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Home My WebLink About219-1601. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Surface Casing Repair 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 14,508 feet N/A feet true vertical 3,579 feet N/A feet Effective Depth measured 14,508 feet feet true vertical 3,579 feet 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 / TXP 4,950' 3,750' PHL Retrievable BOT SLZXP LTP Packers and SSSV (type, measured and true vertical depth)(2) Swell Packers 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 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 4,431, 4,901, 5,913 & 6,605 3,635, 3,749, 3,807 & 3,742 323-676 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 22 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 821 Gas-Mcf MD 107' 3,460 Size 107' 3,747' 76 3,45986 530 3251 321 measured TVD 7" 6-5/8' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 219-160 50-029-23657-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL025514 & ADL355023 Milne Point Unit / Schrader Bluff Oil Pool MPU M-24 Plugs Junk measured Length Slotted Liner 4,904' 9,604' Casing Conductor 3,749' 3,579' 4,904' 14,505' 5,066'Surface Tieback 20" 9-5/8" 107' 5,066' 5,410psi 3,470psi 5,750psi 7,240psi 6,090psi Burst N/A Collapse N/A 3,090psi PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:41 pm, Aug 13, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.08.13 12:43:58 - 08'00' Taylor Wellman (2143) RBDMS JSB 082224 WCB 10-22-2024 DSR-8/21/24 Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Wellhead 50-029-23657-00-00 219-160 12/22/2023 3/12/2024 12/22/2023 - Friday WELLHEAD: Set 4" BPV w/ S-10 lubricator Pre Csg repair. No pressure on gauge 12/20/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/21/2023 - Thursday No operations to report. No operations to report. No operations to report. 12/23/2023 - Saturday No operations to report. 12/26/2023 - Tuesday 12/24/2023 - Sunday No operations to report. 12/25/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Wellhead 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 1/5/2024 - Friday No operations to report. 1/3/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/4/2024 - Thursday No operations to report. Day 1 of excavation: Dig out gravel around cellar box down 4' to expose exterior of cellar box to prep to be cut off from the conductor pipe. Pictures in well file folder. No operations to report. 1/6/2024 - Saturday No operations to report. 1/9/2024 - Tuesday 1/7/2024 - Sunday No operations to report. 1/8/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Wellhead 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 1/12/2024 - Friday No operations to report. 1/10/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Day 2- Welder cut cellar box and removed. Dressed off remaining cellar around conductor. 1/11/2024 - Thursday No operations to report. Day 5 Surface casing repair: Installed shoring boxes in cellar. No operations to report. 1/13/2024 - Saturday Day 4 Surafce casing repair; Continued excavting cellar around wellhead. 1/16/2024 - Tuesday 1/14/2024 - Sunday Day 3: Surfce casing leak repair: Continue excavating cellar around wellhead. 1/15/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Wellhead 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 1/19/2024 - Friday No operations to report. 1/17/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/18/2024 - Thursday No operations to report. No operations to report. No operations to report. 1/20/2024 - Saturday WELLHEAD: Bled hanger void off, opened tree to verify BPV holding well on vac, N/D tree/adapter cleaned up hanger, ready for support structure. 1/23/2024 - Tuesday 1/21/2024 - Sunday Worley deliverd Well Support Structure to location. Off loaded structure from truck on side of the pad. Will be back at later time to install over wellhead. 1/22/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Wellhead 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 MPU Well Support busy bringing field up,supporting COIL and CDR2. Kept heat/wrap on Maximus. No operations to report. 1/27/2024 - Saturday Field on weather hold. Lost power due to high winds on multiple pads. 1/30/2024 - Tuesday 1/28/2024 - Sunday MPU Well Support kept heat/wrap on legs and disconnected travel bolts. -40 ambient. 1/29/2024 - Monday 1/26/2024 - Friday MPU Well Support kept Maximus wrapped/heated. 1/24/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary M-24 surface prep,install trench box extensions,backfill,set rig mats. High winds and low temps(35mph/-25) 1/25/2024 - Thursday MPU Well Support spotted Maximus over well,shoveled snow,wrapped and put (2) Jet Heaters on legs. No issues. -35mph wind and -30 Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Well Support 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 MPU Well Support helped Welder remove more conductor. Need to wire wheel and have Inspection sign off, before affixing patch. No issues. MPU Well Support heated excavation and drilled holes in conductor at 7' from OA VR plug threads. No fluid. Continued to wrap/heat unit and scheduled welder to arrive in morning and start patch works. No issues. 2/3/2024 - Saturday MPU Well Support assisted welder (NES Bailey), with removing conductor and stripping internal urethane insulation, prepping for Mistras UT inspection. Unit remains wrapped/heated. No issues. 2/6/2024 - Tuesday 2/4/2024 - Sunday MPU Well Support drilled another hole in conductor as circ port for N2 purge. Worley Welders unable to do job and were released from location. NES welders sourced and project to continue in morning. Unit remains wrapped/heated. No issues. 2/5/2024 - Monday 2/2/2024 - Friday MPU Well Support made up to adapter flange,fastened top hat and put heat in excavation. Unit is wrapped/heated and working well. No issues. 1/31/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MPU Well Support kept unit heated/wrapped. Workloaded precluded progress on project. No issues. 2/1/2024 - Thursday MPU Well Support C/O Day. New troops arrived and adjusted 'cross height in shop. Heat/wrap remains in place. No issues. Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Well Support 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 2/9/2024 - Friday T/I/O= BPV/0/0 Surface Casing Repair: Removed 22" of cement from conductor below conductor cut line with compressed air, Exposed casing is severely pitted, Cement is improperly set, Final T/I/O= BPV/0/0. 2/7/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary T/I/O= BPV/0/0 Surface casing Repair; Removed slips, Buffed outer casing, Identified hole @ 96.5" from bottom of casing hangar, All visible casing is severly pitted, Further conductor removal is required to find good metal, Started to remove insulated conductor an additional 1', See photos of pitted casing in file. Final WHPS T/I/O BPV/0/0. 2/8/2024 - Thursday T/I/O= BPV/0/0 Surface Casing Repair, Removed 1' from insulated conductor, Removed 1' from conductor, Severely pitted to bottom of exposed casing, Final T/I/O= BPV/0/0. BPV/0/0; Surface Casing Repair: Removed 22" of insulated conductor, Removed insulation, Removed 22" of conductor, Removed 6" of cement from conductor to level of conductor cut, UT verified 5'3" of bad casing, UT from top of conductor cut to bottom of casing hanger, Final T/I/O= BPV/0/0. Inspection team UT'd the surface casing. Need to dig out 2 more feet to verify good metal. 2/10/2024 - Saturday BPV/0/0 Surface casing Valve: Removed 16" frozen tundra mud from around conductor with jackhammer and shovel, Removed 20" of cement from outside conductor with jackhammer, Final T/I/O= BPV/0/0. 2/13/2024 - Tuesday 2/11/2024 - Sunday T/I/O= BPV/0/0 Surface Casing repair: Excavated 1-1.5' of mud from around conductor with supersucker and shovel, Final T/I/O= BPV/0/0. 2/12/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Well Support 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 T/I/0= BPV/0/0 Surface Casing Repair; NES welder starting prepping to weld up conductor. Made top plate cover for insulated conductor, tacted bottom 2 pieces of conductor. T/I/O= BPV/0/0 Welders finished weddling vertical seams on sleeve, finished both tops on sleeves. Will continue welding on bottoms of wedding rings. Final WHP's = BPV/0/0. 2/17/2024 - Saturday T/I/O= BPV/0/0 Surface casing Repair: State man Josh Hunt inspected final welds on sleeve, found no discrepancies. 2/20/2024 - Tuesday 2/18/2024 - Sunday T/I/O= BPV/0/0 Surface Casing Repair: Worley welders finsihed welding patch. QC inspected welds, all welds passed, Inspection crew UT the vertical welds, and mag tested the sleeve to the wedding rings. installed OA valve on back side , installed VR plug and blind on front side of OA casing. pressured up OA with nitrogen to 100 psi. first 15 mins lost 2 psi, second 15 mins lost 2 psi for a totalof 4 psi in 30 mins, pressured OA back up to 102 psi with nitrogen, first 15 mins lost 1 psi, second 15 mins lost 1 psi, extended the test for another 15 mins lost1 psi, for a total of 3 psi in 45 mins. Bled OA back to 0 psi. Final WHP's = BPV/0/0. 2/19/2024 - Monday 2/16/2024 - Friday T/I/O= BPV/0/0 Inspection crew mag tested weld on wedding bands all passed, R/D Pro Heat machine, installed sleeve and tacted to wedding bands. Started to weld vertical beads on lower section of sleeve. Continue welding sleeve tomorrow. Final WHP's = BPV/0/0. 2/14/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary T/I/O= BPV/0/0, Patched hole in casing with belzona 1121, UT verified good pipe for wedding bands, Installed 3 wedding bands on casing, UT verified good welds on wedding bands, Ground welds on wedding bands smooth, Plan for tomorrw weld wedding bands to casing, Final T/I/O= BPV/0/0. 2/15/2024 - Thursday T/I/O= BPV/0/0 Surface Casing repair: Installed Pro Heat machine to surface casing, heated casing to 550° -590°. Heated casing for 4 hours with temperature between 550° to 590°. Purged nitorgen through front side of OA valve to slop trailer for welding operations. Welded wedding rings to casing. QC inspected and approved welds. Shut in nitogen purge. Reduced heat to 450° to 490°, held heat for 2 hours. Final WHP's BPV/0/0. Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Well Support 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 2/23/2024 - Friday MPU Well Support assisted Welder,who welded for 10hrs on Conductor proper. Unit is wrapped/heated. No issues. 2/21/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/22/2024 - Thursday MIT-OA to 1000 psi, Post Patch, 2.7 bbls diesel to pressureup, 15 min OA lost 40 psi, 30 min OA lost 17 psi. MPU Well Support dug snow out of excavation,post Phase 3 weather. Welder started welding on conductor(3hrs). rewrapped legs and heat is on them. No issues. No operations to report. No operations to report. 