-36MPU I-36 wp06Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp06Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Well Coordinates: 6,009,444.08 N, 551,689.19 E (70° 26' 11.57" N, 149° 34' 42.85" W)Datum Height: MPU I-36 Planned RKB @ 60.10usftScan Range: 26.50 to 5,182.52 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.15 Build: 91EScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftGLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referenceScan Type:Scan Type:25.00Scan Range: 26.50 to 5,182.52 usft. Measured Depth. Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp06Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 26.50 to 5,182.52 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningM Pt I PadMPI-01 - MPI-01 - MPI-0111.56 408.21 7.68 418.11 2.982408.21Centre Distance Pass - MPI-01 - MPI-01 - MPI-0111.65 426.50 7.63 436.37 2.899426.50Ellipse Separation Pass - MPI-01 - MPI-01 - MPI-0112.22 451.50 8.00 461.26 2.897451.50Clearance Factor Pass - MPI-02 - MPI-02 - MPI-0223.91 905.24 16.08 917.11 3.052905.24Clearance Factor Pass - MPI-03 - MPI-03 - MPI-0393.52 984.11 85.11 988.79 11.125984.11Ellipse Separation Pass - MPI-03 - MPI-03 - MPI-0394.70 1,026.50 86.01 1,026.86 10.9031,026.50Clearance Factor Pass - MPI-04 - MPI-04 - MPI-04159.17 1,000.53 150.50 1,008.92 18.3531,000.53Centre Distance Pass - MPI-04 - MPI-04 - MPI-04159.17 1,001.50 150.49 1,009.78 18.3361,001.50Ellipse Separation Pass - MPI-04 - MPI-04 - MPI-04165.23 1,101.50 155.79 1,096.48 17.5071,101.50Clearance Factor Pass - MPI-04 - MPI-04A - MPI-04A159.17 1,000.53 150.50 1,008.92 18.3531,000.53Centre Distance Pass - MPI-04 - MPI-04A - MPI-04A159.17 1,001.50 150.49 1,009.78 18.3361,001.50Ellipse Separation Pass - MPI-04 - MPI-04A - MPI-04A165.23 1,101.50 155.79 1,096.48 17.5071,101.50Clearance Factor Pass - MPI-04 - MPI-04AL1 - MPI-04AL1159.17 1,000.53 150.50 1,008.92 18.3531,000.53Centre Distance Pass - MPI-04 - MPI-04AL1 - MPI-04AL1159.17 1,001.50 150.49 1,009.78 18.3361,001.50Ellipse Separation Pass - MPI-04 - MPI-04AL1 - MPI-04AL1165.23 1,101.50 155.79 1,096.48 17.5071,101.50Clearance Factor Pass - MPI-04 - MPI-04APB1 - MPI-04APB1159.17 1,000.53 150.50 1,008.92 18.3531,000.53Centre Distance Pass - MPI-04 - MPI-04APB1 - MPI-04APB1159.17 1,001.50 150.49 1,009.78 18.3361,001.50Ellipse Separation Pass - MPI-04 - MPI-04APB1 - MPI-04APB1165.23 1,101.50 155.79 1,096.48 17.5071,101.50Clearance Factor Pass - MPI-04 - MPI-04PB1 - MPI-04PB1159.17 1,000.53 150.50 1,008.92 18.3531,000.53Centre Distance Pass - MPI-04 - MPI-04PB1 - MPI-04PB1159.17 1,001.50 150.49 1,009.78 18.3361,001.50Ellipse Separation Pass - MPI-04 - MPI-04PB1 - MPI-04PB1165.23 1,101.50 155.79 1,096.48 17.5071,101.50Clearance Factor Pass - MPI-05 - MPI-05 - MPI-0525.36 1,208.59 17.13 1,210.60 3.0811,208.59Clearance Factor Pass - MPI-06 - MPI-06 - MPI-06104.47 1,985.84 89.64 1,918.23 7.0471,985.84Ellipse Separation Pass - MPI-06 - MPI-06 - MPI-06105.33 2,026.50 90.27 1,955.44 6.9952,026.50Clearance Factor Pass - MPI-07 - MPI-07 - MPI-07107.93 1,589.60 97.09 1,569.08 9.9621,589.60Ellipse Separation Pass - MPI-07 - MPI-07 - MPI-07108.96 1,626.50 97.88 1,601.88 9.8361,626.50Clearance Factor Pass - MPI-08 - MPI-08 - MPI-08244.65 1,168.86 236.82 1,132.59 31.2581,168.86Centre Distance Pass - MPI-08 - MPI-08 - MPI-08244.66 1,176.50 236.79 1,139.04 31.0891,176.50Ellipse Separation Pass - 06 May, 2020-14:35COMPASSPage 2 of 7 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp06Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 26.50 to 5,182.52 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-08 - MPI-08 - MPI-081,120.26 5,182.52 1,058.89 3,887.62 18.2555,182.52Clearance Factor Pass - MPI-09 - MPI-09 - MPI-0930.39 630.11 24.46 632.81 5.128630.11Ellipse Separation Pass - MPI-09 - MPI-09 - MPI-0930.56 651.50 24.56 653.82 5.087651.50Clearance Factor Pass - MPI-10 - MPI-10 - MPI-1015.56 26.50 13.72 28.75 8.42726.50Centre Distance Pass - MPI-10 - MPI-10 - MPI-1015.65 76.50 13.66 78.69 7.84576.50Ellipse Separation Pass - MPI-10 - MPI-10 - MPI-1025.91 1,376.50 15.41 1,384.90 2.4681,376.50Clearance Factor Pass - MPI-11 - MPI-11 - MPI-11282.20 460.10 278.80 455.41 82.945460.10Centre Distance Pass - MPI-11 - MPI-11 - MPI-11282.28 476.50 278.78 470.57 80.696476.50Ellipse Separation Pass - MPI-11 - MPI-11 - MPI-11412.94 2,226.50 396.58 1,988.50 25.2412,226.50Clearance Factor Pass - MPI-11 - MPI-11L1 - MPI-11L1282.20 460.10 278.80 455.41 82.945460.10Centre Distance Pass - MPI-11 - MPI-11L1 - MPI-11L1282.28 476.50 278.78 470.57 80.696476.50Ellipse Separation Pass - MPI-11 - MPI-11L1 - MPI-11L1412.94 2,226.50 396.58 1,988.50 25.2412,226.50Clearance Factor Pass - MPI-12 - MPI-12 - MPI-12299.27 1,085.17 292.18 1,049.81 42.1971,085.17Centre Distance Pass - MPI-12 - MPI-12 - MPI-12299.31 1,101.50 292.11 1,064.20 41.5861,101.50Ellipse Separation Pass - MPI-12 - MPI-12 - MPI-12616.04 2,826.50 588.45 2,456.65 22.3212,826.50Clearance Factor Pass - MPI-12 - MPI-12L1 - MPI-12L1299.27 1,085.17 292.18 1,049.81 42.1971,085.17Centre Distance Pass - MPI-12 - MPI-12L1 - MPI-12L1299.31 1,101.50 292.11 1,064.20 41.5861,101.50Ellipse Separation Pass - MPI-12 - MPI-12L1 - MPI-12L1616.04 2,826.50 588.45 2,456.65 22.3212,826.50Clearance Factor Pass - MPI-12 - MPI-12PB1 - MPI-12PB1299.27 1,085.17 292.18 1,049.81 42.1961,085.17Centre Distance Pass - MPI-12 - MPI-12PB1 - MPI-12PB1299.31 1,101.50 292.11 1,064.20 41.5851,101.50Ellipse Separation Pass - MPI-12 - MPI-12PB1 - MPI-12PB1616.04 2,826.50 588.42 2,456.65 22.3032,826.50Clearance Factor Pass - MPI-15 - MPI-15 - MPI-1540.47 26.50 38.62 28.90 21.87726.50Centre Distance Pass - MPI-15 - MPI-15 - MPI-1540.78 301.50 37.80 303.78 13.710301.50Ellipse Separation Pass - MPI-15 - MPI-15 - MPI-1544.28 426.50 40.84 428.34 12.853426.50Clearance Factor Pass - MPI-15 - MPI-15L1 - MPI-15L140.47 26.50 38.62 28.90 21.87726.50Centre Distance Pass - MPI-15 - MPI-15L1 - MPI-15L140.78 301.50 37.80 303.78 13.710301.50Ellipse Separation Pass - MPI-15 - MPI-15L1 - MPI-15L144.28 426.50 40.84 428.34 12.853426.50Clearance Factor Pass - MPI-15 - MPI-15PB1 - MPI-15PB140.47 26.50 38.62 28.90 21.87726.50Centre Distance Pass - MPI-15 - MPI-15PB1 - MPI-15PB140.78 301.50 37.80 303.78 13.710301.50Ellipse Separation Pass - MPI-15 - MPI-15PB1 - MPI-15PB144.28 426.50 40.84428.34 12.853426.50Clearance Factor Pass - 06 May, 2020-14:35COMPASSPage 3 of 7 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp06Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 26.50 to 5,182.52 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-16 - MPI-16 - MPI-1669.99 273.72 66.95 282.12 23.035273.72Centre Distance Pass - MPI-16 - MPI-16 - MPI-1670.11 301.50 66.86 309.70 21.596301.50Ellipse Separation Pass - MPI-16 - MPI-16 - MPI-16237.69 2,476.50 206.90 2,474.55 7.7192,476.50Clearance Factor Pass - MPI-17 - MPI-17 - MPI-1799.40 661.33 93.03 672.04 15.600661.33Ellipse Separation Pass - MPI-17 - MPI-17 - MPI-17435.19 4,051.50 360.00 4,394.41 5.7884,051.50Clearance Factor Pass - MPI-17 - MPI-17L1 - MPI-17L199.40 661.33 93.03 672.04 15.600661.33Ellipse Separation Pass - MPI-17 - MPI-17L1 - MPI-17L1435.19 4,051.50 360.00 4,394.41 5.7884,051.50Clearance Factor Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB199.40 661.33 93.03 672.04 15.600661.33Ellipse Separation Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1435.19 4,051.50 360.00 4,394.41 5.7884,051.50Clearance Factor Pass - MPI-17 - MPI-17L2 - MPI-17L299.40 661.33 93.03 672.04 15.600661.33Ellipse Separation Pass - MPI-17 - MPI-17L2 - MPI-17L2435.19 4,051.50 360.00 4,394.41 5.7884,051.50Clearance Factor Pass - MPI-18 - MPI-18 - MPI-18130.27 26.50 128.43 29.59 70.55026.50Centre Distance Pass - MPI-18 - MPI-18 - MPI-18130.50 101.50 128.36 103.98 61.023101.50Ellipse Separation Pass - MPI-18 - MPI-18 - MPI-18348.34 3,026.50 296.08 3,261.66 6.6663,026.50Clearance Factor Pass - MPI-19 - MPI-19 - MPI-19160.73 26.50 158.89 35.44 87.02626.50Ellipse Separation Pass - MPI-19 - MPI-19 - MPI-19192.77 1,026.50 183.96 1,036.39 21.8891,026.50Clearance Factor Pass - MPI-19 - MPI-19L1 - MPI-19L1160.73 26.50 158.89 35.44 87.02626.50Ellipse Separation Pass - MPI-19 - MPI-19L1 - MPI-19L1192.77 1,026.50 183.96 1,036.39 21.8891,026.50Clearance Factor Pass - MPI-19 - MPI-19PB1 - MPI-19PB1160.73 26.50 158.89 35.44 87.02626.50Ellipse Separation Pass - MPI-19 - MPI-19PB1 - MPI-19PB1192.77 1,026.50 183.96 1,036.39 21.8891,026.50Clearance Factor Pass - MPI-19 - MPI-19PB2 - MPI-19PB2160.73 26.50 158.89 35.44 87.02626.50Ellipse Separation Pass - MPI-19 - MPI-19PB2 - MPI-19PB2192.77 1,026.50 183.96 1,036.39 21.8891,026.50Clearance Factor Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21i wp0379.94 591.51 75.96 591.55 20.072591.51Centre Distance Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21i wp0379.97 601.50 75.94 601.22 19.831601.50Ellipse Separation Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21i wp03484.24 5,182.52 437.45 5,141.70 10.3485,182.52Clearance Factor Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp0328.51 397.34 25.40 397.69 9.190397.34Centre Distance Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp0328.51 401.50 25.39 401.80 9.133401.50Ellipse Separation Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp0376.59 1,976.50 65.69 1,941.85 7.0271,976.50Clearance Factor Pass - Plan: MPU I-27 - MPU I-27 - MPU I-27 wp03144.83 276.50 142.44 276.80 60.588276.50Centre Distance Pass - Plan: MPU I-27 - MPU I-27 - MPU I-27 wp03144.88 301.50 142.37 301.80 57.745301.50Ellipse Separation Pass - 06 May, 2020-14:35COMPASSPage 4 of 7 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp06Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 26.50 to 5,182.52 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningPlan: MPU I-27 - MPU I-27 - MPU I-27 wp031,120.08 5,182.52 1,071.13 4,910.09 22.8835,182.52Clearance Factor Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp0353.33 607.80 49.25 608.14 13.070607.80Ellipse Separation Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03262.42 5,182.52 220.33 5,006.69 6.2345,182.52Clearance Factor Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp0327.86 316.50 25.13 316.54 10.195316.50Centre Distance Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp0327.87 326.50 25.09 326.56 10.030326.50Ellipse Separation Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp0329.31 401.50 26.17 401.31 9.339401.50Clearance Factor Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i wp08114.61 276.50 112.05 276.50 44.790276.50Centre Distance Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i wp08114.66 301.50 111.99 301.50 43.027301.50Ellipse Separation Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i wp08182.60 1,576.50 173.88 1,606.36 20.9511,576.50Clearance Factor Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i114.61 26.50 112.70 26.75 59.95926.50Ellipse Separation Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i189.19 1,626.50 179.81 1,661.20 20.1611,626.50Clearance Factor Pass - Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool26.50 2,000.00 MPU I-36 wp06 3_Gyro-GC_Csg2,000.00 5,182.52 MPU I-36 wp06 3_MWD+IFR2+MS+Sag5,182.52 15,462.67 MPU I-36 wp06 3_MWD+IFR2+MS+SagEllipse error terms are correlated across survey tool tie-on points.Separation is the actual distance between ellipsoids.Calculated ellipses incorporate surface errors.Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).Distance Between centres is the straight line distance between wellbore centres.All station coordinates were calculated using the Minimum Curvature method.06 May, 2020-14:35COMPASSPage 5 of 7 0.001.002.003.004.00Separation Factor0 275 550 825 1100 1375 1650 1925 2200 2475 2750 3025 3300 3575 3850 4125 4400 4675 4950 5225Measured Depth (550 usft/in)MPI-05MPI-02MPI-10MPI-01No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU I-36 NAD 1927 (NADCON CONUS)Alaska Zone 0433.60+N/-S +E/-W Northing Easting Latittude Longitude0.000.00 6009444.08 551689.1970° 26' 11.572 N149° 34' 42.850 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-36, True NorthVertical (TVD) Reference:MPU I-36 Planned RKB @ 60.10usftMeasured Depth Reference:MPU I-36 Planned RKB @ 60.10usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-03-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 2000.00 MPU I-36 wp06 (MPU I-36) 3_Gyro-GC_Csg2000.00 5182.52 MPU I-36 wp06 (MPU I-36) 3_MWD+IFR2+MS+Sag5182.52 15462.67 MPU I-36 wp06 (MPU I-36) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 275 550 825 1100 1375 1650 1925 2200 2475 2750 3025 3300 3575 3850 4125 4400 4675 4950 5225Measured Depth (550 usft/in)MPU I-35iMPU I-35i wp08MPU I-21i wp03MPI-05MPI-17MPI-09MPI-16MPI-02MPI-10MPI-15MPI-01MPU I-29 wp03MPU I-22 wp03MPU I-28i wp03GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference26.50 To 15462.67Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-36Wellbore: MPU I-36Plan: MPU I-36 wp06Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3830.09 3769.99 5182.52 9-5/8 9 5/8" X 12 1/4"3990.10 3930.00 15462.67 6-5/8 6 5/8" X 8 1/2" 06 May, 2020Milne PointM Pt I PadPlan: MPU I-36MPU I-36MPU I-36 wp06Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp06Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Well Coordinates: 6,009,444.08 N, 551,689.19 E (70° 26' 11.57" N, 149° 34' 42.85" W)Datum Height: MPU I-36 Planned RKB @ 60.10usftScan Range: 5,182.52 to 15,462.67 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.15 Build: 91EScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftGLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referenceScan Type:Scan Type:25.00Scan Range: 5,182.52 to 15,462.67 usft. Measured Depth. Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp06Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 5,182.52 to 15,462.67 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningM Pt I PadMPI-07 - MPI-07 - MPI-071,701.86 5,182.52 1,669.97 3,851.22 53.3725,182.52Clearance Factor Pass - MPI-08 - MPI-08 - MPI-081,120.26 5,182.52 1,058.89 3,887.62 18.2555,182.52Ellipse Separation Pass - MPI-08 - MPI-08 - MPI-081,561.07 6,232.52 1,407.42 4,935.46 10.1606,232.52Clearance Factor Pass - MPI-09 - MPI-09 - MPI-09656.67 5,902.89 574.84 4,718.90 8.0255,902.89Centre Distance Pass - MPI-09 - MPI-09 - MPI-09671.57 6,107.52 559.12 4,869.59 5.9726,107.52Ellipse Separation Pass - MPI-09 - MPI-09 - MPI-09804.08 6,557.52 639.93 5,182.55 4.8996,557.52Clearance Factor Pass - MPI-12 - MPI-12 - MPI-121,735.17 5,182.52 1,671.26 3,414.30 27.1515,182.52Clearance Factor Pass - MPI-12 - MPI-12L1 - MPI-12L11,735.17 5,182.52 1,671.26 3,414.30 27.1515,182.52Clearance Factor Pass - MPI-12 - MPI-12PB1 - MPI-12PB11,735.17 5,182.52 1,671.04 3,414.30 27.0575,182.52Clearance Factor Pass - MPI-17 - MPI-17 - MPI-171,381.27 5,182.52 1,273.33 4,828.04 12.7975,182.52Clearance Factor Pass - MPI-17 - MPI-17L1 - MPI-17L11,381.27 5,182.52 1,273.33 4,828.04 12.7975,182.52Clearance Factor Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB11,381.27 5,182.52 1,273.33 4,828.04 12.7975,182.52Clearance Factor Pass - MPI-17 - MPI-17L2 - MPI-17L21,381.27 5,182.52 1,274.04 4,828.08 12.8815,182.52Clearance Factor Pass - MPI-19 - MPI-19 - MPI-19221.75 11,332.52 95.33 9,720.00 1.75411,332.52Clearance Factor Pass - MPI-19 - MPI-19 - MPI-19220.98 11,351.01 96.21 9,720.00 1.77111,351.01Centre Distance Pass - MPI-19 - MPI-19L1 - MPI-19L1189.5510,757.5250.469,145.571.36310,757.52Clearance FactorPass - MPI-19 - MPI-19L1 - MPI-19L1180.2010,857.5249.039,254.361.37410,857.52Ellipse SeparationPass - MPI-19 - MPI-19L1 - MPI-19L1150.01 11,213.32 87.27 9,604.66 2.39111,213.32Centre Distance Pass - MPI-19 - MPI-19PB1 - MPI-19PB1247.73 8,557.52 124.69 6,904.82 2.0138,557.52Clearance Factor Pass - MPI-19 - MPI-19PB1 - MPI-19PB1247.07 8,596.34 124.86 6,937.51 2.0228,596.34Centre Distance Pass - MPI-19 - MPI-19PB2 - MPI-19PB2247.73 8,557.52 124.69 6,904.82 2.0138,557.52Clearance Factor Pass - MPI-19 - MPI-19PB2 - MPI-19PB2247.07 8,596.34 124.86 6,937.51 2.0228,596.34Centre Distance Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21i wp03310.72 14,007.52 116.95 13,932.54 1.60414,007.52Clearance Factor Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21i wp03310.35 14,024.54 117.46 13,936.49 1.60914,024.54Centre Distance Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03506.44 5,249.53 458.99 5,728.71 10.6735,249.53Centre Distance Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03535.40 14,032.52 294.24 14,570.85 2.22014,032.52Ellipse Separation Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03536.83 14,057.52 294.48 14,570.85 2.21514,057.52Clearance Factor Pass - Plan: MPU I-27 - MPU I-27 - MPU I-27 wp03891.19 15,207.52 606.44 14,858.45 3.13015,207.52Clearance Factor Pass - 06 May, 2020-14:36COMPASSPage 2 of 7 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp06Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 5,182.52 to 15,462.67 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningPlan: MPU I-27 - MPU I-27 - MPU I-27 wp03890.76 15,232.52 606.33 14,858.45 3.13215,232.52Ellipse Separation Pass - Plan: MPU I-27 - MPU I-27 - MPU I-27 wp03890.76 15,235.40 606.38 14,858.45 3.13215,235.40Centre Distance Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03262.42 5,182.52 220.33 5,006.69 6.2345,182.52Centre Distance Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03270.5815,462.6725.5815,273.471.10415,462.67Clearance FactorPass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp03483.32 15,462.67 200.66 16,039.82 1.71015,462.67Clearance Factor Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i wp08765.60 15,432.52 470.00 14,768.86 2.59015,432.52Clearance Factor Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i wp08765.48 15,445.88 470.16 14,768.86 2.59215,445.88Centre Distance Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i1,230.85 5,182.52 1,201.18 3,941.10 41.4935,182.52Clearance Factor Pass - M Pt J PadMPJ-01 - MPJ-01 - MPJ-011,091.02 10,421.41 981.01 4,037.75 9.91710,421.41Centre Distance Pass - MPJ-01 - MPJ-01 - MPJ-011,091.07 10,432.52 980.97 4,042.11 9.91010,432.52Ellipse Separation Pass - MPJ-01 - MPJ-01 - MPJ-011,092.48 10,482.52 982.09 4,061.70 9.89710,482.52Clearance Factor Pass - MPJ-01 - MPJ-01A - MPJ-01A452.60 11,946.80 289.56 5,643.75 2.77611,946.80Centre Distance Pass - MPJ-01 - MPJ-01A - MPJ-01A452.87 11,982.52 289.30 5,673.30 2.76911,982.52Clearance Factor Pass - MPJ-01 - MPJ-01AL1 - MPJ-01AL1578.79 11,532.52 441.85 5,225.26 4.22711,532.52Ellipse Separation Pass - MPJ-01 - MPJ-01AL1 - MPJ-01AL1578.73 11,543.91 441.93 5,230.36 4.23011,543.91Centre Distance Pass - MPJ-01 - MPJ-01AL1 - MPJ-01AL1711.52 14,057.52 475.42 7,952.00 3.01414,057.52Clearance Factor Pass - MPJ-06 - MPJ-06 - MPJ-06765.20 10,507.52 637.74 4,444.94 6.00310,507.52Clearance Factor Pass - MPJ-06 - MPJ-06 - MPJ-06763.36 10,557.52 636.43 4,471.37 6.01410,557.52Ellipse Separation Pass - MPJ-06 - MPJ-06 - MPJ-06763.22 10,576.32 636.54 4,482.216.02510,576.32Centre Distance Pass - MPJ-08 - MPJ-08 - MPJ-0861.7910,994.81-12.064,812.170.83710,994.81Centre DistanceFAIL - MPJ-08 - MPJ-08 - MPJ-0872.0011,057.52-65.774,863.690.52311,057.52Clearance FactorFAIL - MPJ-08 - MPJ-08 - MPJ-0880.3311,082.52-71.844,884.710.52811,082.52Ellipse SeparationFAIL - MPJ-08 - MPJ-08A - MPJ-08A61.7910,994.81-12.064,812.970.83710,994.81Centre DistanceFAIL - MPJ-08 - MPJ-08A - MPJ-08A72.0111,057.52-65.144,864.460.52511,057.52Clearance FactorFAIL - MPJ-08 - MPJ-08A - MPJ-08A80.7311,082.52-68.864,882.230.54011,082.52Ellipse SeparationFAIL - MPJ-09 - MPJ-09 - MPJ-09745.80 10,521.03 652.43 4,346.71 7.98710,521.03Centre Distance Pass - MPJ-09 - MPJ-09 - MPJ-09755.83 10,657.52 641.93 4,404.50 6.63610,657.52Ellipse Separation Pass - MPJ-09 - MPJ-09 - MPJ-09977.81 11,257.52 790.87 4,822.17 5.23111,257.52Clearance Factor Pass - MPJ-09 - MPJ-09A - MPJ-09A745.80 10,521.03 652.45 4,346.98 7.98910,521.03Centre Distance Pass - 06 May, 2020-14:36COMPASSPage 3 of 7See collision noteson page 50 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp06Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 5,182.52 to 15,462.67 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-09 - MPJ-09A - MPJ-09A755.83 10,657.52 641.95 4,404.77 6.63710,657.52Ellipse Separation Pass - MPJ-09 - MPJ-09A - MPJ-09A977.81 11,257.52 790.96 4,822.44 5.23311,257.52Clearance Factor Pass - MPJ-11 - MPJ-11 - MPJ-11720.00 12,432.52 585.13 5,340.48 5.33912,432.52Clearance Factor Pass - MPJ-11 - MPJ-11 - MPJ-11718.58 12,482.52 584.21 5,376.43 5.34812,482.52Ellipse Separation Pass - MPJ-11 - MPJ-11 - MPJ-11718.45 12,503.08 584.37 5,391.71 5.35812,503.08Centre Distance Pass - MPJ-15 - MPJ-15 - MPJ-15742.88 12,460.70 564.94 5,360.72 4.17512,460.70Centre Distance Pass - MPJ-15 - MPJ-15 - MPJ-15760.52 12,707.52 540.59 5,549.43 3.45812,707.52Ellipse Separation Pass - MPJ-15 - MPJ-15 - MPJ-15849.02 13,082.52 582.58 5,831.32 3.18613,082.52Clearance Factor Pass - MPJ-16 - MPJ-16 - MPJ-16146.3412,707.52-80.375,806.960.64612,707.52Clearance FactorFAIL - MPJ-16 - MPJ-16 - MPJ-16144.6912,752.16-75.065,845.950.65812,752.16Centre DistanceFAIL - MPJ-18 - MPJ-18 - MPJ-181,021.55 10,851.52 945.46 4,236.05 13.42610,851.52Centre Distance Pass - MPJ-18 - MPJ-18 - MPJ-181,034.39 11,057.52 934.34 4,360.98 10.33911,057.52Ellipse Separation Pass - MPJ-18 - MPJ-18 - MPJ-181,443.83 12,107.52 1,238.78 5,017.83 7.04212,107.52Clearance Factor Pass - MPJ-19 - MPJ-19 - MPJ-191,056.68 9,764.68 997.26 3,915.44 17.7849,764.68Centre Distance Pass - MPJ-19 - MPJ-19 - MPJ-191,057.46 9,807.52 996.18 3,930.49 17.2559,807.52Ellipse Separation Pass - MPJ-19 - MPJ-19 - MPJ-191,259.53 10,507.52 1,168.06 4,187.54 13.76910,507.52Clearance Factor Pass - MPJ-19 - MPJ-19A - MPJ-19A1,039.66 9,836.78 971.48 4,085.50 15.2509,836.78Centre Distance Pass - MPJ-19 - MPJ-19A - MPJ-19A1,041.67 9,907.52 969.92 4,114.38 14.5189,907.52Ellipse Separation Pass - MPJ-19 - MPJ-19A - MPJ-19A1,228.74 10,557.52 1,124.82 4,427.83 11.82410,557.52Clearance Factor Pass - MPJ-22 - MPJ-22 - MPJ-22630.60 9,108.79 573.20 4,072.52 10.9869,108.79Centre Distance Pass - MPJ-22 - MPJ-22 - MPJ-22632.45 9,157.52 572.01 4,079.44 10.4649,157.52Ellipse Separation Pass - MPJ-22 - MPJ-22 - MPJ-22757.71 9,532.52 663.77 4,132.38 8.0669,532.52Clearance Factor Pass - MPJ-25 - MPJ-25 - MPJ-2534.1810,356.22-2.584,332.960.93010,356.22Centre DistanceFAIL - MPJ-25 - MPJ-25 - MPJ-2541.2610,382.52-31.114,345.370.57010,382.52Clearance FactorFAIL - MPJ-25 - MPJ-25 - MPJ-2556.5910,407.52-33.274,357.150.63010,407.52Ellipse SeparationFAIL - MPJ-25 - MPJ-25PB1 - MPJ-25PB155.5410,307.52-53.574,318.700.50910,307.52Ellipse SeparationFAIL - MPJ-25 - MPJ-25PB1 - MPJ-25PB146.6610,332.52-45.194,328.200.50810,332.52Clearance FactorFAIL - MPJ-25 - MPJ-25PB1 - MPJ-25PB145.9710,341.19-35.554,331.500.56410,341.19Centre DistanceFAIL - MPJ-26 - MPJ-26 - MPJ-26862.33 8,357.52 778.19 4,062.04 10.2498,357.52Clearance Factor Pass - MPJ-26 - MPJ-26 - MPJ-26796.63 8,657.52 726.79 4,036.45 11.4068,657.52Ellipse Separation Pass - 06 May, 2020-14:36COMPASSPage 4 of 7See notes on page 50 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp06Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 5,182.52 to 15,462.67 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-26 - MPJ-26 - MPJ-26795.85 8,692.88 727.29 4,036.45 11.6078,692.88Centre Distance Pass - MPJ-26 - MPJ-26L1 - MPJ-26L1862.33 8,357.52 778.19 4,062.04 10.2498,357.52Clearance Factor Pass - MPJ-26 - MPJ-26L1 - MPJ-26L1796.63 8,657.52 726.79 4,036.45 11.4068,657.52Ellipse Separation Pass - MPJ-26 - MPJ-26L1 - MPJ-26L1795.85 8,692.88 727.29 4,036.45 11.6078,692.88Centre Distance Pass - MPJ-26 - MPJ-26L2 - MPJ-26L2862.33 8,357.52 778.19 4,062.04 10.2498,357.52Clearance Factor Pass - MPJ-26 - MPJ-26L2 - MPJ-26L2796.63 8,657.52 726.79 4,036.45 11.4068,657.52Ellipse Separation Pass - MPJ-26 - MPJ-26L2 - MPJ-26L2795.85 8,692.88 727.29 4,036.45 11.6078,692.88Centre Distance Pass - MPJ-26 - MPJ-26PB1 - MPJ-26PB1862.33 8,357.52 778.19 4,062.04 10.2498,357.52Clearance Factor Pass - MPJ-26 - MPJ-26PB1 - MPJ-26PB1796.63 8,657.52 726.79 4,036.45 11.4068,657.52Ellipse Separation Pass - MPJ-26 - MPJ-26PB1 - MPJ-26PB1795.85 8,692.88 727.29 4,036.45 11.6078,692.88Centre Distance Pass - MPJ-26 - MPJ-26PB2 - MPJ-26PB2862.33 8,357.52 778.19 4,062.04 10.2498,357.52Clearance Factor Pass - MPJ-26 - MPJ-26PB2 - MPJ-26PB2796.63 8,657.52 726.79 4,036.45 11.4068,657.52Ellipse Separation Pass - MPJ-26 - MPJ-26PB2 - MPJ-26PB2795.85 8,692.88 727.29 4,036.45 11.6078,692.88Centre Distance Pass - Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool26.50 2,000.00 MPU I-36 wp06 3_Gyro-GC_Csg2,000.00 5,182.52 MPU I-36 wp06 3_MWD+IFR2+MS+Sag5,182.52 15,462.67 MPU I-36 wp06 3_MWD+IFR2+MS+SagEllipse error terms are correlated across survey tool tie-on points.Separation is the actual distance between ellipsoids.Calculated ellipses incorporate surface errors.Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).Distance Between centres is the straight line distance between wellbore centres.All station coordinates were calculated using the Minimum Curvature method.06 May, 2020-14:36COMPASSPage 5 of 7 0.001.002.003.004.00Separation Factor5500 6050 6600 7150 7700 8250 8800 9350 9900 10450 11000 11550 12100 12650 13200 13750 14300 14850 15400Measured Depth (1100 usft/in)No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU I-36 NAD 1927 (NADCON CONUS)Alaska Zone 0433.60+N/-S +E/-W Northing Easting Latittude Longitude0.000.006009444.08 551689.1970° 26' 11.572 N149° 34' 42.850 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-36, True NorthVertical (TVD) Reference:MPU I-36 Planned RKB @ 60.10usftMeasured Depth Reference:MPU I-36 Planned RKB @ 60.10usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-03-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 2000.00 MPU I-36 wp06 (MPU I-36) 3_Gyro-GC_Csg2000.00 5182.52 MPU I-36 wp06 (MPU I-36) 3_MWD+IFR2+MS+Sag5182.52 15462.67 MPU I-36 wp06 (MPU I-36) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)5500 6050 6600 7150 7700 8250 8800 9350 9900 10450 11000 11550 12100 12650 13200 13750 14300 14850 15400Measured Depth (1100 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference26.50 To 15462.67Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-36Wellbore: MPU I-36Plan: MPU I-36 wp06Ladder / S.F. Plots2 of 2CASING DETAILSTVD TVDSS MD Size Name3830.09 3769.99 5182.52 9-5/8 9 5/8" X 12 1/4"3990.10 3930.00 15462.67 6-5/8 6 5/8" X 8 1/2" 14 May, 2020 Plan: MPU I-36 wp07 Milne Point M Pt I Pad Plan: MPU I-36 MPU I-36 -750075015002250300037504500True Vertical Depth (1500 usft/in)-1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750Vertical Section at 6.50° (1500 usft/in)MPU I-36 (Chantilly) wp02 HeelMPU I-36 (Chantilly) wp02 CP1MPU I-36 (Chantilly) wp02 CP2MPU I-36 (Chantilly) wp02 CP3MPU I-36 (Chantilly) wp02 CP4MPU I-36 (Chantilly) wp02 Toe9 5/8" X 12 1/4"6 5/8" X 8 1/2"50010001500200025003000350040004500500055 00 60 00 650 0700075008000850090009500100001050011000115001200012500130001350014000145001500015468MPU I-36 wp07Start Dir 3º/100' : 280' MD, 280'TVDStart Dir 4º/100' : 450' MD, 449.78'TVDStart Dir 2º/100' : 577.5' MD, 577.11'TVDStart Dir 4º/100' : 1577.5' MD, 1556.92'TVDEnd Dir : 1941' MD, 1879.81' TVDStart Dir 4º/100' : 2390.55' MD, 2251.74'TVDEndDir :4882.52' MD, 3803.94'TVDStartDir4º/100':5182.52'MD, 3830.09'TVDEndDir :5336.58' MD, 3835.25'TVDStartDir3º/100':6602.44'MD, 3809.63'TVDEndDir : 6755.88' MD, 3810.1'TVDStartDir3º/100':8630.66'MD, 3859.43'TVDEndDir :8665.78' MD, 3860.09'TVDStart Dir 3º/100' : 11238.66' MD,3889.89'TVDEnd Dir: 11301.77'MD,3891.01'TVDStartDir3º/100':12501.77'MD, 3913'TVDEndDir : 12714.71' MD, 3917.75'TVDStartDir3º/100':15467.54'MD,3990.09'TVDTotal Depth:15467.77'MD,3990.1'TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Pedal CurveWarning Method: Error RatioWELL DETAILS: Plan: MPU I-3633.60+N/-S +E/-WNorthingEastingLatittudeLongitude0.000.006009444.08551689.19 70° 26' 11.572 N 149° 34' 42.850 WSURVEY PROGRAMDate: 2020-03-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool26.50 2000.00 MPU I-36 wp07 (MPU I-36) 3_Gyro-GC_Csg2000.00 5182.52 MPU I-36 wp07 (MPU I-36) 3_MWD+IFR2+MS+Sag5182.52 15467.77 MPU I-36 wp07 (MPU I-36) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSNo formation data is availableREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-36, True NorthVertical (TVD) Reference:MPU I-36 Planned RKB @ 60.10usftMeasured Depth Reference:MPU I-36 Planned RKB @ 60.10usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt I PadWell:Plan: MPU I-36Wellbore:MPU I-36Design:MPU I-36 wp07CASING DETAILSTVD TVDSS MD SizeName3830.09 3769.99 5182.52 9-5/8 9 5/8" X 12 1/4"3990.10 3930.00 15467.77 6-5/8 6 5/8" X 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.002 280.00 0.00 0.00 280.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 280' MD, 280'TVD3 450.00 5.10 340.00 449.78 7.11 -2.59 3.00 340.00 6.77 Start Dir 4º/100' : 450' MD, 449.78'TVD4 577.50 0.00 0.00 577.11 12.43 -4.53 4.00 180.00 11.84 Start Dir 2º/100' : 577.5' MD, 577.11'TVD5 1177.50 12.00 240.00 1172.73 -18.87 -58.74 2.00 240.00 -25.406 1577.50 20.00 240.00 1556.92 -73.95 -154.15 2.00 0.00 -90.92 Start Dir 4º/100' : 1577.5' MD, 1556.92'TVD7 1941.00 34.18 247.35 1879.81 -144.73 -303.00 4.00 16.63 -178.10 End Dir : 1941' MD, 1879.81' TVD8 2390.55 34.18 247.35 2251.74 -241.99 -536.04 0.00 0.00 -301.12 Start Dir 4º/100' : 2390.55' MD, 2251.74'TVD9 4882.52 85.00 2.77 3803.94 1079.72 -1334.24 4.00 114.12 921.74 End Dir : 4882.52' MD, 3803.94' TVD10 5182.52 85.00 2.77 3830.09 1378.23 -1319.80 0.00 0.00 1219.97 MPU I-36 (Chantilly) wp02 Heel Start Dir 4º/100' : 5182.52' MD, 3830.09'TVD11 5336.58 91.16 2.57 3835.25 1531.97 -1312.62 4.00 -1.82 1373.53 End Dir : 5336.58' MD, 3835.25' TVD12 6602.44 91.16 2.57 3809.63 2796.29 -1255.77 0.00 0.00 2636.16 Start Dir 3º/100' : 6602.44' MD, 3809.63'TVD13 6755.55 88.50 6.32 3810.09 2948.90 -1243.90 3.00 125.37 2789.13 MPU I-36 (Chantilly) wp02 CP1 End Dir : 6755.88' MD, 3810.1' TVD14 6755.88 88.49 6.31 3810.10 2949.22 -1243.87 3.00 -142.80 2789.45 End Dir : 6755.88' MD, 3810.1' TVD15 8630.66 88.49 6.31 3859.43 4811.98 -1037.75 0.00 0.00 4663.57 Start Dir 3º/100' : 8630.66' MD, 3859.43'TVD16 8665.58 89.34 6.93 3860.09 4846.67 -1033.73 3.00 36.00 4698.49 MPU I-36 (Chantilly) wp02 CP2 End Dir : 8665.78' MD, 3860.09' TVD17 8665.78 89.34 6.93 3860.09 4846.86 -1033.70 3.00 -129.38 4698.69 End Dir : 8665.78' MD, 3860.09' TVD18 11238.66 89.34 6.93 3889.89 7400.80 -723.49 0.00 0.00 7271.33 Start Dir 3º/100' : 11238.66' MD, 3889.89'TVD19 11251.78 88.95 7.00 3890.09 7413.82 -721.90 3.00 169.09 7284.44 MPU I-36 (Chantilly) wp02 CP320 11301.77 88.95 5.50 3891.01 7463.50 -716.46 3.00 -90.01 7334.42 End Dir : 11301.77' MD, 3891.01' TVD21 12501.77 88.95 5.50 3913.00 8657.78 -601.46 0.00 0.00 8534.04 Start Dir 3º/100' : 12501.77' MD, 3913'TVD22 12714.71 88.49 11.87 3917.75 8868.12 -569.33 3.00 94.16 8746.66 End Dir : 12714.71' MD, 3917.75' TVD23 15467.54 88.49 11.87 3990.09 11561.11 -3.12 0.000.0011486.44 Start Dir 3º/100' : 15467.54' MD, 3990.09'TVD24 15467.77 88.50 11.87 3990.10 11561.34 -3.07 3.00 -31.73 11486.67 MPU I-36 (Chantilly) wp02 Toe Start Dir 3º/100' : 15467.54' MD, 3990.09'TVD -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 South(-)/North(+) (1500 usft/in)-6000 -5250 -4500 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 West(-)/East(+) (1500 usft/in) MPU I-36 (Chantilly) wp02 Toe MPU I-36 (Chantilly) wp02 CP4 MPU I-36 (Chantilly) wp02 CP3 MPU I-36 (Chantilly) wp02 CP2 MPU I-36 (Chantilly) wp02 CP1 MPU I-36 (Chantilly) wp02 Heel 9 5/8" X 12 1/4" 6 5/8" X 8 1/2" 1 0 0 017 502250250030003 5 0 0 3 7 5 0 3990 MPU I-36 wp07 Start Dir 3º/100' : 280' MD, 280'TVD Start Dir 4º/100' : 450' MD, 449.78'TVD Start Dir 2º/100' : 577.5' MD, 577.11'TVD Start Dir 4º/100' : 1577.5' MD, 1556.92'TVD End Dir : 1941' MD, 1879.81' TVD Start Dir 4º/100' : 2390.55' MD, 2251.74'TVD End Dir : 4882.52' MD, 