2/24/2024 - Saturday MPU Well Support assisted welder,who spent 10hrs welding on conductor. Unit remains wrapped/heated. -25. No issues. 2/27/2024 - Tuesday 2/25/2024 - Sunday MPU Well Support assisted welder,as he worked on conductor. -25. Unit heated/wrapped. No issues. 2/26/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Well Support 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 No operations to report. No operations to report. 3/2/2024 - Saturday MPU Well Support heated,wrapped and removed water from excavation. Pulled shoring boxes out,backfilled partially and covered excavation with rig mats. Removed heat and cleaned up area. No issues. 3/5/2024 - Tuesday 3/3/2024 - Sunday MPU Well Support R/D Cross,lowered unit,installed travel bolts,disconnected eletrical controls and moved Unit off well. Staged on side of pad,as per conversation with GPB. Lattice Crane released from location and returned home. Shoring boxes frozen inside excavation floor. Multiple heaters and wrap in hole,water vac'd away and will remove shoring after shift change. Travel/protection boxes installed on electrical motors and all buttoned up sound. No issues 3/4/2024 - Monday 3/1/2024 - Friday Extreme weather conditions,precluded any/all work. -65 windchill and -30 ambient. Need manlift for next operation. Unit remains wrapped/heated. 2/28/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MPU Well Support filled conductor with cement and Blue Goo'd to surface. Cleaned house. Unit remains wrapped / heated. No issues. 2/29/2024 - Thursday Job suspended due to weather. Too cold to operate ManLift. Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Well Support 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 WELLHEAD: Clean up hanger thaw out void and BPV area, N/U tree/adapter test tubing hanger void 500 low 5000 high 5/10 min good test, pulled BPV secure well. NES welders finished welding cellar boxaround wellhead. R&P started backfilling around wellhead and set subtimbers. 3/9/2024 - Saturday Well Support Techs set foundation, grating package, installed production laterals, power fluid line, installed swab platform and set well house. Pressure tested prodcution lines to 1150 psi and power fluid line to 3650 psi no issues. Assisted wellhead guys with pulling BPV. 3/12/2024 - Tuesday 3/10/2024 - Sunday Roads and Pads finsihed back filling cellar and setting sub timbers, Well Support techs will start re-connecting when weather breaks. 3/11/2024 - Monday 3/8/2024 - Friday MPU SupportTech assisted NES welder with welding up cellar box. Continued welding cellar. 3/6/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MPU Support Techs assisted NES welder in prepping cellar box to be installed around tree. 3/7/2024 - Thursday MPU Well Support tech assisted NES welder in prepping cellar box. Cellar box was transported back to location and set in hole. Crew leveled cellar box in tact cellar together. NES welders started to weld cellar back togther. (ƄèÍŽÍťĖĺĲϙÍŘĺŪĲîϙèôīīÍŘϙæĺƄϙťĺϙČÍĖĲϙÍèèôŜŜϙÍŘĺŪĲîϙťĺϙèŪťϙĺƯϙæĺƄ ôīīÍŘϙæĺƄϙŘôıĺŽÍī (ƄèÍŽÍťĖĺĲ ēĺŘĖĲČϙĖĲŜťÍīīÍťĖĺĲ IĲŜťÍīīÍťĖĺĲϙĺċϙ®ôīīēôÍîϙŪŕŕĺŘťϙťŘŪèťŪŘô "ÍıÍČôîϙèÍŜĖĲČ FĺīôϙĖĲϙèÍŜĖĲČ ôıĺŽÍīϙĺċϙÍîîĖťĖĺĲÍīϙèĺĲîŪèťĺŘϙťĺϙƱĲîϙČĺĺî ŕĖŕô ®ôîîĖĲČϙæÍĲîϙĖĲŜťÍīīÍťĖĺĲ ÍťèēϙĖĲŜťÍīīÍťĖĺĲ ÍèħƱīīôîϙÍĲîϙſôīîôîϙèôīīÍŘϙĖĲŜťÍīīôî 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Surface Casing Repair 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 14,508 feet N/A feet true vertical 3,579 feet N/A feet Effective Depth measured 14,508 feet feet true vertical 3,579 feet 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 / TXP 4,950' 3,750' PHL Retrievable BOT SLZXP LTP Packers and SSSV (type, measured and true vertical depth)(2) Swell Packers 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 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 4,431, 4,901, 5,913 & 6,605 3,635, 3,749, 3,807 & 3,742 323-676 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 22 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 821 Gas-Mcf MD 107' 3,460 Size 107' 3,747' 76 3,45986 530 3251 321 measured TVD 7" 6-5/8' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 219-160 50-029-23657-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL025514 & ADL355023 Milne Point Unit / Schrader Bluff Oil Pool MPU M-24 Plugs Junk measured Length Slotted Liner 4,904' 9,604' Casing Conductor 3,749' 3,579' 4,904' 14,505' 5,066'Surface Tieback 20" 9-5/8" 107' 5,066' 5,410psi 3,470psi 5,750psi 7,240psi 6,090psi Burst N/A Collapse N/A 3,090psi PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:35 pm, Apr 11, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.04.11 14:30:24 - 08'00' Taylor Wellman (2143) DSR-4/12/24WCB 2-13-2024 RBDMS JSB 041824 Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Wellhead 50-029-23657-00-00 219-160 12/22/2023 3/12/2024 12/22/2023 - Friday WELLHEAD: Set 4" BPV w/ S-10 lubricator Pre Csg repair. No pressure on gauge 12/20/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/21/2023 - Thursday No operations to report. No operations to report. No operations to report. 12/23/2023 - Saturday No operations to report. 12/26/2023 - Tuesday 12/24/2023 - Sunday No operations to report. 12/25/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Wellhead 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 1/5/2024 - Friday No operations to report. 1/3/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/4/2024 - Thursday No operations to report. Day 1 of excavation: Dig out gravel around cellar box down 4' to expose exterior of cellar box to prep to be cut off from the conductor pipe. Pictures in well file folder. No operations to report. 1/6/2024 - Saturday No operations to report. 1/9/2024 - Tuesday 1/7/2024 - Sunday No operations to report. 1/8/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Wellhead 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 1/12/2024 - Friday No operations to report. 1/10/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Day 2- Welder cut cellar box and removed. Dressed off remaining cellar around conductor. 1/11/2024 - Thursday No operations to report. Day 5 Surface casing repair: Installed shoring boxes in cellar. No operations to report. 1/13/2024 - Saturday Day 4 Surafce casing repair; Continued excavting cellar around wellhead. 1/16/2024 - Tuesday 1/14/2024 - Sunday Day 3: Surfce casing leak repair: Continue excavating cellar around wellhead. 1/15/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Wellhead 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 1/19/2024 - Friday No operations to report. 1/17/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/18/2024 - Thursday No operations to report. No operations to report. No operations to report. 1/20/2024 - Saturday WELLHEAD: Bled hanger void off, opened tree to verify BPV holding well on vac, N/D tree/adapter cleaned up hanger, ready for support structure. 1/23/2024 - Tuesday 1/21/2024 - Sunday Worley deliverd Well Support Structure to location. Off loaded structure from truck on side of the pad. Will be back at later time to install over wellhead. 1/22/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Wellhead 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 MPU Well Support busy bringing field up,supporting COIL and CDR2. Kept heat/wrap on Maximus. No operations to report. 1/27/2024 - Saturday Field on weather hold. Lost power due to high winds on multiple pads. 1/30/2024 - Tuesday 1/28/2024 - Sunday MPU Well Support kept heat/wrap on legs and disconnected travel bolts. -40 ambient. 1/29/2024 - Monday 1/26/2024 - Friday MPU Well Support kept Maximus wrapped/heated. 1/24/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary M-24 surface prep,install trench box extensions,backfill,set rig mats. High winds and low temps(35mph/-25) 1/25/2024 - Thursday MPU Well Support spotted Maximus over well,shoveled snow,wrapped and put (2) Jet Heaters on legs. No issues. -35mph wind and -30 Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Well Support 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 MPU Well Support helped Welder remove more conductor. Need to wire wheel and have Inspection sign off, before affixing patch. No issues. MPU Well Support heated excavation and drilled holes in conductor at 7' from OA VR plug threads. No fluid. Continued to wrap/heat unit and scheduled welder to arrive in morning and start patch works. No issues. 2/3/2024 - Saturday MPU Well Support assisted welder (NES Bailey), with removing conductor and stripping internal urethane insulation, prepping for Mistras UT inspection. Unit remains wrapped/heated. No issues. 2/6/2024 - Tuesday 2/4/2024 - Sunday MPU Well Support drilled another hole in conductor as circ port for N2 purge. Worley Welders unable to do job and were released from location. NES welders sourced and project to continue in morning. Unit remains wrapped/heated. No issues. 2/5/2024 - Monday 2/2/2024 - Friday MPU Well Support made up to adapter flange,fastened top hat and put heat in excavation. Unit is wrapped/heated and working well. No issues. 1/31/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MPU Well Support kept unit heated/wrapped. Workloaded precluded progress on project. No issues. 2/1/2024 - Thursday MPU Well Support C/O Day. New troops arrived and adjusted 'cross height in shop. Heat/wrap remains in place. No issues. Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Well Support 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 2/9/2024 - Friday T/I/O= BPV/0/0 Surface Casing Repair: Removed 22" of cement from conductor below conductor cut line with compressed air, Exposed casing is severely pitted, Cement is improperly set, Final T/I/O= BPV/0/0. 2/7/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary T/I/O= BPV/0/0 Surface casing Repair; Removed slips, Buffed outer casing, Identified hole @ 96.5" from bottom of casing hangar, All visible casing is severly pitted, Further conductor removal is required to find good metal, Started to remove insulated conductor an additional 1', See photos of pitted casing in file. Final WHPS T/I/O BPV/0/0. 2/8/2024 - Thursday T/I/O= BPV/0/0 Surface Casing Repair, Removed 1' from insulated conductor, Removed 1' from conductor, Severely pitted to bottom of exposed casing, Final T/I/O= BPV/0/0. BPV/0/0; Surface Casing Repair: Removed 22" of insulated conductor, Removed insulation, Removed 22" of conductor, Removed 6" of cement from conductor to level of conductor cut, UT verified 5'3" of bad casing, UT from top of conductor cut to bottom of casing hanger, Final T/I/O= BPV/0/0. Inspection team UT'd the surface casing. Need to dig out 2 more feet to verify good metal. 2/10/2024 - Saturday BPV/0/0 Surface casing Valve: Removed 16" frozen tundra mud from around conductor with jackhammer and shovel, Removed 20" of cement from outside conductor with jackhammer, Final T/I/O= BPV/0/0. 2/13/2024 - Tuesday 2/11/2024 - Sunday T/I/O= BPV/0/0 Surface Casing repair: Excavated 1-1.5' of mud from around conductor with supersucker and shovel, Final T/I/O= BPV/0/0. 2/12/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Well Support 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 T/I/0= BPV/0/0 Surface Casing Repair; NES welder starting prepping to weld up conductor. Made top plate cover for insulated conductor, tacted bottom 2 pieces of conductor. T/I/O= BPV/0/0 Welders finished weddling vertical seams on sleeve, finished both tops on sleeves. Will continue welding on bottoms of wedding rings. Final WHP's = BPV/0/0. 2/17/2024 - Saturday T/I/O= BPV/0/0 Surface casing Repair: State man Josh Hunt inspected final welds on sleeve, found no discrepancies. 2/20/2024 - Tuesday 2/18/2024 - Sunday T/I/O= BPV/0/0 Surface Casing Repair: Worley welders finsihed welding patch. QC inspected welds, all welds passed, Inspection crew UT the vertical welds, and mag tested the sleeve to the wedding rings. installed OA valve on back side , installed VR plug and blind on front side of OA casing. pressured up OA with nitrogen to 100 psi. first 15 mins lost 2 psi, second 15 mins lost 2 psi for a totalof 4 psi in 30 mins, pressured OA back up to 102 psi with nitrogen, first 15 mins lost 1 psi, second 15 mins lost 1 psi, extended the test for another 15 mins lost1 psi, for a total of 3 psi in 45 mins. Bled OA back to 0 psi. Final WHP's = BPV/0/0. 2/19/2024 - Monday 2/16/2024 - Friday T/I/O= BPV/0/0 Inspection crew mag tested weld on wedding bands all passed, R/D Pro Heat machine, installed sleeve and tacted to wedding bands. Started to weld vertical beads on lower section of sleeve. Continue welding sleeve tomorrow. Final WHP's = BPV/0/0. 2/14/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary T/I/O= BPV/0/0, Patched hole in casing with belzona 1121, UT verified good pipe for wedding bands, Installed 3 wedding bands on casing, UT verified good welds on wedding bands, Ground welds on wedding bands smooth, Plan for tomorrw weld wedding bands to casing, Final T/I/O= BPV/0/0. 2/15/2024 - Thursday T/I/O= BPV/0/0 Surface Casing repair: Installed Pro Heat machine to surface casing, heated casing to 550° -590°. Heated casing for 4 hours with temperature between 550° to 590°. Purged nitorgen through front side of OA valve to slop trailer for welding operations. Welded wedding rings to casing. QC inspected and approved welds. Shut in nitogen purge. Reduced heat to 450° to 490°, held heat for 2 hours. Final WHP's BPV/0/0. Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Well Support 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 2/23/2024 - Friday MPU Well Support assisted Welder,who welded for 10hrs on Conductor proper. Unit is wrapped/heated. No issues. 2/21/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/22/2024 - Thursday MIT-OA to 1000 psi, Post Patch, 2.7 bbls diesel to pressureup, 15 min OA lost 40 psi, 30 min OA lost 17 psi. MPU Well Support dug snow out of excavation,post Phase 3 weather. Welder started welding on conductor(3hrs). rewrapped legs and heat is on them. No issues. No operations to report. No operations to report. 2/24/2024 - Saturday MPU Well Support assisted welder,who spent 10hrs welding on conductor. Unit remains wrapped/heated. -25. No issues. 2/27/2024 - Tuesday 2/25/2024 - Sunday MPU Well Support assisted welder,as he worked on conductor. -25. Unit heated/wrapped. No issues. 2/26/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Well Support 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 No operations to report. No operations to report. 3/2/2024 - Saturday MPU Well Support heated,wrapped and removed water from excavation. Pulled shoring boxes out,backfilled partially and covered excavation with rig mats. Removed heat and cleaned up area. No issues. 3/5/2024 - Tuesday 3/3/2024 - Sunday MPU Well Support R/D Cross,lowered unit,installed travel bolts,disconnected eletrical controls and moved Unit off well. Staged on side of pad,as per conversation with GPB. Lattice Crane released from location and returned home. Shoring boxes frozen inside excavation floor. Multiple heaters and wrap in hole,water vac'd away and will remove shoring after shift change. Travel/protection boxes installed on electrical motors and all buttoned up sound. No issues 3/4/2024 - Monday 3/1/2024 - Friday Extreme weather conditions,precluded any/all work. -65 windchill and -30 ambient. Need manlift for next operation. Unit remains wrapped/heated. 2/28/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MPU Well Support filled conductor with cement and Blue Goo'd to surface. Cleaned house. Unit remains wrapped / heated. No issues. 2/29/2024 - Thursday Job suspended due to weather. Too cold to operate ManLift. Well Name Rig API Number Well Permit Number Start Date End Date MP M-24 Well Support 50-029-23657-00-00 219-160 12/22/2024 3/12/2024 WELLHEAD: Clean up hanger thaw out void and BPV area, N/U tree/adapter test tubing hanger void 500 low 5000 high 5/10 min good test, pulled BPV secure well. NES welders finished welding cellar boxaround wellhead. R&P started backfilling around wellhead and set subtimbers. 3/9/2024 - Saturday Well Support Techs set foundation, grating package, installed production laterals, power fluid line, installed swab platform and set well house. Pressure tested prodcution lines to 1150 psi and power fluid line to 3650 psi no issues. Assisted wellhead guys with pulling BPV. 3/12/2024 - Tuesday 3/10/2024 - Sunday Roads and Pads finsihed back filling cellar and setting sub timbers, Well Support techs will start re-connecting when weather breaks. 3/11/2024 - Monday 3/8/2024 - Friday MPU SupportTech assisted NES welder with welding up cellar box. Continued welding cellar. 3/6/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MPU Support Techs assisted NES welder in prepping cellar box to be installed around tree. 3/7/2024 - Thursday MPU Well Support tech assisted NES welder in prepping cellar box. Cellar box was transported back to location and set in hole. Crew leveled cellar box in tact cellar together. NES welders started to weld cellar back togther. 2024-0219_Surface_Csg_Repair_MPU_M-24_jh Page 1 of 8 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 2-19-2024 P. I. Supervisor FROM: Josh Hunt SUBJECT: Surface Casing Repair Petroleum Inspector Milne Point Unit M-24 Hilcorp Alaska LLC PTD 2191600; Sundry 323-676 2/19/2024: I traveled to MPU M-24 and met with Hilcorp’s Josh McDaniels (Wells Foreman) and Kevin Parks. They said all the welding was complete and passed the 100-psi nitrogen test; they provided the welding inspections report. All welds checked out good. I crawled down and did a visual inspection of the patch, welds, and test ports. Everything looked very good, I did not smell or see any diesel in the well cellar or the materiel which was removed during the operation. I was told the surface casing leak was 96.5 inches from the bottom of the casing hanger. The top of the casing patch measured 71 inches from the tubing hanger lockdowns, and the bottom of the patch measured 173 inches from the same lockdowns. I was told the casing patch was originally 10 feet in length and had to be cut down to 8.5 feet to fit in the hole they had dug. I gave them permission to proceed with the rest of the job. Attachments: Photos; Operator Reports      2024-0219_Surface_Csg_Repair_MPU_M-24_jh Page 2 of 8 Surface Casing Repair – MPU M-24 (PTD 2191600) Photos by AOGCC Inspector J. Hunt 2/19/2024 2024-0219_Surface_Csg_Repair_MPU_M-24_jh Page 3 of 8 2024-0219_Surface_Csg_Repair_MPU_M-24_jh Page 4 of 8 2024-0219_Surface_Csg_Repair_MPU_M-24_jh Page 5 of 8 2024-0219_Surface_Csg_Repair_MPU_M-24_jh Page 6 of 8 2024-0219_Surface_Csg_Repair_MPU_M-24_jh Page 7 of 8 2024-0219_Surface_Csg_Repair_MPU_M-24_jh Page 8 of 8 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Surface Casing Repair 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14,508'N/A Casing Collapse Conductor N/A Surface 3,090psi Tieback 5,410psi Slotted Liner 3,470psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title:Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Schrader Bluff Oil Pool N/A 3,579'14,508'3,579'N/A N/A Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writte n approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MPU M-24 AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): 12/28/2023 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025514 & ADL355023 219-160 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23657-00-00 Hilcorp Alaska LLC C.O 477.05 5,066' 4,904' Length Size Proposed Pools: 107'107' TVD Burst Milne Point Unit 9,604' 4,904' MD N/A 6,090psi 5,750psi 7,240psi 3,747' 3,749' 3,579'14,505' See Schematic See Schematic 4-1/2" 107'20" 9-5/8" 7" 5,066' 6-5/8' PHL Retrievable, BOT SLZXP LTP & (2) Swell Packers and N/A Todd Sidoti todd.sidoti@hilcorp.com 777-8443 4,431 MD/ 3,635 TVD, 4,901 MD/ 3,749 TVD, 5,913 MD/ 3,807 TVD & 6,605 MD/ 3,742 TVD and N/A Perforation Depth MD (ft): 12.6 / L-80 / TXP 4,950' m n P s t r N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:10 am, Dec 19, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.12.18 16:06:27 - 09'00' Taylor Wellman (2143) 323-676 SFD 12/20/2023MGR22DEC23 DSR-12/19/23 10-407 *&:JLC 12/26/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.12.26 10:33:22 -09'00'12/26/23 RBDMS JSB 122623 MPU M-24 Surface Casing Leak Repair 12/18/2023 Well Name: MPU M-24 API Number: 50-029-23657-00-00 Current Status: Producer Pad: M-Pad Estimated Start Date: December 28, 2023 Rig: N/A Regulatory Contact: Tom Fouts Permit to Drill Number: 219-160 First Call Engineer: Todd Sidoti (907) 777-8420 (O) (907) 632-4113 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Brief Well Summary & Objective: MPU well M-24 was drilled and completed as a Schrader Bluff OA producer in January 2020. The well has been a steady jet pump producer since completion. In December 2023, a MIT-OA was attempted on the well which failed the surface casing when test pressure reached 1700 psi. Current well condition: 1. PX plug installed in X nipple at 4456’. 2. CMIT T-IA passed to 1500 psi on 12/13/2023. 3. Leak depth evaluation verified leak depth in 9-5/8” casing at ~7’ below grade (~2’ below cellar). Well Repair Procedure: 1. Begin to document daily work with a high level activity log. Include 1-2 photos and a one sentence summary of each day’s activities. The log will be submitted to the AOGCC with the 10-404 at job completion. 2. RD well house and flowlines. 