3803.94' TVD Start Dir 4º/100' : 5182.52' MD, 3830.09'TVD End Dir : 5336.58' MD, 3835.25' TVD Start Dir 3º/100' : 6602.44' MD, 3809.63'TVD End Dir : 6755.88' MD, 3810.1' TVD Start Dir 3º/100' : 8630.66' MD, 3859.43'TVD End Dir : 8665.78' MD, 3860.09' TVD Start Dir 3º/100' : 11238.66' MD, 3889.89'TVD End Dir : 11301.77' MD, 3891.01' TVD Start Dir 3º/100' : 12501.77' MD, 3913'TVD End Dir : 12714.71' MD, 3917.75' TVD Start Dir 3º/100' : 15467.54' MD, 3990.09'TVD Total Depth : 15467.77' MD, 3990.1' TVD CASING DETAILS TVD TVDSS MD Size Name 3830.09 3769.99 5182.52 9-5/8 9 5/8" X 12 1/4" 3990.10 3930.00 15467.77 6-5/8 6 5/8" X 8 1/2" Project: Milne Point Site: M Pt I Pad Well: Plan: MPU I-36 Wellbore: MPU I-36 Plan: MPU I-36 wp07 WELL DETAILS: Plan: MPU I-36 33.60+N/-S +E/-W Northing Easting Latittude Longitude0.00 0.00 6009444.08 551689.19 70° 26' 11.572 N 149° 34' 42.850 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPU I-36, True North Vertical (TVD) Reference:MPU I-36 Planned RKB @ 60.10usft Measured Depth Reference:MPU I-36 Planned RKB @ 60.10usft Calculation Method:Minimum Curvature Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp07 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: From: Site Latitude: Longitude: Position Uncertainty: Northing: Easting: Grid Convergence: M Pt I Pad, TR-13-10 usft Map usft usft °0.39Slot Radius:"0 6,008,388.01 550,245.83 0.00 70° 26' 1.282 N 149° 35' 25.422 W Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: Plan: MPU I-36, Slot I-26 usft usft 0.00 0.00 6,009,444.08 551,689.19 33.60Wellhead Elevation:33.60 usft0.50 70° 26' 11.572 N 149° 34' 42.850 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-36 Model NameMagnetics BGGM2019 4/23/2020 16.00 80.85 57,377.73369478 Phase:Version: Audit Notes: Design MPU I-36 wp07 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:26.50 6.500.000.0026.50 5/14/2020 7:03:00PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp07 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Inclination (°) Azimuth (°) +E/-W (usft) Tool Face (°) +N/-S (usft) Measured Depth (usft) Vertical Depth (usft) Dogleg Rate (°/100usft) Build Rate (°/100usft) Turn Rate (°/100usft) Plan Sections TVD System usft 0.000.000.000.000.000.0026.500.000.0026.50 -33.60 0.000.000.000.000.000.00280.000.000.00280.00 219.90 340.000.003.003.00-2.597.11449.78340.005.10450.00 389.68 180.000.00-4.004.00-4.5312.43577.110.000.00577.50 517.01 240.000.002.002.00-58.74-18.871,172.73240.0012.001,177.50 1,112.63 0.000.002.002.00-154.15-73.951,556.92240.0020.001,577.50 1,496.82 16.632.023.904.00-303.00-144.731,879.81247.3534.181,941.00 1,819.71 0.000.000.000.00-536.04-241.992,251.74247.3534.182,390.55 2,191.64 114.124.632.044.00-1,334.241,079.723,803.942.7785.004,882.52 3,743.84 0.000.000.000.00-1,319.801,378.233,830.092.7785.005,182.52 3,769.99 -1.82-0.134.004.00-1,312.621,531.973,835.252.5791.165,336.58 3,775.15 0.000.000.000.00-1,255.772,796.293,809.632.5791.166,602.44 3,749.53 125.372.45-1.743.00-1,243.902,948.903,810.096.3288.506,755.55 3,749.99 -142.80-1.81-2.393.00-1,243.872,949.223,810.106.3188.496,755.88 3,750.00 0.000.000.000.00-1,037.754,811.983,859.436.3188.498,630.66 3,799.33 36.001.762.433.00-1,033.734,846.673,860.096.9389.348,665.58 3,799.99 -129.38-2.32-1.903.00-1,033.704,846.863,860.096.9389.348,665.78 3,799.99 0.000.000.000.00-723.497,400.803,889.896.9389.3411,238.66 3,829.79 169.090.57-2.953.00-721.907,413.823,890.097.0088.9511,251.78 3,829.99 -90.01-3.000.003.00-716.467,463.503,891.015.5088.9511,301.77 3,830.91 0.000.000.000.00-601.468,657.783,913.005.5088.9512,501.77 3,852.90 94.162.99-0.213.00-569.338,868.123,917.7511.8788.4912,714.71 3,857.65 0.000.000.000.00-3.1211,561.113,990.0911.8788.4915,467.54 3,929.99 -31.73-1.582.553.00-3.0711,561.343,990.1011.8788.5015,467.77 3,930.00 5/14/2020 7:03:00PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp07 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS -33.60 Vert Section 26.50 0.00 26.50 0.00 0.000.00 551,689.196,009,444.08-33.60 0.00 0.00 100.00 0.00 100.00 0.00 0.000.00 551,689.196,009,444.0839.90 0.00 0.00 200.00 0.00 200.00 0.00 0.000.00 551,689.196,009,444.08139.90 0.00 0.00 280.00 0.00 280.00 0.00 0.000.00 551,689.196,009,444.08219.90 0.00 0.00 Start Dir 3º/100' : 280' MD, 280'TVD 300.00 0.60 300.00 0.10 -0.04340.00 551,689.156,009,444.18239.90 3.00 0.09 400.00 3.60 399.92 3.54 -1.29340.00 551,687.886,009,447.61339.82 3.00 3.37 450.00 5.10 449.78 7.11 -2.59340.00 551,686.566,009,451.17389.68 3.00 6.77 Start Dir 4º/100' : 450' MD, 449.78'TVD 500.00 3.10 499.65 10.46 -3.81340.00 551,685.316,009,454.52439.55 4.00 9.97 577.50 0.00 577.11 12.43 -4.530.00 551,684.586,009,456.48517.01 4.00 11.84 Start Dir 2º/100' : 577.5' MD, 577.11'TVD 600.00 0.45 599.61 12.39 -4.60240.00 551,684.506,009,456.44539.51 2.00 11.79 700.00 2.45 699.57 11.12 -6.79240.00 551,682.326,009,455.16639.47 2.00 10.28 800.00 4.45 799.38 8.12 -12.00240.00 551,677.136,009,452.11739.28 2.00 6.70 900.00 6.45 898.93 3.37 -20.23240.00 551,668.946,009,447.31838.83 2.00 1.06 1,000.00 8.45 998.08 -3.12 -31.46240.00 551,657.766,009,440.75937.98 2.00 -6.66 1,100.00 10.45 1,096.72 -11.32 -45.68240.00 551,643.606,009,432.441,036.62 2.00 -16.42 1,177.50 12.00 1,172.73 -18.87 -58.74240.00 551,630.596,009,424.811,112.63 2.00 -25.40 1,200.00 12.45 1,194.72 -21.25 -62.87240.00 551,626.486,009,422.401,134.62 2.00 -28.23 1,300.00 14.45 1,291.97 -32.88 -83.01240.00 551,606.426,009,410.631,231.87 2.00 -42.06 1,400.00 16.45 1,388.35 -46.20 -106.08240.00 551,583.446,009,397.151,328.25 2.00 -57.91 1,500.00 18.45 1,483.75 -61.19 -132.05240.00 551,557.586,009,381.981,423.65 2.00 -75.75 1,577.50 20.00 1,556.92 -73.95 -154.15240.00 551,535.576,009,369.071,496.82 2.00 -90.92 Start Dir 4º/100' : 1577.5' MD, 1556.92'TVD 1,600.00 20.86 1,578.01 -77.83 -160.97240.72 551,528.776,009,365.141,517.91 4.00 -95.56 1,700.00 24.73 1,670.18 -95.93 -195.22243.35 551,494.666,009,346.811,610.08 4.00 -117.42 1,800.00 28.64 1,759.51 -115.34 -235.70245.30 551,454.326,009,327.121,699.41 4.00 -141.28 1,900.00 32.56 1,845.57 -135.95 -282.23246.82 551,407.946,009,306.191,785.47 4.00 -167.03 1,941.00 34.18 1,879.81 -144.73 -303.00247.35 551,387.236,009,297.261,819.71 4.00 -178.10 End Dir : 1941' MD, 1879.81' TVD 2,000.00 34.18 1,928.62 -157.50 -333.58247.35 551,356.746,009,284.291,868.52 0.00 -194.25 2,100.00 34.18 2,011.36 -179.13 -385.42247.35 551,305.056,009,262.301,951.26 0.00 -221.61 2,200.00 34.18 2,094.09 -200.77 -437.26247.35 551,253.376,009,240.312,033.99 0.00 -248.98 2,300.00 34.18 2,176.82 -222.40 -489.10247.35 551,201.696,009,218.322,116.72 0.00 -276.34 2,390.55 34.18 2,251.73 -241.99 -536.04247.35 551,154.896,009,198.402,191.63 0.00 -301.12 Start Dir 4º/100' : 2390.55' MD, 2251.74'TVD 2,400.00 34.02 2,259.56 -244.01 -540.94247.96 551,150.006,009,196.352,199.46 4.00 -303.67 2,500.00 32.60 2,343.16 -261.58 -592.89254.78 551,098.186,009,178.422,283.06 4.00 -327.02 2,600.00 31.58 2,427.91 -272.28 -644.84262.06 551,046.316,009,167.362,367.81 4.00 -343.53 2,700.00 30.99 2,513.40 -276.04 -696.53269.68 550,994.656,009,163.252,453.30 4.00 -353.12 2,800.00 30.86 2,599.23 -272.85 -747.72277.47 550,943.456,009,166.082,539.13 4.00 -355.74 2,900.00 31.19 2,684.96 -262.72 -798.16285.21 550,892.956,009,175.862,624.86 4.00 -351.39 3,000.00 31.97 2,770.18 -245.71 -847.59292.70 550,843.416,009,192.532,710.08 4.00 -340.08 3,100.00 33.18 2,854.48 -221.89 -895.78299.79 550,795.066,009,216.012,794.38 4.00 -321.86 5/14/2020 7:03:00PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp07 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 2,877.34 Vert Section 3,200.00 34.75 2,937.44 -191.38 -942.49306.37 550,748.146,009,246.192,877.34 4.00 -296.84 3,300.00 36.66 3,018.67 -154.33 -987.50312.40 550,702.876,009,282.932,958.57 4.00 -265.13 3,400.00 38.84 3,097.76 -110.92 -1,030.59317.89 550,659.496,009,326.033,037.66 4.00 -226.87 3,500.00 41.25 3,174.32 -61.36 -1,071.54322.85 550,618.206,009,375.303,114.22 4.00 -182.27 3,600.00 43.86 3,248.00 -5.90 -1,110.17327.34 550,579.206,009,430.493,187.90 4.00 -131.54 3,700.00 46.62 3,318.43 55.20 -1,146.27331.41 550,542.686,009,491.333,258.33 4.00 -74.92 3,800.00 49.52 3,385.26 121.64 -1,179.67335.12 550,508.826,009,557.533,325.16 4.00 -12.69 3,900.00 52.52 3,448.16 193.09 -1,210.21338.52 550,477.786,009,628.763,388.06 4.00 54.85 4,000.00 55.62 3,506.85 269.21 -1,237.75341.65 550,449.726,009,704.683,446.75 4.00 127.36 4,100.00 58.79 3,561.01 349.62 -1,262.14344.55 550,424.786,009,784.923,500.91 4.00 204.50 4,200.00 62.02 3,610.40 433.94 -1,283.27347.27 550,403.066,009,869.083,550.30 4.00 285.88 4,300.00 65.30 3,654.78 521.76 -1,301.04349.82 550,384.696,009,956.763,594.68 4.00 371.12 4,400.00 68.62 3,693.92 612.64 -1,315.36352.24 550,369.746,010,047.533,633.82 4.00 459.80 4,500.00 71.97 3,727.63 706.14 -1,326.16354.56 550,358.306,010,140.943,667.53 4.00 551.48 4,600.00 75.35 3,755.76 801.81 -1,333.38356.79 550,350.426,010,236.553,695.66 4.00 645.71 4,700.00 78.76 3,778.16 899.18 -1,336.99358.95 550,346.136,010,333.893,718.06 4.00 742.05 4,800.00 82.17 3,794.73 997.78 -1,336.981.06 550,345.456,010,432.473,734.63 4.00 840.01 4,882.52 85.00 3,803.94 1,079.72 -1,334.242.77 550,347.636,010,514.433,743.84 4.00 921.74 End Dir : 4882.52' MD, 3803.94' TVD 4,900.00 85.00 3,805.47 1,097.12 -1,333.402.77 550,348.356,010,531.823,745.37 0.00 939.12 5,000.00 85.00 3,814.18 1,196.62 -1,328.592.77 550,352.476,010,631.353,754.08 0.00 1,038.53 5,100.00 85.00 3,822.90 1,296.12 -1,323.772.77 550,356.606,010,730.873,762.80 0.00 1,137.94 5,182.52 85.00 3,830.09 1,378.23 -1,319.802.77 550,360.006,010,813.003,769.99 0.00 1,219.97 Start Dir 4º/100' : 5182.52' MD, 3830.09'TVD - 9 5/8" X 12 1/4" 5,200.00 85.70 3,831.51 1,395.64 -1,318.962.75 550,360.726,010,830.413,771.41 4.00 1,237.35 5,300.00 89.70 3,835.52 1,495.42 -1,314.282.62 550,364.706,010,930.223,775.42 4.00 1,337.03 5,336.58 91.16 3,835.25 1,531.97 -1,312.622.57 550,366.116,010,966.763,775.15 4.00 1,373.52 End Dir : 5336.58' MD, 3835.25' TVD 5,400.00 91.16 3,833.97 1,595.31 -1,309.782.57 550,368.526,011,030.123,773.87 0.00 1,436.78 5,500.00 91.16 3,831.94 1,695.19 -1,305.282.57 550,372.326,011,130.023,771.84 0.00 1,536.53 5,600.00 91.16 3,829.92 1,795.07 -1,300.792.57 550,376.116,011,229.913,769.82 0.00 1,636.27 5,700.00 91.16 3,827.90 1,894.94 -1,296.302.57 550,379.916,011,329.813,767.80 0.00 1,736.02 5,800.00 91.16 3,825.87 1,994.82 -1,291.812.57 550,383.716,011,429.713,765.77 0.00 1,835.76 5,900.00 91.16 3,823.85 2,094.70 -1,287.322.57 550,387.516,011,529.613,763.75 0.00 1,935.51 6,000.00 91.16 3,821.83 2,194.58 -1,282.832.57 550,391.316,011,629.503,761.73 0.00 2,035.25 6,100.00 91.16 3,819.80 2,294.46 -1,278.342.57 550,395.116,011,729.403,759.70 0.00 2,135.00 6,200.00 91.16 3,817.78 2,394.34 -1,273.852.57 550,398.906,011,829.303,757.68 0.00 2,234.74 6,300.00 91.16 3,815.75 2,494.22 -1,269.362.57 550,402.706,011,929.203,755.65 0.00 2,334.49 6,400.00 91.16 3,813.73 2,594.09 -1,264.862.57 550,406.506,012,029.093,753.63 0.00 2,434.23 6,500.00 91.16 3,811.71 2,693.97 -1,260.372.57 550,410.306,012,128.993,751.61 0.00 2,533.98 6,602.44 91.16 3,809.63 2,796.29 -1,255.772.57 550,414.196,012,231.333,749.53 0.00 2,636.16 Start Dir 3º/100' : 6602.44' MD, 3809.63'TVD 6,700.00 89.46 3,809.10 2,893.63 -1,249.364.96 550,419.926,012,328.703,749.00 3.00 2,733.59 6,755.55 88.50 3,810.09 2,948.90 -1,243.906.32 550,425.006,012,384.003,749.99 3.00 2,789.13 5/14/2020 7:03:00PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp07 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 3,750.00 Vert Section 6,755.88 88.49 3,810.10 2,949.22 -1,243.876.31 550,425.036,012,384.333,750.00 2.97 2,789.46 End Dir : 6755.88' MD, 3810.1' TVD 6,800.00 88.49 3,811.26 2,993.06 -1,239.026.31 550,429.586,012,428.193,751.16 0.00 2,833.56 6,900.00 88.49 3,813.89 3,092.42 -1,228.026.31 550,439.886,012,527.623,753.79 0.00 2,933.53 7,000.00 88.49 3,816.52 3,191.78 -1,217.036.31 550,450.196,012,627.043,756.42 0.00 3,033.49 7,100.00 88.49 3,819.15 3,291.14 -1,206.046.31 550,460.496,012,726.463,759.05 0.00 3,133.45 7,200.00 88.49 3,821.78 3,390.50 -1,195.046.31 550,470.806,012,825.883,761.68 0.00 3,233.42 7,300.00 88.49 3,824.42 3,489.86 -1,184.056.31 550,481.106,012,925.313,764.32 0.00 3,333.38 7,400.00 88.49 3,827.05 3,589.21 -1,173.056.31 550,491.416,013,024.733,766.95 0.00 3,433.35 7,500.00 88.49 3,829.68 3,688.57 -1,162.066.31 550,501.716,013,124.153,769.58 0.00 3,533.31 7,600.00 88.49 3,832.31 3,787.93 -1,151.066.31 550,512.016,013,223.583,772.21 0.00 3,633.28 7,700.00 88.49 3,834.94 3,887.29 -1,140.076.31 550,522.326,013,323.003,774.84 0.00 3,733.24 7,800.00 88.49 3,837.57 3,986.65 -1,129.086.31 550,532.626,013,422.423,777.47 0.00 3,833.21 7,900.00 88.49 3,840.20 4,086.01 -1,118.086.31 550,542.936,013,521.853,780.10 0.00 3,933.17 8,000.00 88.49 3,842.83 4,185.37 -1,107.096.31 550,553.236,013,621.273,782.73 0.00 4,033.14 8,100.00 88.49 3,845.47 4,284.73 -1,096.096.31 550,563.536,013,720.693,785.37 0.00 4,133.10 8,200.00 88.49 3,848.10 4,384.09 -1,085.106.31 550,573.846,013,820.123,788.00 0.00 4,233.07 8,300.00 88.49 3,850.73 4,483.45 -1,074.116.31 550,584.146,013,919.543,790.63 0.00 4,333.03 8,400.00 88.49 3,853.36 4,582.80 -1,063.116.31 550,594.456,014,018.963,793.26 0.00 4,433.00 8,500.00 88.49 3,855.99 4,682.16 -1,052.126.31 550,604.756,014,118.393,795.89 0.00 4,532.96 8,600.00 88.49 3,858.62 4,781.52 -1,041.126.31 550,615.056,014,217.813,798.52 0.00 4,632.93 8,630.66 88.49 3,859.43 4,811.99 -1,037.756.31 550,618.216,014,248.293,799.33 0.00 4,663.58 Start Dir 3º/100' : 8630.66' MD, 3859.43'TVD 8,665.58 89.34 3,860.09 4,846.67 -1,033.736.93 550,622.006,014,283.003,799.99 3.00 4,698.49 8,665.78 89.34 3,860.09 4,846.86 -1,033.706.93 550,622.026,014,283.193,799.99 2.95 4,698.69 End Dir : 8665.78' MD, 3860.09' TVD 8,700.00 89.34 3,860.49 4,880.83 -1,029.586.93 550,625.916,014,317.193,800.39 0.00 4,732.91 8,800.00 89.34 3,861.65 4,980.10 -1,017.526.93 550,637.286,014,416.523,801.55 0.00 4,832.90 8,900.00 89.34 3,862.81 5,079.36 -1,005.466.93 550,648.656,014,515.863,802.71 0.00 4,932.89 9,000.00 89.34 3,863.96 5,178.62 -993.416.93 550,660.026,014,615.193,803.86 0.00 5,032.88 9,100.00 89.34 3,865.12 5,277.89 -981.356.93 550,671.386,014,714.533,805.02 0.00 5,132.87 9,200.00 89.34 3,866.28 5,377.15 -969.296.93 550,682.756,014,813.863,806.18 0.00 5,232.86 9,300.00 89.34 3,867.44 5,476.42 -957.236.93 550,694.126,014,913.203,807.34 0.00 5,332.85 9,400.00 89.34 3,868.60 5,575.68 -945.186.93 550,705.496,015,012.533,808.50 0.00 5,432.84 9,500.00 89.34 3,869.76 5,674.94 -933.126.93 550,716.856,015,111.873,809.66 0.00 5,532.83 9,600.00 89.34 3,870.91 5,774.21 -921.066.93 550,728.226,015,211.203,810.81 0.00 5,632.82 9,700.00 89.34 3,872.07 5,873.47 -909.016.93 550,739.596,015,310.543,811.97 0.00 5,732.81 9,800.00 89.34 3,873.23 5,972.73 -896.956.93 550,750.966,015,409.883,813.13 0.00 5,832.80 9,900.00 89.34 3,874.39 6,072.00 -884.896.93 550,762.336,015,509.213,814.29 0.00 5,932.79 10,000.00 89.34 3,875.55 6,171.26 -872.836.93 550,773.696,015,608.553,815.45 0.00 6,032.78 10,100.00 89.34 3,876.70 6,270.52 -860.786.93 550,785.066,015,707.883,816.60 0.00 6,132.77 10,200.00 89.34 3,877.86 6,369.79 -848.726.93 550,796.436,015,807.223,817.76 0.00 6,232.76 10,300.00 89.34 3,879.02 6,469.05 -836.666.93 550,807.806,015,906.553,818.92 0.00 6,332.76 10,400.00 89.34 3,880.18 6,568.32 -824.616.93 550,819.166,016,005.893,820.08 0.00 6,432.75 10,500.00 89.34 3,881.34 6,667.58 -812.556.93 550,830.536,016,105.223,821.24 0.00 6,532.74 5/14/2020 7:03:00PM COMPASS 5000.15 Build 91E Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp07 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 3,822.40 Vert Section 10,600.00 89.34 3,882.50 6,766.84 -800.496.93 550,841.906,016,204.563,822.40 0.00 6,632.73 10,700.00 89.34 3,883.65 6,866.11 -788.446.93 550,853.276,016,303.893,823.55 0.00 6,732.72 10,800.00 89.34 3,884.81 6,965.37 -776.386.93 550,864.636,016,403.233,824.71 0.00 6,832.71 10,900.00 89.34 3,885.97 7,064.63 -764.326.93 550,876.006,016,502.563,825.87 0.00 6,932.70 11,000.00 89.34 3,887.13 7,163.90 -752.266.93 550,887.376,016,601.903,827.03 0.00 7,032.69 11,100.00 89.34 3,888.29 7,263.16 -740.216.93 550,898.746,016,701.233,828.19 0.00 7,132.68 11,200.00 89.34 3,889.45 7,362.43 -728.156.93 550,910.116,016,800.573,829.35 0.00 7,232.67 11,238.66 89.34 3,889.89 7,400.80 -723.496.93 550,914.506,016,838.973,829.79 0.00 7,271.33 Start Dir 3º/100' : 11238.66' MD, 3889.89'TVD 11,251.78 88.95 3,890.09 7,413.82 -721.907.00 550,916.006,016,852.003,829.99 3.00 7,284.44 11,301.77 88.95 3,891.01 7,463.51 -716.465.50 550,921.106,016,901.723,830.91 3.00 7,334.42 End Dir : 11301.77' MD, 3891.01' TVD 11,400.00 88.95 3,892.81 7,561.27 -707.045.50 550,929.836,016,999.533,832.71 0.00 7,432.62 11,500.00 88.95 3,894.64 7,660.79 -697.465.50 550,938.726,017,099.113,834.54 0.00 7,532.59 11,600.00 88.95 3,896.47 7,760.31 -687.885.50 550,947.626,017,198.693,836.37 0.00 7,632.56 11,700.00 88.95 3,898.30 7,859.84 -678.295.50 550,956.516,017,298.263,838.20 0.00 7,732.53 11,800.00 88.95 3,900.14 7,959.36 -668.715.50 550,965.406,017,397.843,840.04 0.00 7,832.49 11,900.00 88.95 3,901.97 8,058.88 -659.135.50 550,974.296,017,497.423,841.87 0.00 7,932.46 12,000.00 88.95 3,903.80 8,158.40 -649.555.50 550,983.186,017,597.003,843.70 0.00 8,032.43 12,100.00 88.95 3,905.63 8,257.93 -639.965.50 550,992.086,017,696.573,845.53 0.00 8,132.40 12,200.00 88.95 3,907.47 8,357.45 -630.385.50 551,000.976,017,796.153,847.37 0.00 8,232.37 12,300.00 88.95 3,909.30 8,456.97 -620.805.50 551,009.866,017,895.733,849.20 0.00 8,332.33 12,400.00 88.95 3,911.13 8,556.50 -611.215.50 551,018.756,017,995.313,851.03 0.00 8,432.30 12,501.77 88.95 3,913.00 8,657.78 -601.465.50 551,027.806,018,096.653,852.90 0.00 8,534.04 Start Dir 3º/100' : 12501.77' MD, 3913'TVD 12,600.00 88.74 3,914.98 8,755.25 -589.558.44 551,039.046,018,194.193,854.88 3.00 8,632.24 12,700.00 88.53 3,917.37 8,853.71 -572.3011.43 551,055.616,018,292.763,857.27 3.00 8,732.02 12,714.71 88.49 3,917.75 8,868.12 -569.3311.87 551,058.486,018,307.183,857.65 3.00 8,746.66 End Dir : 12714.71' MD, 3917.75' TVD 12,800.00 88.49 3,919.99 8,951.55 -551.7811.87 551,075.446,018,390.733,859.89 0.00 8,831.55 12,900.00 88.49 3,922.62 9,049.38 -531.2211.87 551,095.336,018,488.683,862.52 0.00 8,931.07 13,000.00 88.49 3,925.25 9,147.21 -510.6511.87 551,115.216,018,586.643,865.15 0.00 9,030.60 13,100.00 88.49 3,927.88 9,245.03 -490.0811.87 551,135.106,018,684.603,867.78 0.00 9,130.13 13,200.00 88.49 3,930.50 9,342.86 -469.5111.87 551,154.996,018,782.563,870.40 0.00 9,229.65 13,300.00 88.49 3,933.13 9,440.69 -448.9411.87 551,174.886,018,880.513,873.03 0.00 9,329.18 13,400.00 88.49 3,935.76 9,538.51 -428.3711.87 551,194.766,018,978.473,875.66 0.00 9,428.70 13,500.00 88.49 3,938.39 9,636.34 -407.8111.87 551,214.656,019,076.433,878.29 0.00 9,528.23 13,600.00 88.49 3,941.02 9,734.17 -387.2411.87 551,234.546,019,174.383,880.92 0.00 9,627.76 13,700.00 88.49 3,943.64 9,831.99 -366.6711.87 551,254.436,019,272.343,883.54 0.00 9,727.28 13,800.00 88.49 3,946.27 9,929.82 -346.1011.87 551,274.326,019,370.303,886.17 0.00 9,826.81 13,900.00 88.49 3,948.90 10,027.65 -325.5311.87 551,294.206,019,468.263,888.80 0.00 9,926.33 14,000.00 88.49 3,951.53 10,125.47 -304.9611.87 551,314.096,019,566.213,891.43 0.00 10,025.86 14,100.00 88.49 3,954.16 10,223.30 -284.4011.87 551,333.986,019,664.173,894.06 0.00 10,125.39 14,200.00 88.49 3,956.78 10,321.13 -263.8311.87 551,353.876,019,762.133,896.68 0.00 10,224.91 14,300.00 88.49 3,959.41 10,418.95 -243.2611.87 551,373.766,019,860.093,899.31 0.00 10,324.44 5/14/2020 7:03:00PM COMPASS 5000.15 Build 91E Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp07 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 3,901.94 Vert Section 14,400.00 88.49 3,962.04 10,516.78 -222.6911.87 551,393.646,019,958.043,901.94 0.00 10,423.97 14,500.00 88.49 3,964.67 10,614.60 -202.1211.87 551,413.536,020,056.003,904.57 0.00 10,523.49 14,600.00 88.49 3,967.30 10,712.43 -181.5511.87 551,433.426,020,153.963,907.20 0.00 10,623.02 14,700.00 88.49 3,969.92 10,810.26 -160.9911.87 551,453.316,020,251.913,909.82 0.00 10,722.54 14,800.00 88.49 3,972.55 10,908.08 -140.4211.87 551,473.206,020,349.873,912.45 0.00 10,822.07 14,900.00 88.49 3,975.18 11,005.91 -119.8511.87 551,493.086,020,447.833,915.08 0.00 10,921.60 15,000.00 88.49 3,977.81 11,103.74 -99.2811.87 551,512.976,020,545.793,917.71 0.00 11,021.12 15,100.00 88.49 3,980.44 11,201.56 -78.7111.87 551,532.866,020,643.743,920.34 0.00 11,120.65 15,200.00 88.49 3,983.06 11,299.39 -58.1411.87 551,552.756,020,741.703,922.96 0.00 11,220.17 15,300.00 88.49 3,985.69 11,397.22 -37.5811.87 551,572.636,020,839.663,925.59 0.00 11,319.70 15,400.00 88.49 3,988.32 11,495.04 -17.0111.87 551,592.526,020,937.623,928.22 0.00 11,419.23 15,467.54 88.49 3,990.09 11,561.12 -3.1211.87 551,605.956,021,003.783,929.99 0.00 11,486.45 Start Dir 3º/100' : 15467.54' MD, 3990.09'TVD 15,467.77 88.50 3,990.10 11,561.34 -3.0711.87 551,606.006,021,004.003,930.00 3.03 11,486.67 Total Depth : 15467.77' MD, 3990.1' TVD Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Tar gets Dip Angle (°) Dip Dir. (°) MPU I-36 (Chantilly) wp02 Heel 3,830.09 6,010,813.00 550,360.001,378.23 -1,319.800.00 0.00 -plan hits target center - Circle (radius 