3. Clear and level pad area around well. a. The well support structure will be used to support the wellhead. The positions where the support legs will be placed need to all be level and at the same elevation. 4. Spot rig mats and containment for support structure. 5. RU crane. Set BPV. ND tree and RD Crane. 6. MIRU well support structure and secure to tubing head adapter. 7. Transfer 50,000# of wellhead load to the well support structure per operating manual. a. Monitor wellhead during load transfer and stop if any movement is observed. 8. Complete an ACWR (Area Civil Work Request) which includes a location for all utilities, thermosyphons, and any underground infrastructure. 9. Cut away and remove cellar. a. Cellar is secured in place with welds to conductor, these supports will be removed. 10. Excavate 9’ below grade. a. Qualified person must be on-site for daily sign off on excavation per OSHA requirements, every 24 hours. b. Install sump area and dewater as necessary. c. In instances of excessive ground water inflow, previous excavation repairs have benefited from placing a sump pump in a hole in front of or adjacent to well. 11. Install Build-A-Box shoring system as required. MPU M-24 Surface Casing Leak Repair 12/18/2023 a. Assume class C soils. b. Maintain top of box minimum 1 feet above grade. c. Install ventilation fans and heater trunks (excavation is over 8 feet); follow approved ventilation plan. 12. Egress. OSHA requires one form of egress; install Davit winch on top box section, Davit to remain above grade at all times. 13. Drill test hole with cold-cutting drill bit in conductor at ~8.5’ below grade and sniff for LELs. 14. Circulate water into OA taking returns from the conductor until clean. a. If fluid or soft, broken cement is observed, drill test hole 6” lower until no fluid and good cement is found. b. Once no fluid and hard, good cement is observed behind hole, proceed to next step. 15. Cut and remove insulated 20” conductor. a. Two horizontal cuts in the 20” conductor (one below the slips and one at deepest drilled hole) and two vertical cuts will be required for removal. b. Primary cutting option is to use an air arc torch but the Hot Work Permit for this portion of the job will dictate if an alternative cutting method will be required. c. Insulation behind 20” conductor can be flammable. d. Use of a N2 cap/purge will be determined on site prior to proceeding. 16. Remove outer 20” conductor, cement and insulation. a. Remove the cement between 20” conductor and surface casing to the furthest extent possible, until clean, hard bonded cement is observed. i. This can require steaming and a vac truck. b. Buff and prepare the surface casing for inspection and welding. c. UT inspection of the exposed surface casing. d. Sleeve wedding band locations to be identified, marked and UT’d on a grid for nominal wall thickness verification. e. If UT shows wall thickness <80% nominal, deepen the excavation and remove more 20” conductor to ensure the corrosion has been straddled. f. Once UT shows wall thickness >80% nominal continue. 17. Prep well for repair. a. Evacuate fluid level in 9-5/8” surface casing below bottom welding location to avoid heat sink from casing to fluid on backside. b. Surfactant/solvent wash the annulus between the casing and conductor, steam rinse. c. Apply 2-part Belzona to seal any observable holes in the 9-5/8” surface casing and let cure for recommended time. 18. Notify AOGCC inspector for opportunity to inspect surface casing condition and casing sleeve welding operations. 19. Weld casing sleeve. a. Ensure welder qualifications. i. WPS/PQR: 4130 to X52 for welding top band to starting head. ii. WPS/PQR: L80 to X52 for welding bands to surface casing. iii. WPS/PQR: X52 to X52 for welding bands and sleeve. b. Dry fit casing sleeve/banding to ensure compatibility and positioning. MPU M-24 Surface Casing Leak Repair 12/18/2023 c. Maintain open bleed on OA. d. Verify air movers/ventilation and establish a fire watch. e. Install N2 purge equipment i. N2 cap/purge above leak. ii. Prior to welding, install continuous four-way gas meter for LEL’s and N2 on downstream side of purge. f. Install wedding bands and sleeve in accordance with sleeve design and weld package, continuously monitoring weld temperatures. i. Melting sticks are not permitted. g. NDE weld. h. Leak check casing with 100 psi N2. 20. Fit up and weld insulated 20” conductor back together. 21. Cement surface casing by conductor annulus to within 1” of conductor top. 22. Pull shoring while backfilling around the conductor and re-install cellar. 23. RDMO well support structure. 24. RU crane and NU production tree. 25. Test tree to 500 psi low/5,000 psi high. Pull BPV. 26. RD crane. 27. RU well house and flowlines. MPU M-24 Surface Casing Leak Repair 12/18/2023 Excavation Schematic DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23657-00-00Well Name/No. MILNE PT UNIT M-24Completion Status1-OILCompletion Date1/29/2020Permit to Drill2191600Operator Hilcorp Alaska, LLCMD14508TVD3579Current Status1-OIL4/7/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP/ABG/DGR/EWR/ADR 2"/5" MD...ABG/DGR/EWR/ADR 2"/5" TVD PB1, PB2, PB3NoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC3/25/2020105 14508 Electronic Data Set, Filename: MPU M-24 LWD Final.las32309EDDigital DataC3/25/20205055 14470 Electronic Data Set, Filename: MPU M-24 ADR Quadrants All Curves.las32309EDDigital DataC3/25/2020 Electronic File: MPU M-24 LWD Final MD.cgm32309EDDigital DataC3/25/2020 Electronic File: MPU M-24 LWD Final TVD.cgm32309EDDigital DataC3/25/2020 Electronic File: MPU M-24_Definitive Survey Report.pdf32309EDDigital DataC3/25/2020 Electronic File: MPU M-24_Definitive Survey Report.txt32309EDDigital DataC3/25/2020 Electronic File: MPU M-24_GIS.txt32309EDDigital DataC3/25/2020 Electronic File: MPU M-24_Plan.pdf32309EDDigital DataC3/25/2020 Electronic File: MPU M-24_VSec.pdf32309EDDigital DataC3/25/2020 Electronic File: MPU M-24 LWD Final MD.emf32309EDDigital DataC3/25/2020 Electronic File: MPU M-24 LWD Final TVD.emf32309EDDigital DataC3/25/2020 Electronic File: MPU_M-24_Geosteering.dlis32309EDDigital DataC3/25/2020 Electronic File: MPU_M-24_Geosteering.ver32309EDDigital DataC3/25/2020 Electronic File: MPU M-24 LWD Final MD.pdf32309EDDigital DataC3/25/2020 Electronic File: MPU M-24 LWD Final TVD.pdf32309EDDigital DataC3/25/2020 Electronic File: MPU M-24 LWD Final MD.tif32309EDDigital DataC3/25/2020 Electronic File: MPU M-24 LWD Final TVD.tif32309EDDigital Data0 0 2191600 MILNE PT UNIT M-24 LOG HEADERS32309LogLog Header ScansTuesday, April 7, 2020AOGCCPage 1 of 5PB1~PB2~PB3~MPU M-24 LWDFinal.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23657-00-00Well Name/No. MILNE PT UNIT M-24Completion Status1-OILCompletion Date1/29/2020Permit to Drill2191600Operator Hilcorp Alaska, LLCMD14508TVD3579Current Status1-OIL4/7/2020UICNo0 0 2191600 MILNE PT UNIT M-24 PB1 LOG HEADERS32310LogLog Header ScansC3/25/2020105 5803 Electronic Data Set, Filename: MPU M-24PB1 LWD Final.las32310EDDigital DataC3/25/20205055 5766 Electronic Data Set, Filename: MPU M-24PB1 ADR Quadrants All Curves.las32310EDDigital DataC3/25/2020 Electronic File: MPU M-24PB1 LWD Final MD.cgm32310EDDigital DataC3/25/2020 Electronic File: MPU M-24PB1 LWD Final TVD.cgm32310EDDigital DataC3/25/2020 Electronic File: MPU M-24PB1_Definitive Survey Report.pdf32310EDDigital DataC3/25/2020 Electronic File: MPU M-24PB1_Definitive Survey Report.txt32310EDDigital DataC3/25/2020 Electronic File: MPU M-24PB1_GIS.txt32310EDDigital DataC3/25/2020 Electronic File: MPU M-24PB1_Plan.pdf32310EDDigital DataC3/25/2020 Electronic File: MPU M-24PB1_VSec.pdf32310EDDigital DataC3/25/2020 Electronic File: MPU M-24PB1 LWD Final MD.emf32310EDDigital DataC3/25/2020 Electronic File: MPU M-24PB1 LWD Final TVD.emf32310EDDigital DataC3/25/2020 Electronic File: MPU_M-24PB1_Geosteering.dlis32310EDDigital DataC3/25/2020 Electronic File: MPU_M-24PB1_Geosteering.ver32310EDDigital DataC3/25/2020 Electronic File: MPU M-24PB1 LWD Final MD.pdf32310EDDigital DataC3/25/2020 Electronic File: MPU M-24PB1 LWD Final TVD.pdf32310EDDigital DataC3/25/2020 Electronic File: MPU M-24PB1 LWD Final MD.tif32310EDDigital DataC3/25/2020 Electronic File: MPU M-24PB1 LWD Final TVD.tif32310EDDigital DataC3/25/2020105 9810 Electronic Data Set, Filename: MPU M-24PB2 LWD Final.las32311EDDigital DataC3/25/20205055 9774 Electronic Data Set, Filename: MPU M-24PB2 ADR Quadrants All Curves.las32311EDDigital DataC3/25/2020 Electronic File: MPU M-24PB2 LWD Final MD.cgm32311EDDigital DataTuesday, April 7, 2020AOGCCPage 2 of 5MPU M-24PB1LWD Final.lasMPU M-24PB2LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23657-00-00Well Name/No. MILNE PT UNIT M-24Completion Status1-OILCompletion Date1/29/2020Permit to Drill2191600Operator Hilcorp Alaska, LLCMD14508TVD3579Current Status1-OIL4/7/2020UICNoC3/25/2020 Electronic File: MPU M-24PB2 LWD Final TVD.cgm32311EDDigital DataC3/25/2020 Electronic File: MPU M-24PB2_Definitive Survey Report.pdf32311EDDigital DataC3/25/2020 Electronic File: MPU M-24PB2_Definitive Survey Report.txt32311EDDigital DataC3/25/2020 Electronic File: MPU M-24PB2_GIS.txt32311EDDigital DataC3/25/2020 Electronic File: MPU M-24PB2_Plan.pdf32311EDDigital DataC3/25/2020 Electronic File: MPU M-24PB2_VSec.pdf32311EDDigital DataC3/25/2020 Electronic File: MPU M-24PB2 LWD Final MD.emf32311EDDigital DataC3/25/2020 Electronic File: MPU M-24PB2 LWD Final TVD.emf32311EDDigital DataC3/25/2020 Electronic File: MPU_M-24PB2_Geosteering.dlis32311EDDigital DataC3/25/2020 Electronic File: MPU_M-24PB2_Geosteering.ver32311EDDigital DataC3/25/2020 Electronic File: MPU M-24PB2 LWD Final MD.pdf32311EDDigital DataC3/25/2020 Electronic File: MPU M-24PB2 LWD Final TVD.pdf32311EDDigital DataC3/25/2020 Electronic File: MPU M-24PB2 LWD Final MD.tif32311EDDigital DataC3/25/2020 Electronic File: MPU M-24PB2 LWD Final TVD.tif32311EDDigital Data0 0 2191600 MILNE PT UNIT M-24 PB2 LOG HEADERS32311LogLog Header ScansC3/25/2020105 14389 Electronic Data Set, Filename: MPU M-24PB3 LWD Final.las32312EDDigital DataC3/25/20205055 14352 Electronic Data Set, Filename: MPU M-24PB3 ADR Quadrants All Curves.las32312EDDigital DataC3/25/2020 Electronic File: MPU M-24PB3 LWD Final MD.cgm32312EDDigital DataC3/25/2020 Electronic File: MPU M-24PB3 LWD Final TVD.cgm32312EDDigital DataC3/25/2020 Electronic File: MPU M-24PB3_Definitive Survey Report.pdf32312EDDigital DataC3/25/2020 Electronic File: MPU M-24PB3_Definitive Survey Report.txt32312EDDigital DataTuesday, April 7, 2020AOGCCPage 3 of 5MPU M-24PB3 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23657-00-00Well Name/No. MILNE PT UNIT M-24Completion Status1-OILCompletion Date1/29/2020Permit to Drill2191600Operator Hilcorp Alaska, LLCMD14508TVD3579Current Status1-OIL4/7/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud 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:1/29/2020Release Date: 11/21/2019C3/25/2020 Electronic File: MPU M-24PB3_GIS.txt32312EDDigital DataC3/25/2020 Electronic File: MPU M-24PB3_Plan.pdf32312EDDigital DataC3/25/2020 Electronic File: MPU M-24PB3_VSec.pdf32312EDDigital DataC3/25/2020 Electronic File: MPU M-24PB3 LWD Final MD.emf32312EDDigital DataC3/25/2020 Electronic File: MPU M-24PB3 LWD Final TVD.emf32312EDDigital DataC3/25/2020 Electronic File: MPU_M-24PB3_Geosteering.dlis32312EDDigital DataC3/25/2020 Electronic File: MPU_M-24PB3_Geosteering.ver32312EDDigital DataC3/25/2020 Electronic File: MPU M-24PB3 LWD Final MD.pdf32312EDDigital DataC3/25/2020 Electronic File: MPU M-24PB3 LWD Final TVD.pdf32312EDDigital DataC3/25/2020 Electronic File: MPU M-24PB3 LWD Final MD.tif32312EDDigital DataC3/25/2020 Electronic File: MPU M-24PB3 LWD Final TVD.tif32312EDDigital Data0 0 2191600 MILNE PT UNIT M-24 PB3 LOG HEADERS32312LogLog Header ScansTuesday, April 7, 2020AOGCCPage 4 of 5 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23657-00-00Well Name/No. MILNE PT UNIT M-24Completion Status1-OILCompletion Date1/29/2020Permit to Drill2191600Operator Hilcorp Alaska, LLCMD14508TVD3579Current Status1-OIL4/7/2020UICNoComments:Compliance Reviewed By:Date:Tuesday, April 7, 2020AOGCCPage 5 of 5M. Guhl4/7/2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVE® FEB 19 2020 WELL COMPLETION OR RECOMPLETION REPORT 1 a. Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1 b. Well CI 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1 Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Hilcorp Alaska, LLC Aband.: 1/29/2020 219->40 3. Address: 7. Date Spudded: 15. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 December 3, 2019 s 50-029-23657-00-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 5039' FSL, 651' FEL, Sec 14, T13N, R9E, UM, AK January 19, 2020 MPU M-24 Top of Productive Interval: 9. Ref Elevations: KB: 52' • 17. Field / Pool(s): Milne Point Unit 581' FNL, 2150' FEL, Sec 14, T13N, R9E, UM, AK GL: 25.1' BF: 25.1' (frig) Schrader Bluff Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: w 552' FSL, 2225' FWL, Sec 23, T13N, R9E, UM, AK 14,508' MD / 3,579' TVD ADL025514 / ADL355023 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 533513 y- 6027889 Zone- 4 14,508' MD / 3,579' TVD LONS 16-004 TPI: x- 532015 y- 6027542 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 531161 y- 6018112 Zone- 4 N/A 2,068' MD / 1,848' TVD ' 5. Directional or Inclination Survey: Yes ✓ (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary ROP/ABG/DGR/EWR/ADR 2"/5" MD ABG/DGR/EWR/ADR 2"/5" TVD PB1, PB2, PB3 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE AMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20° 216# X-52 Surface 107' Surface 107' 42" ±270 ft3 9-5/8" 40# L-80 Surface 5,066' Surface 3,747' 12-1/4" Stg 1 L - 305 sx / T - 400 sx Stg 2 L - 417 sx / T - 270 sx 204 bbls 7" 26# L-80 Surface 4,904' Surface 3,748' Tieback Tieback Assy. 6-5/8" 20# L-80 1 4,901' 14,505' 3,748' 3,579' 8-1/2" Cementless Slotted Liner 24. Open to production or injection? Yes 7 N ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Perfd): 4-1/2" 4,950' 4,431' MD / 3,633' TVD **Please see attached schematic for Slotted Liner detail** Liner run on 1/25/2020 QOMPLETiON 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information vELr"/�,� DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 2/4/2020 Jet Pump Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 2/7/2020 24 Test Period 1615 949 0 N/A 587 Flow Tubing Press. 304 Casing Press: 2356 Calculated 24 -Hour Rate --lo. Oil -Bbl: 1615 Gas -MCF: ff4,+ 9'11 Water -Bbl: 0 Oil Gravity - API (corr): 16 Form 10-407 Revised 5/ 0 7 XO/x CONTINUED ON PAGE 2 Submit ORIGINIAL only XQg315/20 �' ,M�Qzg� RB®MS.L�FEB 2 4 2020 0 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 2,068' 1,848' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 5,048' SB OA 3,747' information, including reports, per 20 AAC 25.071. SV5 1,385' 1,311' SV1 2,113' 1,884' Ugnu LA3 3,556' 3,104' SB NA 4,358' 3,609' SB OA 4,804' 3,746' Formation at total depth: SB OA 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Surveys, Csg and Cmt Report, OH Sidetrack Summary Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Drilling Manag Contact Email: cdln er hi1cor .com Authorized ,�1�-rU �� Contact Phone: 777-8389 Signature: / Date: INSTRUCTIONS General: This form andhe required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Hilcorp Alaska. LLC Innovation KB Elev.: 5Y/ GL Elev.: 25.1' Doyon 14 Surface Casing Ref KB 58.8' 20" SW'ES tea. Z21B' t ! 4-1/2" 4. 3 f 4 e'l t t X72 9 It SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU M-24 Last Completed: 01/29/20 PTD: 219-160 Tree Cameron 3 1/8" SM Wellhead 5 7- Hanger with 3" CIW "H" BPV profile. Zea 3/8" NPT control lines. 8-1/2" Cementless Slotted Liner in 8-1/2" hole Conductor (Insulated) 215.5 / X-52 / Weld N/A 6 107' N/A 9-5/8" h 40 / L-80 / TXP 8.679" Surface 7 0.0758 7" Tieback 26/ L-80 /TXP 6.151" Surface 4,904' 0.0383 6-5/8" Slotted Liner 20 / L-80 / Hydril 563 5.924" 4,901' e'l t t X72 9 It SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU M-24 Last Completed: 01/29/20 PTD: 219-160 Tree Cameron 3 1/8" SM Wellhead FMC 11" SM TC -1A w/11" x 3 1/2" TC -II Top and Bottom Tubing 12-1/4" 2nd stage Hanger with 3" CIW "H" BPV profile. Zea 3/8" NPT control lines. OPEN HOLE/ CEMENT DETAIL 42" 50 bbls (10 Yards Pilecrete dumped down backside) 12-1/4" 1st stage L — 305 sx/ T— 400 sx 12-1/4" 2nd stage L — 417 sx / T — 270 sx 8-1/2" Cementless Slotted Liner in 8-1/2" hole CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20"x34" Conductor (Insulated) 215.5 / X-52 / Weld N/A Surface 107' N/A 9-5/8" Surface 40 / L-80 / TXP 8.679" Surface 5,066' 0.0758 7" Tieback 26/ L-80 /TXP 6.151" Surface 4,904' 0.0383 6-5/8" Slotted Liner 20 / L-80 / Hydril 563 5.924" 4,901' 14,505' 0.0355 3.813" Slotting Pattern: 4 rows, 8 slots/row, 32 slots/ft, 2" x 0.125" slots, slots on 6" centers, no slot overlap 4,950' TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP 3.958" Surface 4,950 0.0087 WELL INCLINATION DETAIL KOP @ 410' Max Hole Angle = 68 @ Jet Pump Max Hole Angle = 68 @ XN profile Max Hole Angle = 90 @ Tubing tail Max Hole Angle = 100 JEWELRY DETAIL No. Packers12 Top MD Item Drift ID 11 4,904' Upper Completion 6.151 1 22' 11" x 4-1/2" NSCT Tubing Hanger 3.970" 3 4,401' 4.5" Discharge Pressure Gauge Mandrel (Discharge Gauge) 3.874" 4 4,393' 4.5" XD Sliding Sleeve (12C 1-30-20) 3.813" 5 4,383' 4.5" Gauge Mandrel w/ X" Wire (Intake Gauge) 3.889" 6 4,419' 4.5" X Nipple (3.813" Packing Bore) 3.813" 7 4,431' 7" x 4.5" PHL Retrievable Packer 3.890" 8 4,456' 4.5" XN Nipple (MIN ID = 3.725") 3.813" 9 4,950' 4.5" WLEG 3.958" centers urwr Lower Completion 10 4,901' BOT SLZXP Liner Top Packer w/BD Slips 7" x 9-5/8" 6.170" 5.924" 13 14,505' Round nose float shoe - DAa11 IIIIII IIIIII IIIIII 6-5/$D 111111 Jts Top Top Btm Btm (MD) (TVD) (MD) (TVD) IIIIII 4,927' 3,749' 11 4,904' 7" Tieback Assy.(8.25" OD No -Go) 6.151 3,807' 6,601' 3,741' 3 12 4,922' 7" Hydril 563 L-80 x 6-5/8" Hydril 563 L-80 XO 3,606' 8 9,488' (2) Sbdl Pas 5,913' MD 9,815' 3,652' 4 1 10,133' See 10,298' 1 6,6051ND 911" 6 5/8" Slotted LINER DETAIL SON IIIIII 6-5/8" SOLID LINER DETAIL 4 rows, 8 slots/row, 2"x0.125" slots on 6" centers urwr DAa11 IIIIII IIIIII IIIIII 6-5/$D 111111 Jts Top Top Btm Btm (MD) (TVD) (MD) (TVD) 3 4,927' 3,749' 5,048' 3,747' 16 5,924' 3,807' 6,601' 3,741' 3 9,129' 3,612' 9,250' 3,606' 8 9,488' 3,614' 9,815' 3,652' 4 1 10,133' 1 3,666' 1 10,298' 1 3,656' 8-1/2' Shoe @ Hole 14,505' 73 GENERAL WELL INFO TD = 14,508' (MD) / TD = 3,579'(fVD) API: 50-029-23657-00-00 PBTD=14,508'(MD)/TD=3,579'(TVD) Surface Casing drilled/run by Doyon 14 Completed by Innovation rig on 1/29/2020 Its (Mp) Top (TVD) Btm (MD) Btm (TVD) 21 5,048' ' 3,747' 5,904' 3,807' 62 6,622' 3,739' 9,129' 3,612' 6 9,250' 3,606' 9,488' 3,614' 8 9,815' 3,652' 10,133' 3,666' 103 10,298' 3,656' 1 14,465' 0 1 3,579' Revised By: CJD 2/10/2019 Well Name: MP M-24 Field: Milne Point County/State: North Slope Borough, AK (LAT/LONG): Ovation (RKB): API #: Spud Date: Job Name: 1915943D MPU M-24 Drilling Contractor AFE #: AFE $: Hilcorp Energy Company Composite Report C' '-�- -_'t? I L.1 - S �- '_� o.. C_-_' �� d J 1P_ Activity Date ops Summary 12/2/2019 Please see M-26 drilling report for details.;Clean up cellar box and wellhead. Prep rig floor and pipe shed for rig move. Skid rig floor into moving position. *" AOGCC notified of upcoming diverter test 05:32 on 02 Dec 2019 ***;Notify pad operator, PJSM. Move rig off M-26 onto M-24. Spot Rig, Prep to level and shim rig. 12/3/2019 Skid rig floor into drilling position. Work on rig acceptance checklist. R/U all stairs and landings. R/U rig floor steam, water, air and mud lines. Spot 5 -star trailers and all support buildings. Spot Rockwasher & cuttings box. Diverter adapter and annular were installed prior to rig move.;R/U diverter line. Install surface riser. Install turnbuckles & conductor valves. Replace #2 Drag Chain and sprocket. Replace mud cleaner piping, C/O Mud Pump valve seats. Welder replacing pipe shed railing tops. *** Rig accepted at 10:00 ***;Finish R/U diverter system. Install mouse hole. Begin loading mud into the pits. Load BHA into pipe shed. Inspect saver sub & backup. Spot upright water tanks and cement silos, cont work on acceptance checklist. Cont welding pipeshed rails and C/O #2 conveyor. Test gas alarms.;M/U 2 jts HWDP & Perform diverter function test. Knife valve open in 17 sec. & diverter close in 22 sec. 3000 PSI system pressure, 1800 PSI after closure, 34 sec. 200 PSI recovery in 165 sec. full recovery. 2000 PSI avg - 6 nitrogen bottles.;Closest ignition source to end diverter 121' - Wellhouse light. 