30.00) MPU I-36 (Chantilly) wp02 CP2 3,860.09 6,014,283.00 550,622.004,846.67 -1,033.730.00 0.00 -plan hits target center - Point MPU I-36 (Chantilly) wp02 CP4 3,940.09 6,019,537.00 551,342.0010,096.06 -277.260.00 0.00 -plan misses target center by 34.89usft at 13976.63usft MD (3950.91 TVD, 10102.61 N, -309.77 E) - Point MPU I-36 (Chantilly) wp02 Toe 3,990.10 6,021,004.00 551,606.0011,561.34 -3.070.00 0.00 -plan hits target center - Point MPU I-36 (Chantilly) wp02 CP1 3,810.09 6,012,384.00 550,425.002,948.90 -1,243.900.00 0.00 -plan hits target center - Point MPU I-36 (Chantilly) wp02 CP3 3,890.09 6,016,852.00 550,916.007,413.82 -721.900.00 0.00 -plan hits target center - Point Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 6 5/8" X 8 1/2"3,990.1015,467.77 6-5/8 8-1/2 9 5/8" X 12 1/4"3,830.095,182.52 9-5/8 12-1/4 5/14/2020 7:03:00PM COMPASS 5000.15 Build 91E Page 8 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-36 MPU I-36 Survey Calculation Method:Minimum Curvature MPU I-36 Planned RKB @ 60.10usft Design:MPU I-36 wp07 Database:NORTH US + CANADA MD Reference:MPU I-36 Planned RKB @ 60.10usft North Reference: Well Plan: MPU I-36 True Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 280.00 280.00 0.00 0.00 Start Dir 3º/100' : 280' MD, 280'TVD 450.00 449.78 7.11 -2.59 Start Dir 4º/100' : 450' MD, 449.78'TVD 577.50 577.11 12.43 -4.53 Start Dir 2º/100' : 577.5' MD, 577.11'TVD 1,577.50 1,556.92 -73.95 -154.15 Start Dir 4º/100' : 1577.5' MD, 1556.92'TVD 1,941.00 1,879.81 -144.73 -303.00 End Dir : 1941' MD, 1879.81' TVD 2,390.55 2,251.73 -241.99 -536.04 Start Dir 4º/100' : 2390.55' MD, 2251.74'TVD 4,882.52 3,803.94 1,079.72 -1,334.24 End Dir : 4882.52' MD, 3803.94' TVD 5,182.52 3,830.09 1,378.23 -1,319.80 Start Dir 4º/100' : 5182.52' MD, 3830.09'TVD 5,336.58 3,835.25 1,531.97 -1,312.62 End Dir : 5336.58' MD, 3835.25' TVD 6,602.44 3,809.63 2,796.29 -1,255.77 Start Dir 3º/100' : 6602.44' MD, 3809.63'TVD 6,755.88 3,810.10 2,949.22 -1,243.87 End Dir : 6755.88' MD, 3810.1' TVD 8,630.66 3,859.43 4,811.99 -1,037.75 Start Dir 3º/100' : 8630.66' MD, 3859.43'TVD 8,665.78 3,860.09 4,846.86 -1,033.70 End Dir : 8665.78' MD, 3860.09' TVD 11,238.66 3,889.89 7,400.80 -723.49 Start Dir 3º/100' : 11238.66' MD, 3889.89'TVD 11,301.77 3,891.01 7,463.51 -716.46 End Dir : 11301.77' MD, 3891.01' TVD 12,501.77 3,913.00 8,657.78 -601.46 Start Dir 3º/100' : 12501.77' MD, 3913'TVD 12,714.71 3,917.75 8,868.12 -569.33 End Dir : 12714.71' MD, 3917.75' TVD 15,467.54 3,990.09 11,561.12 -3.12 Start Dir 3º/100' : 15467.54' MD, 3990.09'TVD 15,467.77 3,990.10 11,561.34 -3.07 Total Depth : 15467.77' MD, 3990.1' TVD 5/14/2020 7:03:00PM COMPASS 5000.15 Build 91E Page 9 14 May, 2020Milne PointM Pt I PadPlan: MPU I-36MPU I-36MPU I-36 wp07Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp07Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Well Coordinates: 6,009,444.08 N, 551,689.19 E (70° 26' 11.57" N, 149° 34' 42.85" W)Datum Height: MPU I-36 Planned RKB @ 60.10usftScan Range: 26.50 to 5,182.52 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.15 Build: 91EScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftGLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referenceScan Type:Scan Type:25.00 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 26.50 to 5,182.52 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningM Pt I PadMPI-01 - MPI-01 - MPI-0111.56 408.21 7.68 418.11 2.982408.21Centre Distance Pass - MPI-01 - MPI-01 - MPI-0111.65 426.50 7.63 436.37 2.899426.50Ellipse Separation Pass - MPI-01 - MPI-01 - MPI-0112.22 451.50 8.00 461.26 2.897451.50Clearance Factor Pass - MPI-02 - MPI-02 - MPI-0223.91 905.24 16.08 917.11 3.052905.24Clearance Factor Pass - MPI-03 - MPI-03 - MPI-0393.52 984.11 85.11 988.79 11.125984.11Ellipse Separation Pass - MPI-03 - MPI-03 - MPI-0394.70 1,026.50 86.01 1,026.86 10.9031,026.50Clearance Factor Pass - MPI-04 - MPI-04 - MPI-04159.17 1,000.53 150.50 1,008.92 18.3531,000.53Centre Distance Pass - MPI-04 - MPI-04 - MPI-04159.17 1,001.50 150.49 1,009.78 18.3361,001.50Ellipse Separation Pass - MPI-04 - MPI-04 - MPI-04165.23 1,101.50 155.79 1,096.48 17.5071,101.50Clearance Factor Pass - MPI-04 - MPI-04A - MPI-04A159.17 1,000.53 150.50 1,008.92 18.3531,000.53Centre Distance Pass - MPI-04 - MPI-04A - MPI-04A159.17 1,001.50 150.49 1,009.78 18.3361,001.50Ellipse Separation Pass - MPI-04 - MPI-04A - MPI-04A165.23 1,101.50 155.79 1,096.48 17.5071,101.50Clearance Factor Pass - MPI-04 - MPI-04AL1 - MPI-04AL1159.17 1,000.53 150.50 1,008.92 18.3531,000.53Centre Distance Pass - MPI-04 - MPI-04AL1 - MPI-04AL1159.17 1,001.50 150.49 1,009.78 18.3361,001.50Ellipse Separation Pass - MPI-04 - MPI-04AL1 - MPI-04AL1165.23 1,101.50 155.79 1,096.48 17.5071,101.50Clearance Factor Pass - MPI-04 - MPI-04APB1 - MPI-04APB1159.17 1,000.53 150.50 1,008.92 18.3531,000.53Centre Distance Pass - MPI-04 - MPI-04APB1 - MPI-04APB1159.17 1,001.50 150.49 1,009.78 18.3361,001.50Ellipse Separation Pass - MPI-04 - MPI-04APB1 - MPI-04APB1165.23 1,101.50 155.79 1,096.48 17.5071,101.50Clearance Factor Pass - MPI-04 - MPI-04PB1 - MPI-04PB1159.17 1,000.53 150.50 1,008.92 18.3531,000.53Centre Distance Pass - MPI-04 - MPI-04PB1 - MPI-04PB1159.17 1,001.50 150.49 1,009.78 18.3361,001.50Ellipse Separation Pass - MPI-04 - MPI-04PB1 - MPI-04PB1165.23 1,101.50 155.79 1,096.48 17.5071,101.50Clearance Factor Pass - MPI-05 - MPI-05 - MPI-0525.36 1,208.59 17.13 1,210.60 3.0811,208.59Clearance Factor Pass - MPI-06 - MPI-06 - MPI-06104.47 1,985.84 89.64 1,918.23 7.0471,985.84Ellipse Separation Pass - MPI-06 - MPI-06 - MPI-06105.33 2,026.50 90.27 1,955.44 6.9952,026.50Clearance Factor Pass - MPI-07 - MPI-07 - MPI-07107.93 1,589.60 97.09 1,569.08 9.9621,589.60Ellipse Separation Pass - MPI-07 - MPI-07 - MPI-07108.96 1,626.50 97.88 1,601.88 9.8361,626.50Clearance Factor Pass - MPI-08 - MPI-08 - MPI-08244.65 1,168.86 236.82 1,132.59 31.2581,168.86Centre Distance Pass - MPI-08 - MPI-08 - MPI-08244.66 1,176.50 236.79 1,139.04 31.0891,176.50Ellipse Separation Pass - 14 May, 2020-18:56COMPASSPage 2 of 7 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 26.50 to 5,182.52 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-08 - MPI-08 - MPI-081,120.26 5,182.52 1,058.89 3,887.62 18.2555,182.52Clearance Factor Pass - MPI-09 - MPI-09 - MPI-0930.39 630.11 24.46 632.81 5.128630.11Ellipse Separation Pass - MPI-09 - MPI-09 - MPI-0930.56 651.50 24.56 653.82 5.087651.50Clearance Factor Pass - MPI-10 - MPI-10 - MPI-1015.56 26.50 13.72 28.75 8.42726.50Centre Distance Pass - MPI-10 - MPI-10 - MPI-1015.65 76.50 13.66 78.69 7.84576.50Ellipse Separation Pass - MPI-10 - MPI-10 - MPI-1025.91 1,376.50 15.41 1,384.90 2.4681,376.50Clearance Factor Pass - MPI-11 - MPI-11 - MPI-11282.20 460.10 278.80 455.41 82.945460.10Centre Distance Pass - MPI-11 - MPI-11 - MPI-11282.28 476.50 278.78 470.57 80.696476.50Ellipse Separation Pass - MPI-11 - MPI-11 - MPI-11412.94 2,226.50 396.58 1,988.50 25.2412,226.50Clearance Factor Pass - MPI-11 - MPI-11L1 - MPI-11L1282.20 460.10 278.80 455.41 82.945460.10Centre Distance Pass - MPI-11 - MPI-11L1 - MPI-11L1282.28 476.50 278.78 470.57 80.696476.50Ellipse Separation Pass - MPI-11 - MPI-11L1 - MPI-11L1412.94 2,226.50 396.58 1,988.50 25.2412,226.50Clearance Factor Pass - MPI-12 - MPI-12 - MPI-12299.27 1,085.17 292.18 1,049.81 42.1971,085.17Centre Distance Pass - MPI-12 - MPI-12 - MPI-12299.31 1,101.50 292.11 1,064.20 41.5861,101.50Ellipse Separation Pass - MPI-12 - MPI-12 - MPI-12616.04 2,826.50 588.45 2,456.65 22.3212,826.50Clearance Factor Pass - MPI-12 - MPI-12L1 - MPI-12L1299.27 1,085.17 292.18 1,049.81 42.1971,085.17Centre Distance Pass - MPI-12 - MPI-12L1 - MPI-12L1299.31 1,101.50 292.11 1,064.20 41.5861,101.50Ellipse Separation Pass - MPI-12 - MPI-12L1 - MPI-12L1616.04 2,826.50 588.45 2,456.65 22.3212,826.50Clearance Factor Pass - MPI-12 - MPI-12PB1 - MPI-12PB1299.27 1,085.17 292.18 1,049.81 42.1961,085.17Centre Distance Pass - MPI-12 - MPI-12PB1 - MPI-12PB1299.31 1,101.50 292.11 1,064.20 41.5851,101.50Ellipse Separation Pass - MPI-12 - MPI-12PB1 - MPI-12PB1616.04 2,826.50 588.42 2,456.65 22.3032,826.50Clearance Factor Pass - MPI-15 - MPI-15 - MPI-1540.47 26.50 38.62 28.90 21.87726.50Centre Distance Pass - MPI-15 - MPI-15 - MPI-1540.78 301.50 37.80 303.78 13.710301.50Ellipse Separation Pass - MPI-15 - MPI-15 - MPI-1544.28 426.50 40.84 428.34 12.853426.50Clearance Factor Pass - MPI-15 - MPI-15L1 - MPI-15L140.47 26.50 38.62 28.90 21.87726.50Centre Distance Pass - MPI-15 - MPI-15L1 - MPI-15L140.78 301.50 37.80 303.78 13.710301.50Ellipse Separation Pass - MPI-15 - MPI-15L1 - MPI-15L144.28 426.50 40.84 428.34 12.853426.50Clearance Factor Pass - MPI-15 - MPI-15PB1 - MPI-15PB140.47 26.50 38.62 28.90 21.87726.50Centre Distance Pass - MPI-15 - MPI-15PB1 - MPI-15PB140.78 301.50 37.80 303.78 13.710301.50Ellipse Separation Pass - MPI-15 - MPI-15PB1 - MPI-15PB144.28 426.50 40.84428.34 12.853426.50Clearance Factor Pass - 14 May, 2020-18:56COMPASSPage 3 of 7 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 26.50 to 5,182.52 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-16 - MPI-16 - MPI-1669.99 273.72 66.95 282.12 23.035273.72Centre Distance Pass - MPI-16 - MPI-16 - MPI-1670.11 301.50 66.86 309.70 21.596301.50Ellipse Separation Pass - MPI-16 - MPI-16 - MPI-16237.69 2,476.50 206.90 2,474.55 7.7192,476.50Clearance Factor Pass - MPI-17 - MPI-17 - MPI-1799.40 661.33 93.03 672.04 15.600661.33Ellipse Separation Pass - MPI-17 - MPI-17 - MPI-17435.19 4,051.50 360.00 4,394.41 5.7884,051.50Clearance Factor Pass - MPI-17 - MPI-17L1 - MPI-17L199.40 661.33 93.03 672.04 15.600661.33Ellipse Separation Pass - MPI-17 - MPI-17L1 - MPI-17L1435.19 4,051.50 360.00 4,394.41 5.7884,051.50Clearance Factor Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB199.40 661.33 93.03 672.04 15.600661.33Ellipse Separation Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1435.19 4,051.50 360.00 4,394.41 5.7884,051.50Clearance Factor Pass - MPI-17 - MPI-17L2 - MPI-17L299.40 661.33 93.03 672.04 15.600661.33Ellipse Separation Pass - MPI-17 - MPI-17L2 - MPI-17L2435.19 4,051.50 360.00 4,394.41 5.7884,051.50Clearance Factor Pass - MPI-18 - MPI-18 - MPI-18130.27 26.50 128.43 29.59 70.55026.50Centre Distance Pass - MPI-18 - MPI-18 - MPI-18130.50 101.50 128.36 103.98 61.023101.50Ellipse Separation Pass - MPI-18 - MPI-18 - MPI-18348.34 3,026.50 296.08 3,261.66 6.6663,026.50Clearance Factor Pass - MPI-19 - MPI-19 - MPI-19160.73 26.50 158.89 35.44 87.02626.50Ellipse Separation Pass - MPI-19 - MPI-19 - MPI-19192.77 1,026.50 183.96 1,036.39 21.8891,026.50Clearance Factor Pass - MPI-19 - MPI-19L1 - MPI-19L1160.73 26.50 158.89 35.44 87.02626.50Ellipse Separation Pass - MPI-19 - MPI-19L1 - MPI-19L1192.77 1,026.50 183.96 1,036.39 21.8891,026.50Clearance Factor Pass - MPI-19 - MPI-19PB1 - MPI-19PB1160.73 26.50 158.89 35.44 87.02626.50Ellipse Separation Pass - MPI-19 - MPI-19PB1 - MPI-19PB1192.77 1,026.50 183.96 1,036.39 21.8891,026.50Clearance Factor Pass - MPI-19 - MPI-19PB2 - MPI-19PB2160.73 26.50 158.89 35.44 87.02626.50Ellipse Separation Pass - MPI-19 - MPI-19PB2 - MPI-19PB2192.77 1,026.50 183.96 1,036.39 21.8891,026.50Clearance Factor Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21i wp0379.94 591.51 75.96 591.55 20.072591.51Centre Distance Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21i wp0379.97 601.50 75.94 601.22 19.831601.50Ellipse Separation Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21i wp03484.57 5,182.52 437.80 5,142.02 10.3615,182.52Clearance Factor Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp0328.51 397.34 25.40 397.69 9.190397.34Centre Distance Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp0328.51 401.50 25.39 401.80 9.133401.50Ellipse Separation Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp0376.59 1,976.50 65.69 1,941.85 7.0271,976.50Clearance Factor Pass - Plan: MPU I-27 - MPU I-27 - MPU I-27 wp04144.67 276.50 142.11 276.50 56.529276.50Centre Distance Pass - Plan: MPU I-27 - MPU I-27 - MPU I-27 wp04144.72 301.50 142.05 301.50 54.299301.50Ellipse Separation Pass - 14 May, 2020-18:56COMPASSPage 4 of 7 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 26.50 to 5,182.52 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningPlan: MPU I-27 - MPU I-27 - MPU I-27 wp041,120.08 5,182.52 1,071.08 4,909.74 22.8595,182.52Clearance Factor Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp0353.13 607.85 48.97 608.18 12.770607.85Ellipse Separation Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03262.42 5,182.52 220.30 5,006.60 6.2305,182.52Clearance Factor Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp0328.09 317.84 25.35 317.90 10.252317.84Centre Distance Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp0328.10 326.50 25.32 326.57 10.109326.50Ellipse Separation Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp0329.49 401.50 26.35 401.33 9.395401.50Clearance Factor Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i wp08114.61 276.50 112.05 276.50 44.790276.50Centre Distance Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i wp08114.66 301.50 111.99 301.50 43.027301.50Ellipse Separation Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i wp08182.60 1,576.50 173.88 1,606.36 20.9511,576.50Clearance Factor Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i114.61 26.50 112.70 26.75 59.95926.50Ellipse Separation Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i189.66 1,626.50 180.28 1,661.20 20.2111,626.50Clearance Factor Pass - M Pt J PadSurvey tool programFrom(usft)To(usft)Survey/Plan Survey Tool26.50 2,000.00 MPU I-36 wp07 3_Gyro-GC_Csg2,000.00 5,182.52 MPU I-36 wp07 3_MWD+IFR2+MS+Sag5,182.52 15,467.77 MPU I-36 wp07 3_MWD+IFR2+MS+SagEllipse error terms are correlated across survey tool tie-on points.Separation is the actual distance between ellipsoids.Calculated ellipses incorporate surface errors.Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).Distance Between centres is the straight line distance between wellbore centres.All station coordinates were calculated using the Minimum Curvature method.14 May, 2020-18:56COMPASSPage 5 of 7 0.001.002.003.004.00Separation Factor0 275 550 825 1100 1375 1650 1925 2200 2475 2750 3025 3300 3575 3850 4125 4400 4675 4950 5225Measured Depth (550 usft/in)MPI-05MPI-01MPI-10MPI-02No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU I-36 NAD 1927 (NADCON CONUS)Alaska Zone 0433.60+N/-S +E/-W Northing Easting Latittude Longitude0.000.00 6009444.08 551689.1970° 26' 11.572 N149° 34' 42.850 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-36, True NorthVertical (TVD) Reference:MPU I-36 Planned RKB @ 60.10usftMeasured Depth Reference:MPU I-36 Planned RKB @ 60.10usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-03-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 2000.00 MPU I-36 wp07 (MPU I-36) 3_Gyro-GC_Csg2000.00 5182.52 MPU I-36 wp07 (MPU I-36) 3_MWD+IFR2+MS+Sag5182.52 15467.77 MPU I-36 wp07 (MPU I-36) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 275 550 825 1100 1375 1650 1925 2200 2475 2750 3025 3300 3575 3850 4125 4400 4675 4950 5225Measured Depth (550 usft/in)MPU I-22 wp03MPI-09MPI-05MPI-01MPU I-21i wp03MPU I-29 wp03MPI-10MPU I-28i wp03MPU I-27 wp04MPI-02MPI-15MPI-16MPU I-35i wp08MPU I-35iMPI-17NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 5182.52Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-36Wellbore: MPU I-36Plan: MPU I-36 wp07Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3830.09 3769.99 5182.52 9-5/8 9 5/8" X 12 1/4"3990.10 3930.00 15467.77 6-5/8 6 5/8" X 8 1/2" 14 May, 2020Milne PointM Pt I PadPlan: MPU I-36MPU I-36MPU I-36 wp07Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp07Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Well Coordinates: 6,009,444.08 N, 551,689.19 E (70° 26' 11.57" N, 149° 34' 42.85" W)Datum Height: MPU I-36 Planned RKB @ 60.10usftScan Range: 5,182.52 to 15,467.77 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.15 Build: 91EScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftGLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referenceScan Type:Scan Type:25.00 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 5,182.52 to 15,467.77 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningM Pt I PadMPI-07 - MPI-07 - MPI-071,701.86 5,182.52 1,669.97 3,851.22 53.3725,182.52Clearance Factor Pass - MPI-08 - MPI-08 - MPI-081,120.26 5,182.52 1,058.89 3,887.62 18.2555,182.52Ellipse Separation Pass - MPI-08 - MPI-08 - MPI-081,561.07 6,232.52 1,407.42 4,935.46 10.1606,232.52Clearance Factor Pass - MPI-09 - MPI-09 - MPI-09656.67 5,902.89 574.84 4,718.90 8.0255,902.89Centre Distance Pass - MPI-09 - MPI-09 - MPI-09671.57 6,107.52 559.12 4,869.59 5.9726,107.52Ellipse Separation Pass - MPI-09 - MPI-09 - MPI-09804.08 6,557.52 639.93 5,182.55 4.8996,557.52Clearance Factor Pass - MPI-12 - MPI-12 - MPI-121,735.17 5,182.52 1,671.26 3,414.30 27.1515,182.52Clearance Factor Pass - MPI-12 - MPI-12L1 - MPI-12L11,735.17 5,182.52 1,671.26 3,414.30 27.1515,182.52Clearance Factor Pass - MPI-12 - MPI-12PB1 - MPI-12PB11,735.17 5,182.52 1,671.04 3,414.30 27.0575,182.52Clearance Factor Pass - MPI-17 - MPI-17 - MPI-171,381.27 5,182.52 1,273.33 4,828.04 12.7975,182.52Clearance Factor Pass - MPI-17 - MPI-17L1 - MPI-17L11,381.27 5,182.52 1,273.33 4,828.04 12.7975,182.52Clearance Factor Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB11,381.27 5,182.52 1,273.33 4,828.04 12.7975,182.52Clearance Factor Pass - MPI-17 - MPI-17L2 - MPI-17L21,381.27 5,182.52 1,274.04 4,828.08 12.8815,182.52Clearance Factor Pass - MPI-19 - MPI-19 - MPI-19224.42 11,332.52 95.43 9,720.00 1.74011,332.52Clearance Factor Pass - MPI-19 - MPI-19 - MPI-19224.20 11,342.58 95.66 9,720.00 1.74411,342.58Centre Distance Pass - MPI-19 - MPI-19L1 - MPI-19L1188.3410,757.5249.789,145.331.35910,757.52Clearance FactorPass - MPI-19 - MPI-19L1 - MPI-19L1179.0310,857.5248.579,253.951.37210,857.52Ellipse SeparationPass - MPI-19 - MPI-19L1 - MPI-19L1149.73 11,202.11 85.96 9,593.12 2.34811,202.11Centre Distance Pass - MPI-19 - MPI-19PB1 - MPI-19PB1247.73 8,557.52 124.69 6,904.82 2.0138,557.52Clearance Factor Pass - MPI-19 - MPI-19PB1 - MPI-19PB1247.07 8,596.34 124.86 6,937.51 2.0228,596.34Centre Distance Pass - MPI-19 - MPI-19PB2 - MPI-19PB2247.73 8,557.52 124.69 6,904.82 2.0138,557.52Clearance Factor Pass - MPI-19 - MPI-19PB2 - MPI-19PB2247.07 8,596.34 124.86 6,937.51 2.0228,596.34Centre Distance Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21i wp03326.95 14,007.52 119.08 13,929.27 1.57314,007.52Clearance Factor Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21i wp03325.94 14,034.28 119.60 13,936.59 1.58014,034.28Centre Distance Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03478.20 12,675.58 274.59 13,230.15 2.34912,675.58Centre Distance Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03502.37 14,032.52 261.81 14,570.85 2.08814,032.52Ellipse Separation Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03504.23 14,057.52 262.34 14,570.85 2.08514,057.52Clearance Factor Pass - Plan: MPU I-27 - MPU I-27 - MPU I-27 wp04895.43 15,232.52 611.18 14,858.11 3.15015,232.52Clearance Factor Pass - 14 May, 2020-18:57COMPASSPage 2 of 7 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 5,182.52 to 15,467.77 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningPlan: MPU I-27 - MPU I-27 - MPU I-27 wp04895.06 15,258.10 611.34 14,858.11 3.15515,258.10Centre Distance Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03262.42 5,182.52 220.30 5,006.60 6.2305,182.52Centre Distance Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03270.5815,467.7725.9715,273.381.10615,467.77Clearance FactorPass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp03424.27 12,670.01 217.45 13,243.08 2.05112,670.01Centre Distance Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp03483.32 15,467.77 199.92 16,039.97 1.70515,467.77Clearance Factor Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i wp08766.46 15,432.52 470.82 14,768.86 2.59315,432.52Clearance Factor Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i wp08765.73 15,457.52 470.62 14,768.86 2.59515,457.52Ellipse Separation Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i wp08765.67 15,467.77 470.87 14,768.86 2.59715,467.77Centre Distance Pass - Rig: MPU I-35i - MPU I-35i - MPU I-35i971.10 10,356.98 812.46 9,740.56 6.12110,356.98Clearance Factor Pass - M Pt J PadMPJ-01 - MPJ-01 - MPJ-011,089.75 10,422.41 979.74 4,038.32 9.90510,422.41Centre Distance Pass - MPJ-01 - MPJ-01 - MPJ-011,089.79 10,432.52 979.70 4,042.29 9.89910,432.52Ellipse Separation Pass - MPJ-01 - MPJ-01 - MPJ-011,091.17 10,482.52 980.78 4,061.89 9.88510,482.52Clearance Factor Pass - MPJ-01 - MPJ-01A - MPJ-01A493.95 11,838.60 330.23 5,566.21 3.01711,838.60Centre Distance Pass - MPJ-01 - MPJ-01A - MPJ-01A494.09 11,857.52 329.89 5,582.05 3.00911,857.52Ellipse Separation Pass - MPJ-01 - MPJ-01A - MPJ-01A494.50 11,882.52 329.90 5,600.82 3.00411,882.52Clearance Factor Pass - MPJ-01 - MPJ-01AL1 - MPJ-01AL1594.49 11,464.13 456.81 5,187.92 4.31811,464.13Centre Distance Pass - MPJ-01 - MPJ-01AL1 - MPJ-01AL1594.58 11,482.52 456.79 5,200.04 4.31511,482.52Ellipse Separation Pass - MPJ-01 - MPJ-01AL1 - MPJ-01AL1737.71 14,057.52 499.63 7,952.00 3.09914,057.52Clearance Factor Pass - MPJ-06 - MPJ-06 - MPJ-06763.86 10,507.52 636.41 4,444.945.99310,507.52Clearance