208' total length, 202' distance from rig. AOGCC rep Brian Bixby waived witness for diverter test on 12/02/2019 05:38 am.;Continue make up and rack back total of 6 stands of 5" HWDP, Jars and 1 stand of Non Mag Flex Collars.;Cut and slip 52' of drilling line. Service draworks, Topdrive and Iron Roughneck. Clean out rotary table manual brake.; Pre -spud meeting with all hands. Discuss all hazards and responsibilities. LD. safe briefing areas. Make notification to G&I and Moose Pad Operator of upcoming spud.;M/U 12-1/4" Kymera bit, 8" Terra Force mud motor w/ 1.5° AKO, XO sub to 37'. M/U stand of 5" HWDP and tag ice at 81'. Gyro Data on standby.;All hands in position to drill. Fill standpipe, kelly hose conductor & stack w/ water, no leaks. Pressure test to 3500 PSI - good test. Clean out conductor f/ 81't/ 114' with 400 GPM & 40 RPM.;Drill 12-1/4" surface hole f/ 11 4' t/ 219', 105' drilled, 106/hr AROP. Drill 1 st 10'w/ fresh water then displace to 8.8 ppg spud mud. 450 GPM, 600 PSI, 40 RPM, 3K TO, 4K WOB. 53K PU / 53K SO / 53K ROT.;BROOH f/ 219' t/ 124' 450 GPM, 580 psi, 40 RPM. Pull out on elevators from 124' to top of mud motor at 37'.;Hauled 520 bbls H2O from 6 -Mile Lake for total = 520 bbls Hauled 0 bbls H2O from B -Pad Creek for total = 0 bbls Hauled 0 bbls Source Water from G&I = 0 bbls Hauled 0 bbls from A -Pad = 0 bbls Hauled 0 bbls cuttings/mud/cement = 0 bbls 12/4/2019 M/URemaining BHA #1 (DGR, EWR, Directional, PWD, HCIM, TM & UBHO) to 94'. Plug in, confidence test and initialize tools. RIH with three NMDC to 185'. M/U stand of HWDP, RIH t/ 219' and shallow pulse test MWD.;Drill 12-114" surface hole f/ 219't/ 367', 148' drilled, 497hr AROP. 450 GPM, 1240 PSI, 40 RPM, 3-5K TQ, 10K WOB. 8.8 ppg MW, 245 vis, ECD 9.3 70K PU / 68K SO / 70 ROT Kick off @ 367' 3°/100' BUR.; Drill 12-1/4" surface hole f/ 367' t/ 1123' (1087' TVD), 756' drilled, 126/hr AROP. 480 GPM, 1430 PSI, 60 RPM, 6-8K TQ, 10-12K WOB, 9.1 ppg MW, 259 vis, ECD 10.1 PU 90K / SO 92K / ROT 92K, max gas 11 u. Continue 3°/100' BUR, at 550' build with 4*/100'.; Drill 12.25" surface hole f/ 1123' t/ 1817' (1658' TVD) 694' drilled, 115.6'/hr AROP. 480 GPM, 1510 PSI, 60 RPM, 4-5K TO, 12-13K WOB. Max gas 55u. 9.2 ppg MW, 209 vis, 10.4 ECD. 97K PU / 90K SO / 97K ROT. End 4*/100' build at 1467'. Hold 40° tangent.;Drill 12.25" surface hole f/ 1817't/ 2644' (2323' TVD) 827' drilled, 137.83/hr AROP. 500 GPM, 1510 PSI, 60 RPM, 4-5K TO, 3-5K WOB. Max gas 25u. 9.25 ppg MW, 120 vis, 10.2 ECD. 117K PU / 105K SO / 110K ROT. Base of permafrost @ 2068' MD / 1849' TVD. Begin 4°/100' drop and turn at 2073'.;Top of Ungu logged at 2543' MD, 2236' TVD. Hi Vis Sweep pumped at 2548' returned to surface on calculated strokes wl 25% increase.;Just after making connection @ 2256' Drag chain on # 2 conveyer stalled due to ice buildup on rollers, backream full stand slowly at Kelly down, 285 GPM, 850 psi, while clearing drag chain of ice. Last survey at 2581.44' MD / 2269.30 TVD, 29.36° inc, 300.00° azm, 4.38' from plan, 0.96' high & 4.28.;No losses on the day Hauled 910 bbls H2O from 6 -Mile Lake for total = 1430 bbls Hauled 0 bbls H2O from B -Pad Creek for total = 0 bbls Hauled 0 bbls Source Water from G&I = 0 bbls Hauled 0 bbls from A -Pad = 0 bbls Hauled 1087 bbls cuttings/mud/cement = 1087 bbls 12/5/2019 Drill 12.25" surface hole f/ 2644't/ 3214' (2826' TVD) 570' drilled, 95'/hr AROP, 530 GPM, 1660 PSI, 80 RPM, 14K TO, 14K WOB. Max gas 26u. 9.25 ppg MW, 120 vis, 10.2 ECD. 145K PU / 110K SO / 124K ROT. Continue drop and turn @ 4*/100'.;Hi Vis Sweep pumped at 2548' returned to surface on calculated strokes wt 25% increase Backream 30' at connections.; Drill 12.25" surface hole f/ 3214't/ 3908' (3355' TVD) 694' drilled, 115.66'/hr AROP. 550 GPM, 2030 PSI, 80 RPM, 10-11 K TO, 5K WOB. Max gas 98u. 9.2 ppg MW, 131 vis, 10.5 ECD. 163K PU / 109K SO / 130K ROT. Pump Hi Vis sweep @ 3500', Return on time with no increase observed.;Drill 12.25" surface hole f/ 3908' tt 4453' (3649' TVD) 545' drilled, 90.83/hr AROP. 540 GPM, 2000 PSI, 80 RPM, 12-17K TO, 15K WOB. Max gas 828u. 9.35 ppg MW, 153 vis, 10.1 ECD. 165K PU / 107K SO / 130K ROT.;Seeing high torque swings and signs of packoff while backreaming after Kelly down at 4451', continue to backream full stand. Top of SB_N sands @ 4358' MD / 3609' TVD.;Drill 12.25" surface hole f/ 4453'V 4833' (3753' TVD) 380' drilled, 63.3/hr AROP. 550 GPM, 2260 PSI, 80 RPM, 10-15K TO, 10-12K WOB. Max gas 173u. 9.4 ppg MW, 152 vis, 10.1 ECD, 160K PU I 105K SO / 125K ROT. Pump Hi -Vis Sweep at 4645', Returned 300 stks late with 10% increase.;Cross a fault at 4545' with a 30' DTN throw moving the wellbore from the lower SB_ND into the base of the SB_NE Top of SB_OA Sands @ 4813' MD / 3750' TVD. Last survey at 4771.60' MD / 3742.07 TVD, 78.31* inc, 190.56° azm, 5.22' from plan, 4.57' high & 2.54' right.;Daily losses = 0 bbls, Cumulative losses = 0 bbls Hauled 1675 bbls H2O from 6 -Mile Lake for total = 3105 bbls Hauled 0 bbls H2O from B -Pad Creek for total = 0 bbls Hauled 0 bbls Source Water from G&I = 0 bbls Hauled 0 bbls from A -Pad = 0 bbls Hauled 1852 bbls cuttings/mud/cement = 2939 bbls 12/6/2019 Drill 12.25" surface hole F/ 4833' TI 5072' (3753' TVD) 239' drilled, 119.5/hr AROP. 520 GPM, 1680 PSI, 80 RPM, 10-12K TO, 10-12K WOB. Max gas 977u. 9.3 ppg MW, 60 vis, 10.1 ECD. 165K PU / 100K SO / 125K ROT. ECDs 9.8.; Pump 70 bbl High vis sweep with nut plug. Came back on time with Minimal increase in cuttings. Brought back an increase in clay/ looked like wall cake. Monitor well. Static. Pull two stands while back reaming.;RIH to btm with no pumps. Back ream out F/ 5072'T/ 1650' at 550 gpm, 80 RPM, 12 K TO. 125K ROT wt. MW 9.2, Back ream at 5 min per stand & slow for pressure increases. Slow pumps to 450 & 60 RPM at 1650' when shakers loaded up. Pulled slow letting the well clean up. Cleaned up after btm up.;Continue back reaming out F/ 1650'T/ 750'. Got back sand and silt very fine. 450 GPM, 60 RPM. UD all Dp in 90' Mouse hole while back reaming out. Separate joints to send in for cat 5 inspection. Notify casing crew and HES of upcoming casing run.;Monitor well, Static. Blow down TopDrive. Pull out of hole on elevators to the MWD tools, laying down HWDP, Jars & Flex Collars to pipe shed. Hole to calculate fill on the trip out.;Down load tools & clean up rig floor. UD BHA from 91'. Bit Grade 1 -1 -WT -A -E -1 -NO -TD. Clear BHA components and clean rig floor. 2.5 bbl/hr static losses.; Rig up to run 9-5/8" casing. M/U Doyon Volant casing running tool with cement swivel, 4' bail extensions, 9-5/8" elevators, spiders and strap tongs. 2 BPH static losses. Hold PJSM for running casing.;M/U 9-5/8" 40# L-80 TXP BTC -SR casing shoe track to 159.98' - float shoe joint, spacer joint, float collar joint w/ bypass baffle installed and baffle adapter. Thread lock connections & torque to 20,960 ft/lbs with Doyon Volant tool. Check floats - good.;Two 9-518"x12-1/4" Expand-o-lizers w/ 4 stop rings installed on shoe joint, one floating on spacer joint, one each with two each stop rings on joints #3 & 4. 2 BPH static Iosses.;Run 9-5/8" 40# L-80 TXP-BTC casing f/ 160't/ 1841'. TO to 20,960 ft/lbs w/ the Volant tool. Install one 9-5/8"x12-114" Expand-O-Lizer every joint #1-21, every other jt #23-43 Fill pipe on the fly & top off every 10 joints. 13 BBL losses at this point.;Daily (midnight) losses = 6 bbis, Cumulative losses= 6 bbis Hauled 1375 bbis H2O from 6 -Mile Lake for total= 4480 bbis Hauled 0 bbis H2O from B -Pad Creek for total= 0 bbis Hauled 290 bbis Source Water from G&1= 290 bbis Hauled 0 bbls from A -Pad= 0 bbis Hauled 1152 bbis cuttings/mud/cement= 4091 bbls 12/7/2019 Run 9-5/8" 40# L-80 TXP-BTC casing F/ 1841'T/ 2800'. TO to 20,960 ft/lbs w/ the Volant tool. Install one 9-5/8"x12-1/4" Expand-O-Lizer every joint #1-21, every other jt #23-43. Fill pipe on the fly & top off every 10 joints. 13 BBL losses at this point.;Break circ & stage up pumps to 6 bpm at 150-200 psi. Wok pipe 40'. Circ btm up with fine sand and silt in returns. Very little cuttings. Circ 1.5 btm up.;Run 9-5/8" 40# L-80 TXP-BTC casing F/ 2800'T/ 5050'. TO to 20,960 ft/lbs w/ the Volant tool. Install one 9-5/8"x12-1/4" Expand-O-Lizer every joint #1-21, every other jt #23-43 Had to change out Joint # 116 due to bad pin. Ran Joint 127 at the end to M/U for 116.;M/U 20' pup & stage up pumps to 8 bpm at 300 psi. ROT at 10-20 RPM at 16K max. Stall when pipe not moving. Work pipe 20' while circulating two btm up. Mud in good shape on one shaker. Conduct PJSM, Prep for cmt job. 23 bbl loss total while running casing.;BLow down TD, M/U cmt lines, Pump 50 bbl treated mud in front of cmt job with rig. line up to HES & pump 5 bbl water. test lines to 1000/ 4000 psi. Good.;Mix & pump 60 bbl Tuned spacer at 10 ppg at 5 bpm Drop bypass plug. Mix & pump 128 bb112 ppg Lead cmt at 4-5 BPM. 305 sx Mix & purnp 82 15.8 ppg Tail cmt at 3- 5 BPM. (400 sx) Drop closing opening plug. HES pump 20 bbl water Chase with rig 177 bbl mud.;Line up to HES & pump 80 bbl Tuned Spacer at 9.2 ppg. Line back up to rig & pump 94.75 bbis to bump opening plug. Bump 33 stks early f/ calculated. Pressure to 1200 psi and hold, bleed off pressure check floats - good. pressure to 2660 psi, shifting cementer open_.; Reciprocated and rotated 1-5 rpm, 16k torque throughout the job until last 15 bbls before burnping plug. 52 bbl losses while pumping and displacing cement. Casing set in tension with the shoe @ 5066' CIP @ 19:00. 52 bbis loss while cementing.;Circulate hole from Ebu up bpm, 210 psi. 120 bbis pumps spacer returns, 1bu bbis thic ntaminated returns diverted to rockwasher, 230 bbls pumped start taking good mud back to pits. Total of 95 bbis spacer and thick mud overboarded. Spacer,PolEFlake and trace cement observed @ surface.;Continue to circulate a total of 3x btm up through ESC at 6 BPM, 210 psi while working string f/ 125K PUW t/ 225k PUW.;Shut down, flush bag, riser, flow line and surface equipment. Inspect Volant tool, clean die and lubricate cup.;Continue to circulate through ESC @ 6 BPM while WOC to reach 100 psi compressive strength in 7 hrs. SimOps: Pull mouse hole and install new MPD valve on BOP stack. Hold PJSM on 2nd cement stage w/ Doyon, Halliburton, M -I and Peak. MW 9.25, vis 46, YP 7, P/U 275K, S/O 95K.;PT lines w/ H2O t/ 1200 psi low 4100 psi high. Pump 60 bbl of 10 ppg tuned spacer with 4# red dye and 0.5 ppb Poly flake in the 1st 10 bbis at 5 BPM 280 psi Pump 327 bbis of 10.7# lead Perm L Cmt. (417 SX), at 6 BPM 590 psi . Pump 56.2 bbl of 15.8 Tail cmt. (270 SX) at 5 BPM 520 psi;Drop closing plug. Pump 20 bbis H2O. Line up to rig for displacement with 9.25 ppg spud mud. Pump 151 bbls at 6 BPM. Bump plug 32 strokes late. Slowed down t/ 3 BPM last 10 bbis. Pressure to 1400 psi,1000 psi over FCP at 400 psi, and observe ESC shift closed. Bleed down. No flow.;Got mud push back with 173 bbis Lead pumped, spacer was strung out and clabbered. CIP at 04:34 with 204 bbl total good lead cmt back to surface. No losses recorded during 2nd stage.; Disconnect knife valve, drain stack and flush with black water, functioning bag several times. Flush all surface equip with black water and blow down. Remove mousehole. Start N/D diverter line. Prep to lift 20" diverter equipment. SirnOps: Cleaning Mud Pits.;Daily losses = 69 bbis, Cumulative losses = 75 bbis Hauled 710 bbis H2O from 6 -Mile Lake for total= 5190 bbis Hauled 0 bbis H2O from B -Pad Creek for total= 0 bbis Hauled 415 bbis Source Water from G&1= 705 bbis Hauled 0 bbis from A -Pad= 0 bbis Hauled 1183 bbis cuttings/mud/cernent= 5274 bbis 12/8/2019 Lift 20" diverter equip. Install casing slips as per wellhead