Factor Pass - MPJ-06 - MPJ-06 - MPJ-06761.99 10,557.52 635.06 4,471.28 6.00310,557.52Ellipse Separation Pass - MPJ-06 - MPJ-06 - MPJ-06761.83 10,577.09 635.18 4,482.56 6.01510,577.09Centre Distance Pass - MPJ-08 - MPJ-08 - MPJ-0862.6710,992.98-11.264,809.900.84810,992.98Centre DistanceFAIL - MPJ-08 - MPJ-08 - MPJ-0873.4111,057.52-65.014,862.790.53011,057.52Clearance FactorFAIL - MPJ-08 - MPJ-08 - MPJ-0881.8311,082.52-70.574,883.820.53711,082.52Ellipse SeparationFAIL - MPJ-08 - MPJ-08A - MPJ-08A62.6710,992.98-11.264,810.700.84810,992.98Centre DistanceFAIL - MPJ-08 - MPJ-08A - MPJ-08A73.4211,057.52-64.384,863.560.53311,057.52Clearance FactorFAIL - MPJ-08 - MPJ-08A - MPJ-08A82.2011,082.52-67.714,881.440.54811,082.52Ellipse SeparationFAIL - MPJ-09 - MPJ-09 - MPJ-09746.75 10,520.04 653.49 4,345.36 8.00710,520.04Centre Distance Pass - MPJ-09 - MPJ-09 - MPJ-09756.90 10,657.52 642.98 4,403.64 6.64410,657.52Ellipse Separation Pass - 14 May, 2020-18:57COMPASSPage 3 of 7 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 5,182.52 to 15,467.77 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-09 - MPJ-09 - MPJ-09977.63 11,257.52 790.67 4,822.55 5.22911,257.52Clearance Factor Pass - MPJ-09 - MPJ-09A - MPJ-09A746.75 10,520.04 653.50 4,345.63 8.00810,520.04Centre Distance Pass - MPJ-09 - MPJ-09A - MPJ-09A756.90 10,657.52 643.01 4,403.91 6.64510,657.52Ellipse Separation Pass - MPJ-09 - MPJ-09A - MPJ-09A977.63 11,257.52 790.76 4,822.82 5.23211,257.52Clearance Factor Pass - MPJ-11 - MPJ-11 - MPJ-11797.79 12,407.52 661.89 5,333.91 5.87012,407.52Clearance Factor Pass - MPJ-11 - MPJ-11 - MPJ-11797.79 12,410.07 661.89 5,335.79 5.87012,410.07Centre Distance Pass - MPJ-15 - MPJ-15 - MPJ-15680.56 12,567.97 492.09 5,480.67 3.61112,567.97Centre Distance Pass - MPJ-15 - MPJ-15 - MPJ-15694.36 12,732.52 476.51 5,600.14 3.18712,732.52Ellipse Separation Pass - MPJ-15 - MPJ-15 - MPJ-15778.07 13,057.52 514.20 5,845.11 2.94913,057.52Clearance Factor Pass - MPJ-16 - MPJ-16 - MPJ-16227.5712,757.521.345,859.891.00612,757.52Clearance FactorPass - MPJ-16 - MPJ-16 - MPJ-16224.3012,831.377.485,922.551.03412,831.37Centre DistancePass - MPJ-18 - MPJ-18 - MPJ-181,022.35 10,849.94 946.34 4,234.14 13.45010,849.94Centre Distance Pass - MPJ-18 - MPJ-18 - MPJ-181,035.39 11,057.52 935.27 4,359.77 10.34111,057.52Ellipse Separation Pass - MPJ-18 - MPJ-18 - MPJ-181,417.29 12,132.52 1,208.65 5,077.28 6.79312,132.52Clearance Factor Pass - MPJ-19 - MPJ-19 - MPJ-191,057.18 9,765.97 997.69 3,915.45 17.7729,765.97Centre Distance Pass - MPJ-19 - MPJ-19 - MPJ-191,057.98 9,807.52 996.68 3,930.03 17.2609,807.52Ellipse Separation Pass - MPJ-19 - MPJ-19 - MPJ-191,260.44 10,507.52 1,168.99 4,186.52 13.78310,507.52Clearance Factor Pass - MPJ-19 - MPJ-19A - MPJ-19A1,040.28 9,835.84 972.14 4,084.54 15.2689,835.84Centre Distance Pass - MPJ-19 - MPJ-19A - MPJ-19A1,042.34 9,907.52 970.59 4,113.81 14.5279,907.52Ellipse Separation Pass - MPJ-19 - MPJ-19A - MPJ-19A1,229.82 10,557.52 1,125.96 4,426.43 11.84210,557.52Clearance Factor Pass - MPJ-22 - MPJ-22 - MPJ-22630.82 9,108.44 573.44 4,072.19 10.9939,108.44Centre Distance Pass - MPJ-22 - MPJ-22 - MPJ-22632.69 9,157.52 572.25 4,079.14 10.4699,157.52Ellipse Separation Pass - MPJ-22 - MPJ-22 - MPJ-22758.10 9,532.52 664.20 4,131.84 8.0739,532.52Clearance Factor Pass - MPJ-25 - MPJ-25 - MPJ-2534.5110,355.58-2.284,331.640.93810,355.58Centre DistanceFAIL - MPJ-25 - MPJ-25 - MPJ-2541.8610,382.52-30.964,344.330.57510,382.52Clearance FactorFAIL - MPJ-25 - MPJ-25 - MPJ-2557.2510,407.52-32.674,356.100.63710,407.52Ellipse SeparationFAIL - MPJ-25 - MPJ-25PB1 - MPJ-25PB154.6010,307.52-54.604,318.010.50010,307.52Ellipse SeparationFAIL - MPJ-25 - MPJ-25PB1 - MPJ-25PB145.6810,332.52-46.034,327.490.49810,332.52Clearance FactorFAIL - MPJ-25 - MPJ-25PB1 - MPJ-25PB145.0110,340.91-36.474,330.680.55210,340.91Centre DistanceFAIL - MPJ-26 - MPJ-26 - MPJ-26862.33 8,357.52 778.19 4,062.04 10.2498,357.52Clearance Factor Pass - 14 May, 2020-18:57COMPASSPage 4 of 7 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-36 - MPU I-36 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 5,182.52 to 15,467.77 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-36 - MPU I-36 - MPU I-36 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-26 - MPJ-26 - MPJ-26796.63 8,657.52 726.79 4,036.45 11.4068,657.52Ellipse Separation Pass - MPJ-26 - MPJ-26 - MPJ-26795.87 8,692.40 727.29 4,036.45 11.6058,692.40Centre Distance Pass - MPJ-26 - MPJ-26L1 - MPJ-26L1862.33 8,357.52 778.19 4,062.04 10.2498,357.52Clearance Factor Pass - MPJ-26 - MPJ-26L1 - MPJ-26L1796.63 8,657.52 726.79 4,036.45 11.4068,657.52Ellipse Separation Pass - MPJ-26 - MPJ-26L1 - MPJ-26L1795.87 8,692.40 727.29 4,036.45 11.6058,692.40Centre Distance Pass - MPJ-26 - MPJ-26L2 - MPJ-26L2862.33 8,357.52 778.19 4,062.04 10.2498,357.52Clearance Factor Pass - MPJ-26 - MPJ-26L2 - MPJ-26L2796.63 8,657.52 726.79 4,036.45 11.4068,657.52Ellipse Separation Pass - MPJ-26 - MPJ-26L2 - MPJ-26L2795.87 8,692.40 727.29 4,036.45 11.6058,692.40Centre Distance Pass - MPJ-26 - MPJ-26PB1 - MPJ-26PB1862.33 8,357.52 778.19 4,062.04 10.2498,357.52Clearance Factor Pass - MPJ-26 - MPJ-26PB1 - MPJ-26PB1796.63 8,657.52 726.79 4,036.45 11.4068,657.52Ellipse Separation Pass - MPJ-26 - MPJ-26PB1 - MPJ-26PB1795.87 8,692.40 727.29 4,036.45 11.6058,692.40Centre Distance Pass - MPJ-26 - MPJ-26PB2 - MPJ-26PB2862.33 8,357.52 778.19 4,062.04 10.2498,357.52Clearance Factor Pass - MPJ-26 - MPJ-26PB2 - MPJ-26PB2796.63 8,657.52 726.79 4,036.45 11.4068,657.52Ellipse Separation Pass - MPJ-26 - MPJ-26PB2 - MPJ-26PB2795.87 8,692.40 727.29 4,036.45 11.6058,692.40Centre Distance Pass - Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool26.50 2,000.00 MPU I-36 wp07 3_Gyro-GC_Csg2,000.00 5,182.52 MPU I-36 wp07 3_MWD+IFR2+MS+Sag5,182.52 15,467.77 MPU I-36 wp07 3_MWD+IFR2+MS+SagEllipse error terms are correlated across survey tool tie-on points.Separation is the actual distance between ellipsoids.Calculated ellipses incorporate surface errors.Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).Distance Between centres is the straight line distance between wellbore centres.All station coordinates were calculated using the Minimum Curvature method.14 May, 2020-18:57COMPASSPage 5 of 7 0.001.002.003.004.00Separation Factor5500 6050 6600 7150 7700 8250 8800 9350 9900 10450 11000 11550 12100 12650 13200 13750 14300 14850 15400Measured Depth (1100 usft/in)MPJ-16MPJ-08AMPJ-25No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU I-36 NAD 1927 (NADCON CONUS)Alaska Zone 0433.60+N/-S +E/-W Northing Easting Latittude Longitude0.000.006009444.08 551689.1970° 26' 11.572 N149° 34' 42.850 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-36, True NorthVertical (TVD) Reference:MPU I-36 Planned RKB @ 60.10usftMeasured Depth Reference:MPU I-36 Planned RKB @ 60.10usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-03-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 2000.00 MPU I-36 wp07 (MPU I-36) 3_Gyro-GC_Csg2000.00 5182.52 MPU I-36 wp07 (MPU I-36) 3_MWD+IFR2+MS+Sag5182.52 15467.77 MPU I-36 wp07 (MPU I-36) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)5500 6050 6600 7150 7700 8250 8800 9350 9900 10450 11000 11550 12100 12650 13200 13750 14300 14850 15400Measured Depth (1100 usft/in)NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 15467.77Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-36Wellbore: MPU I-36Plan: MPU I-36 wp07Ladder / S.F. Plots2 of 2CASING DETAILSTVD TVDSS MD Size Name3830.09 3769.99 5182.52 9-5/8 9 5/8" X 12 1/4"3990.10 3930.00 15467.77 6-5/8 6 5/8" X 8 1/2" 1 Carlisle, Samantha J (CED) From:Cody Dinger <cdinger@hilcorp.com> Sent:Friday, May 15, 2020 12:33 PM To:Boyer, David L (CED); Davies, Stephen F (CED) Subject:FW: HAK MP I-36 (PTD:TBD) Directional Plan Attachments:MPU I-36 wp07 Proposal Report.pdf; MPU I-36 wp07.txt From: Joseph Engel Sent: Friday, May 15, 2020 11:07 AM To: 'guy.schwartz@alaska.gov' <guy.schwartz@alaska.gov> Cc: Cody Dinger <cdinger@hilcorp.com> Subject: HAK MP I‐36 (PTD:TBD) Directional Plan Guy – Yesterday we submitted the PTD for i‐36. In the submitted proposal packet for wp06 there is a close approach with J‐16, a LTSI kuparuk injector, with a clearance factor of <1.0. The internal decision was made to nudge the lateral away from J‐ 16 before we drill the well. We got the new well plan back faster than anticipated. Please find the updated well plan, wp07, with a nudge in the lateral to ensure our CF with J‐16 is >1.0. Please let me know if you have any questions. Thank you for your time. ‐Joe Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 | Anchorage | AK | 99503 Office: 907.777.8395 | Cell: 805.235.6265 Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements 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 (_______________________________) in the attached application, the following well logs are also required for this 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. WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:MILNE PT UNIT I-36Initial Class/TypeDEV / PENDGeoArea890Unit11328On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2200470MILNE POINT, SCHRADER BLFF OIL - 525140NA1 Permit fee attachedYes2 Lease number appropriateYes3 Unique well name and numberYes4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes20" conductor st 169 ft18 Conductor string providedNA19 Surface casing protects all known USDWsYesUsing 2 stage cmt. ES at 2500 ft md20 CMT vol adequate to circulate on conductor & surf csgNo21 CMT vol adequate to tie-in long string to surf csgYesLateral will utilize slotted liner. 7" tieback for IA.22 CMT will cover all known productive horizonsYesBTC calcs good. Running 40# /47# 9 5/8" casing for subsidence.23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitNAgrassroots well25 If a re-drill, has a 10-403 for abandonment been approvedYessome close crossings on J pad .. Addressed in PTD page 5026 Adequate wellbore separation proposedYes27 If diverter required, does it meet regulationsYesMax formation press= 1700 psi will drill with 8-9-9.5 ppg mud28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYesMASP - 1340 psi will test BOPE to 3000 psi30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)YesH2S not anticipated from drilling of offset wells; however, rig has H2S sensors and alarms.35 Permit can be issued w/o hydrogen sulfide measuresYes36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate5/18/2020ApprGLSDate5/19/2020ApprDLBDate5/18/2020AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateESP completion .Hilcorp using 47# casing for top 2000 ft to help with subsidence buckling. (vs 40#)JMP5/20/2020