rep. with 140K on slips. Cut casing. UD out jt. (16.94' total cut).;N/D Surface stack, Riser and Diverter Tee.;N/U Well head, test WH to 500 psi for 5 min and 2480 psi for 10 min as per Wellhead rep, good test, N/U tbg spool. Remove 4" valves on conductor and install caps. SimOps: Cleaning pits, UD 9-5/8" casing tools, RID H2O pump house & tank farm;R/U 3 1/2" handling equipment and prep celllar for mud returns.;PJSM, M/U Mule shoe, P/U and RIH w/ 3 112" 9.3# L-80 EUE kill string to 2147' torque to 2300 ft/lbs, Monitor returns going to cellar box from open annulus valve. Vac out cellar. M/U pup jt/tbg hanger, & landing jt. Land hanger w/ 15k on hanger. PU/SO 57k/55k. Mule Shoe set @ 2185' MD / 1940' TVD.;RILDS, LID landing jt. Test hanger void. Install BPV, NU adaptor and tree, test tree to 250/5000 psi 5 min ea. Pull BPV. SimOps: Rig up to reverse circulate for freeze protect.;Pump 211 bbis H2O down IA taking returns through tubing to rockwasher 5.3 BPM, 1000 psi. Pump 170 bbis diesel down IA, taking returns through tubing to rockwasher, divert last 31 bbls to cuttings tank.; 158.7 bbis diesel freeze protect left in wellbore. Submit 24 hour Diverter test notification to AOGCC.;Biow down lines to cuttings tank, rig down lines. Clean cellar box & wellhead. Empty cuttings box at rockwasher. Rig down mud pumps, prep pits for move. Cut and cap mousehole in cellar box. Rig released @ 03:OO.;Move rig to M-23. See M-23 drilling report for details.;Daily losses = 0 bbis, Cumulative losses = 75 bbis Hauled 200 bbis H2O from 6 -Mile Lake for total= 5390 bbis Hauled 0 bbls H2O from B -Pad Creek for total= 0 bbls Hauled 0 bbis Source Water from G&1= 705 bbls Hauled 0 bbis from A -Pad= 0 bbis cc Hauled 1120 bbis cuttings/mud/cement= 6394 bbis 1/7/2020 Continue heating and pressure up tires. Perform pre -rig move checklist. Perform SRL checklist. Work on valves in pits, grease gun lines. Work on hitch paper work. Remove cuttings box and berm. Grease choke manifold 1/8/2020 Continue to assist Peak tire rep with pressuring up and checking tires. Blow down all steam and disconnect air and steam lines at interconnects. Pick up stairs around rig. disconnect and pull break shack and environvac away. Rig down electrical.; Pull mods away from Subbase. Back subbase off M-26.;Spot and center sub over M-24, using Sow with mud product on back and dozer due to poor traction.;Set rig mats. Spot catwalk, pipe shed. Start spotting Mud mod.; Spot mud mod, Spot Beyond choke house. set rig mats and spot Gen mod. Spot auxiliary equipment. Start hooking up interconnects and electric. 1/9/2020 Continue hooking up inner connects between pits, gen and catwalk mods. Move envirovac, break shack and hardline racks from ODS of rig to allow wells group enough room for M-26 tie in. Prepped and scope derrick. Prep pits to take on mud. Dress shakers w/ 3x 170's and 1x 170 (each shaker).;PJSM, Bridle down and set hoisting limits on drawworks. Install BPV. Break tbg adapter flange on dry hole tree and N/D same. Verify tbg hanger threads (4.5" NSCT). Load 5" DP in shed. Stage in tree in cellar and secure same.;Check hanger threads. Install DSA and TQ. N/U BOPE. Install aluminum drip pan, hook up beyond MD plumbing. Hook up choke and kill lines. Center stack and install riser. Install hole fill. SimOps: Cont. processing 5" drill pipe in shed. Hang rig tongs.;M/U test sub into top drive. Obtain RKBS'. M/U 5" test joint with dart and TIW.;Fill lines and purge air. Check for leaks. Observe thread end on annular side of stucchi Ieaking.;Bleed of accumulator. Remove stucchi and inspect threads. Redress and re -connect. Hook up accumulator lines and pressure up. - no leaks. Rig accepted at 01:30.;M/U test hoses. Fill lines and purge air. Test BOPE's 250/3000 psi 5" test joints. Witnessed by AOGCC Austin McLeod. Change out test joints to 3-1/2".;Daily hauled 0 bbls to G&I total = 0 bbls Daily hauled 580 bbis from 6 mile creek total =580 bbis Daily Fluid lost 0 bbls total = 0 bbis 1/10/2020 Continue testing BOP's 250/3000 psi w/ 5 min hold on each. Chart and record same. No failures. Witnessed by AOGCC rep Austin McLeod. Drawdown test initial 3000 psi, draw down 1350- 23 sec 200 PSI, 100 sec full. NO2 Avg 2341 psi.. R/D and clear test lines and equipment.; Remove flow nipple from RCD. Install MPD test cap and test same. 200/1000 w/ 15 min hold on high (test good). Remove test cap and re -install flow nipple.;Attempt to remove CTS from BPV. Unable to engage with "T" bar. Vac out stack and flush top of BPV profile. Remove rubber debris from BPV profile. Engage top of CTS profile and pull same. Remove BPV. Monitor IA (static). M/U Landing jt w/ NC -50x4.5" IBT XO. BOLDS.;Work hgr off seat with 5" movement before overpull. Work overpull staging up to 125k before pulling clean @ 54k up, 51 k dn. Pull up 5' & stage up T/11 bpm, 210 psi pump heated FW around displacing diesel (freeze protect) to cuttings box. Pump a total of 270 bbls. Shut down. B/D TDS.;PJSM, R/U Weatherford casing equipment. Pull hanger to floor. Found granular sediment on top of hanger profile (1-2" thick). Clean hanger assy and L/D same. B/O xo's. Continue POOH F/ 2185to surface laying down 3.5" 8rd, L-80, 9.3# kill string. R/D and UD Weatherford casing equipment.;PJSM R/D L/D Weatherford Dbl Stacks and handling Equip.;PJSM Install Wear Ring 38" L 10.75" OD 9" ID. R/U rig tongs and handling Equip.;PJSM P/U M/U 8.5" Bit Smith XR-PS (Dull In 1 -1 -WT -A -E -1 -NO -BHA) 6 3/4" 1.15° StrataForce Lobe 6:7 - 6stg, 6 jnts 5" HWDP, 6 3/4" SLB Hydra Jars and 11 jnts 5" HWDP 593.56' MD. At 120' MD set down 8K started washing down at 205 GPM, 150 PSI due to ice. Drift 5" HWDP 2.75" OD.;PJSM Cont washing down at 205 GPM, 150 PSI P/U singles 5" D.P. Fl Skate F/ 594' to to 1,135' MD . Seeing 50-70 PSI Diff W/ 10 ft/min. Made a few attempts to run on elevators setting down 10K. Cont on elevators F/ 1,135' to 2,153' MD P/U 92K, SLK 79K. Drift 5" D.P. 3.125" OD.;Washed down F/ 2,153'350 GPM, 280 PSI tag drill cement F/ 2,186' to 2,211'W/ 350 GPM, 280 PSI, 50 RPM, TRQ 3.5-5.5K, WOB 3-7K. P/U 92K, SLK 79K. Drill ES F/ 2,211' to 2,214'MD 400 GPM, 620 PSI, 50 RPM, TRQ 4-5K, WOB 3-7K. Had a couple stalls and slight over pull during drilling.;Wiped through 2X full drill rate and once W/O rotary F/ 2,223' to 2,209' P/U 97K, SLK 79K. CBU 1.5X W/ cement and rubber at Shakers.;Shut down RIH to 2,253' MD tagged up W/ 15K down. Started washing down F/ 2,253' to 2,276' MD W/ 350 GPM, 500 PSI, 15 RPM, TRQ 4K, WOB 6K. PIU 103K, SLK 80K, ROT 88K. Appears to may be cement.;Daily hauled 114 bbis to G&I total = 114 bbis Daily hauled 380 bbis from L Pad total =960 bbis Daily Hauled 150 bbis to ORT. Daily Fluid lost 0 bbis total = 0 bbis 1/11/2020 Continue wash down F/ 2276' - T/ 2728' MD. 350 gpm, 500 psi, 15-40 rpm, 4k tq, 103k up, 80k dn, 88k rot while singling in (drift 3.125"). Washing debris down with several stalls. No overpull when corning off stalls.;Trip 3xjts in clean. B/D TDS and continue trip in on elevators. TIH F/ 2728' - T/ 4865' MD singling inform shed (drift 3.125"). Calc disp for trip. Tagged cmt early @ 4865' MD w/ 8k tag. 151 k up, 86k dn.;Drill cmt F/ 4865'- T/ 4917' MD just above V BFL. 350 gpm, 780 psi, 30 rpm, 14k tq, 3-7k WOB.;CBU @ 4917' MD (Rot/Recip). 350 gpm, 560 psi, 30 rpm, 12.5k Tq. Saw hard cmt cuttings back at rs shakers.; R/U to test 9-5/8" casing. Flood choke, kill and close top rams. Purge air from system. Pump @ 1/2-3/4 bpm to 2500 psi w/ 30 min hold (chart and record same). 2.7 bbis pumped, 2.7 bbis bled back.; Cont drill f/ 4917' to 5,065' MD 500 gpm, 1210 psi, 40 rpm, 12.5k Tq, 14K WOB. 161 k up, 82k dn, 111 k C rot. Bfl @ 4936', FC @ 4976'. FS @ 5059' MD.;PJSM Cont to drill F/ 5,065' to 5,095' MD 25' new hole. 350 GPM, 700 PSI, 40 RPM, TRQ 12.5K, WOB 10K, �h P/U 171, SLK 78K, ROT 113K. Good cured cement st Shakers.;PJSM Displace Spud Mud down drag chain W/ 40 bbl Hi Vis Spacer and 329 bbls 8.95 ppg Baridril-N. Heavy cement seen at Shaker at BU. Max Gas 300 U. Circ until weight 9.85 in & out. Rack back 1 stand to 5,044' MD. Monitor well, static.;SPR at 5,095' MD (3,746' TVD) W/ 8.95 MW. MP #1 32-236. 48-271. MP #2 32-233, 48-268.;PJSM Install Head Pin and testing lines. Flood and circ through lines � � and Choke Manifold. Perform FIT to 12 ppg, 604 PSI. Pumped 1.1 bbls, Bled 0.75 bbis. Blow down and R.D Equip.;PJSM POOH racking back 5' D.P. F1 5,044' to 531' MD. Rack back 1 stand 5" HWDP and Jar stand. UD 5" HWDP. No losses. P/U 54K, SLK 52K.;PJSM P/U 5" D,P. F/ Skate and RIH to 1,622' MD. P/U 58K, SLK 57K. No losses. Drift 3.125" OD.; Daily hauled 682 bbis to G&I total = 796 bbis Daily hauled 260 bbis from L Pad total =1,220 bbis Total Hauled 160 bbls to ORT. Daily Fluid lost 0 bbis total = 0 bbis 1/12/2020 Single in picking up 5" NC -50 F/ 1,622'- T/ 5015' MD. Rack back to 4302' then single in again to 5015' MD. Monitor well (static).;POOH F/ 5015'- T/ surface. UD 8.5" rntr assy. Bit grade 1,1, WT,G,E,1,NO,BHA. Hole took calculated displacement.; Clean and clear rig floor. Bring BHA components to rig floor. Prep floor for BHA and trip in.;M/U 8.5" RSS later assy - 8.5" NOV SK616M-J1 D PDC (TFA .777) w/ 8.5" NRP (bit sleeve), 7600 GeoPilot, MWD/LWD w/ FS (non ported), 2x NM Flex DC's, Fs (non ported), 2x 5" NC -50 HWDP, SLB Hydra jars, lx jt 5" NC -50 HWDP.Total length=275.98'.; Upload MWD. Corrosion Ring top of FC. Sym Ops - Remove mule from derrick board for troubleshooting possible electrical fault.;PJSM Single in BHA W/ 5" D.P. S-135 NC 50 F/ 275' to 4,724' MD P/U 140 Jnts (Drift 3.125" OD) Break in GeoPilot and Shallow hole test at 2,500' MD 475 GPM, 1,050 PSI, P/U 120K, SLK 82K.;PJSM RIH 5" D.P. F/ Derrick F/ 4,724' to 4,969' MD P/U 120, SLK 82K. No losses for trip.;PJSM Fill Pipe and Circ at 3 bpm, 230 PSI while slip and cut drilling line. Cut 63' 10 wraps. Accum TM 23,259. 1,734' left on spool. Check Deadman bolts 225 ft/lbs. Check Brake gaps. Unhang Blocks. Set Drawwork parameters and check Iimits.;PJSM Grease Crown, Blocks, Top Drive, Wash Pipe, IBOP and Spinners. Check oil in Top Drive. Open coffin lid and tighten multiple hydraulic fittings.;PJSM P/U RCD. Drain and pull riser. Install RCD and bearing on Stack as per Beyond Rep onsite. Flood lines and Circ, through MPD Equip, no Ieaks.;PJSM Circ. and obtain ECD drilling parameters at 4,969' MD. Rotate at 80 RPM, TRQ 11 K. 350 GPM 9.76 ECD, 400 GPM 9.88 ECD, 450 GPM 9.95 ECD, 500 GPM 10.1 ECD. P/U 145K, SLK 88K, ROT 105K. SPR 5,040' MD (3,746' TVD) MW 9.1. MP 91 32-185, 48-235. MP #2 32-185, 48-235.;PJSM Drill 8.5" Production Hole F/ 5,095' to 5,265' MD ( 3,746' TVD) total 170' (AROP 68') 500 GPM, 1,395 PSI, 130 RPM, TRQ 12-13K, WOB 6-13K. P/U 144K, SLK 70K, ROT 105K. Max Gas 976U. MPD 499 GPM 100% open. Running H2O 15 bph. Both Centrifuges. Currently targeting -90° as per rig site Geo.;Distance to WP #5: 21.23', 21.22' high, 0.60' left.; Daily hauled 40 bbis to G&I total = 836 bbis Daily hauled 130 bbls from L Pad total =1,350 bbis Total Hauled 160 bbis to ORT. Daily Fluid lost 8 bbls total = 8 bbis 1/13/2020 Continue Drlg 8.5" Production Hole F/ 5,265'- T/5,803' MD ( 3,777' TVD) (538 total / AROP 108') 545 GPM, 1,730 PSI, 130 RPM, TRQ 12-14K, WOB 6-15K. 158k up, 68k dn, 104k rot. Max Gas 1730u. MPD full open choke. Screened up to 170's on both shakers.; Reduced inclination to drop in section from OA -1 into the OA -3. Dip was lower than expected and we exited out the top around 5475'. Continue drilling ahead reducing Inc and re-entered OA -1 @ 5700' MD. Continue drlg ahead to 5803' before stopping to sidetrack.; Unable to meet well objectives exposing OA -3 sands in first fault with current wellbore trajectory. Decision made to pullback just outside 9-5/8" shoe and sidetrack.; POOH on elevators F/ 5803' - T/ 5450' MD then Backream out to 5095' MD. 330 gpm, 730 psi, 65 rpm, 12k tq, 160k up, 70k dn, 104k rot. ST #1 - 5095' to 5,803' MD.;Perform open hole side side. F/ 5,095' to 5,131' MD. Control drill at 10 ft/hr as per DD, WOB 0, 420 GPM, 1,050 PSI, 80 RPM, TRQ 10.8K, P/U 160K, SLK 80K. Holding 100% deflection 160° R to gain separation. Picked back up to 5,095' and RIH to 5,115' MD.;Lost high line power and went to Gen power at 18:10.;Cont control drilling at 5 ft/hr F/ 5,116' to 5,131' MD W/ 0.3" to 0.4° different from parent well but the trend difference was not increasing to confirm separation. May be due to concretions. Started control drilling F/ 5,131' to 5,175' MD. Geologist suggested 5,165' for sidetrack.; Troughed for 15 minutes and resumed time drilling with 5 fph 5,175' with 100% deflection , 160°R TF ROP was gradually increased from 5 fph 5,175' to 50 fph to 5,230'. AT 5,176' 89.97° , Old well 89.96°. 5,213'88.99', Old well 90.05°.;450 GPM, 1,165 PSI, 100 RPM, TRQ 10.8K, ECD 9.87, Max Gas 228U P/U 150K, SLK 75K, ROT 103K.;PJSM Drill 8.5" Production Hole Fl 5,230' to 5,463' MD ( 3,776' TVD) total 233' (AROP 77.6') 500 GPM, 1,440 PSI, 120 RPM, TRQ 12.5K, WOB 4-10K. P/U 149K, SLK 69K, ROT 103K. Max Gas 918U. MPD 500 GPM 100% open. Back ream 15-20' every stand. Currently targeting 84" as per rig site Geo.;7 concretions have been drilled in the motherbore so far for a total footage of 33' (11.2% of the lateral section). Distance to WP #5: 43.62', 43.59' high, 1.65' left.; Daily hauled 342 bbis to G&I total = 1,178 bbis Daily hauled 510 bbis from L Pad total =1,860 bbis Total Hauled 160 bbls to ORT. Daily Fluid lost 0 bbis total = 8 bbis 1/14/2020 Drill 8.5" Production Hole F/ 5,463' to 6,060' MD ( 3,805' TVD) total 597' (AROP 995) 530 GPM, 1,725 PSI, 120 RPM, TRQ 14K, WOB 8-15K, ECD 10.7, P/U 164K, SLK 63K, ROT 104K. Max Gas 1,095U. MPD 530 GPM 100% open. Back ream 30' every stand.;Crossed Fault 1 at 5,992' MD Build 100° 55' DTN. Went to high line at 09:00. SPR at 6,060' (3,804' TVD) MW 9.2 ppg. MP #1 32-255, 48-315. MP #2 32-255, 48-315.;Drill 8.5" Production Hole F/ 6,060' to 6,700' MD ( 3,729' TVD) total 640' (AROP 106.6') 530 GPM, 1,860 PSI, 120 RPM, TRQ 14.5K, WOB 8-15K, ECD 11.16. P/U 165K, SLK 58K, ROT 101 K. Max Gas 820U. MPD 530 GPM 100% open. Back ream 30' every stand. Entered OA -3 at 6,688' MD.;SPR at 6,503' (3,759' TVD) MW 9.15 ppg. MP #1 32- 272, 48-330. MP #2 32-275, 48-336.;Drill 8.5" Production Hole F/ 6,700' to 7,331' MD ( 3,699' TVD) total 631' (AROP 1052) 530 GPM, 1,890 PSI, 120 RPM, TRQ 10K, WOB 8-15K, ECD 11.07. P/U 128K, SLK 81 K, ROT 101 K. Max Gas 1,011 U. MPD 525 GPM 100% open. Back ream 30' every stand. OA -3 Sand 6,688'-6,948'.; Increased Lube F/ 1.5% to 2%, Running H2O 35 bph. SPR at 7,705' (3,706' TVD) MW 9.2 ppg. MP 91 32-240, 48-305. MP #2 32-245, 48- 305.;Drill 8.5" Production Hole F/ 7,331' to 7,808' MD ( 3,673' TVD) total 477' (AROP 795) 530 GPM, 1,810 PSI, 120 RPM, TRQ 10K, WOB 8-15K, ECD 11.07, P/U 131 K, SLK 76K, ROT 99K. Max Gas 1,088U. MPD 525 GPM 100% open. Back ream 30' every stand. OA -1 Sand 7,305' to current depth.;SPR 7,583' (3,676' TVD) MW 9.2. MP #1 32-205, 48-265. MP #2 32-205, 48-265.;24 concretions have been drilled in the motherbore so far for a total footage of 148' (5.6% of the lateral section). OA -1 805', OA -2 201', OA -3 683', Cumulative OA Sand 1,913', Cumulative out 737'.;Distance to WP #5: 35.08', 26.86' low, 22.56' right.;Daily hauled 570 bbis to G&I total = 1,748 bbis Daily hauled 650 bbis from L Pad total =2,510 bbis Total Hauled 160 bbis to ORT. Daily Fluid lost 22 bbis total = 30 bbis 1/15/2020 Drill 8.5" Production Hole F/ 7,808' to 8,540' MD ( 3,659' TVD) total 732' (AROP 122') 530 GPM, 1,905 PSI, 120 RPM, TRQ 15.5K, WOB 8-15K, ECD 10.79, MW 9.2, P/U 135K, SLK 67K, ROT 97K. Max Gas 1,100U. MPD 525 GPM 100% open. Back ream 30' every stand. Building Inc to 96 deg.;Went out bottom to OA -4 F/ 8,240' to 8,500' MD (260'). SPR at 8,157' MD (3,682' TVD) MW 9.2. MP #1 32-245, 48-300. MP #2 32-245, 48-305.;Drill 8.5' Production Hole F/ 8,540' to 9,200' MD ( 3,607' TVD) total 660' (AROP 110') 530 GPM, 2,150 PSI, 120 RPM, TRQ 18.5K, WOB 12K, ECD 11.44, MW 9.2, P/U 160K, SLK 35K, ROT 93K. Max Gas 1,065U. MPD 525 GPM 100% open. Back ream 30' every stand.;Went out top OA -1 F/ 9,128' to 9,240' MD (112'). SPR at 8,157' MD (3,682' TVD) MW 9.2. MP #1 32-245, 48-300. MP #2 32-245, 48-305.; Drill 8.5" Production Hole F/ 9,200" to 9,810' MD ( 3,674' TVD) total 610' (AROP 1017) 500 GPM, 2,010 PSI, 120 RPM, TRQ 15K, WOB 8-12K, ECD 11.55, MW 9.2, P/U 140K, SLK 35K, ROT 92K. Max Gas 1,217U. MPD 525 GPM 100% open. Back ream 30' every stand.;At 9,503' MD hole took about 15 bbls and regained parameters at 9,533' MD. Slight breathing at connections. Reduced F/ 530 GPM to 500 GPM, MPD 490 GPM. Held 95° Inc at 9,503' MD increased to 100° Inc looking for markers. Geo verified NE Sand. Decision was made to POOH to 9,325' to sidetrack.;SPR at 9,810' MD (3,674' TVD) MW 9.2. MP #1 32-400, 48-460. MP #2 32-402, 48-482.;BROOH F/ 9,810' to 9,325' MD 310 GPM, 985 PSI, 30 RPM, TRQ 11.5K, Max Gas 838U, ECD 10.8. P/U 133K, SLK 59K, ROT 103K.;Side track operations F/ 9,325" to 9,359' MD 450 GPM, 1,650 PSI, 80 RPM, TRQ 14.5K, WOB 0.5K, MW 9.2, ECD 11.04, Max Gas 519U. MPD 440 GPM 100% open.;Set Geo Pilot to 100% deflection and 180° TF. Troughed down to 9325' for 15 minutes. Time drilling sidetrack F/ 9325' to 9445' ROP F/5-50 fph with 450 gpm, 80 rpm, 1600 psi. ABI started showing inclination dropping from 9325'.;9325'90.58* Old well 90.75°, 9338'89.78*. Old well 91.19°. ABI at Kelly down 9359'-88.99' Old well 91.81'.;Drill 8.5" Production Hole F/ 9,359" to 9,590' MD ( 3,628' TVD) total 231' (AROP 77') 530 GPM, 2,165 PSI, 120 RPM, TRQ 14.5K, WOB 4-12K, ECD 11.48, MW 9.3, PIU 135K, SLK 35K, ROT 94K. Max Gas 1,217U. MPD 519 GPM 100% open. Back ream 30' every stand. Lost SLK @ 9,559' MD. Dump 190 bbl for Wt & MBT.;SPR at 9,493' MD (3,611' TVD) MW 9.3. MP #1 32-350, 48-415. MP #2 32-350, 48-420.;Fault #2 at 9,503' MD 74' DTS. 34 concretions drilled in the motherbore, total footage of 209'(4.7% of the lateral section) OA -1 129', OA -2 530', OA -3 1,235', Cumulative OA Sand 3,378', Cumulative out 849'. Distance to WP #5: 42.04', 41.84' low, 4.03' left.; Daily hauled 1,383 bbls to G&I total = 3,131 bbis Daily hauled 1,300 bbis from L Pad total =3,810 bbis Total Hauled 160 bbis to ORT. Daily Fluid lost 37 bbis total = 67 bbis 1/16/2020 Drill 8.5" Production Hole F/ 9,590' to 10,258' MD ( 3,659' TVD) total 668' (AROP 111.3') 530 GPM, 2,265 PSI, 120 RPM, TRQ 19-21K, WOB 6-15K, ECD 11.48, MW 9.3, P/U 155K, SLK 35K, ROT 93K, Max Gas 1,221U. MPD 522 GPM 100% open. Back ream 30' every stand. Dynamic loss 120 bbis while drilling.; Drilled down at 83°-84° to OA 1 top at 9,810' MD. 314' out of zone. Unable to build build fast enough went out of zone at 10,170' to 10,260' MD (90' below OA). SPR at 10,065' (3,665' TVD) MW 9.3. MP #1 32-345, 48-415. MP #2 32-345, 48-425.;Drill 8.5" Production Hole F/ 10,258' to 10,765' MD (3,604' TVD) total 507' (AROP 92.2') 530 GPM, 2,310 PSI, 120 RPM, TRQ 20.5K, WOB 6-15K, ECD 11.56, MW 9.3, P/U 170K, SLK 35K, ROT 92K. Max Gas 1,169U. MPD 524 GPM 100% open. Back ream 30' every stand. Repaired back drive on Centrifuge #1.;Build F/ 10,260' 100% DF enter OA-1 at 10,709' MD. Increased lubes F/ 2 % to 3%. SPR at 10,510' (3,625' TVD) MW 9.3. MP #1 32-314, 48-383. MP #2 32-310, 48-380.;PJSM Open Top Drive coffin and look for hydraulic leak. Found hydraulic solenoid dripping oil. Put absorbs around to contain leak until new solenoid comes in. Circ at 300 GPM, 860 PSI.;Drill 8.5" Production Hole F1 10,765' to 11,469' MD ( 3,588' TVD) total 704' (AROP 1174) 500 GPM, 2,150 PSI, 120 RPM, TRQ on 22K, TRQ off 24K, WOB 6-15K, ECD 11.51, MW 9.3, P/U 204K, SLK 35K, ROT 93K. Max Gas 1,283U. MPD 490 GPM 100% open. Back ream full stand. Reduce FR F/530 to 500 GPM for ECD's;Dynamic loss 38 bbls while drilling. H2O 40 bph. Both Centrifuges on, Dumped and dilute 340 bbls mud. SPR at 11,084' (3,586' TVD) MW 9.3. MP #1 32-316, 48-387. MP #2 32-318, 48-390.;Drill 8.5" Production Hole F/ 11,469' to 12,037' MD ( 3,591' TVD) total 568' (AROP 1032) 500 GPM, 2,175 PSI, 120 RPM, TRQ on 22K, TRQ off 22K, WOB 8-15K, ECD 11.69, MW 9.3, P/U 155K, SLK 35K, ROT 93K. Max Gas 1,258U. MPD 487 GPM 100% open. Back ream full stand. Dynamic loss 23 bbis while drilling.;At 11,690' unable to build F/ 88°, at 11,717' MD reduced flow to 400 GPM 100 % DIF to build to 91' to re enter OA-1 Fl OA-3. SPR at 12,037'(3,591* TVD) MW 9.3. MP #1 32-350, 48-430. MP #2 32-365, 48-445.;PJSM Rot & Circ F/ 12,037' to 11,970' MD Work on C/O pump liner on MP #1. Circ, at 300 GPM 990 PSI. SIMOPS Grease Drawworks spline.;49 concretions in motherbore, total footage of 261'(3.8% lateral section). OA-1 2,287', OA-2 856', OA-3 11,864', Cumulative OA Sand 5,698', Cumulative out 1,253'. Distance to WP #5: 50.03', 47.07' low, 16.94' Ieft.;Daily hauled 1,212 bbls to G&I total = 4,343 bbls Daily hauled 1,040 bbls from L Pad total =4,850 bbis Total Hauled 160 bbis to ORT. Daily Fluid lost 128 bbis total = 225 bbls 1/17/2020 PJSM Rot & Circ F/ 12,037' to 11,970' MD Work on C/O pump liner on MP #1. Circ. at 300 GPM 990 PSI. SIMOPS Grease Drawworks spline.; Drill 8.5" Production Hole F/ 12,037' to 12,423' MD ( 3,512' TVD) total 386' (AROP 772) 500 GPM, 2,245 PSI, 120 RPM, TRQ on 19.5K, TRQ off 16-19K, WOB 8- 15K, ECD 11.82, MW 9.3, P/U 149K, SLK 35K, ROT 93K. Max Gas 1,796U. MPD 490 GPM 100% open. Back ream full stand. Dynamic loss 43 bbls.; Fault #3 at 11,850' which moved the bit from the OA-3 into OA-1. Throw of 14' DTS. Exited the OA-Sand top from 12220-12340' MD 120' out of zone.;Drill 8.5" Production Hole F/ 12,423' to 12,994' MD ( 3,624' TVD) total 571' (AROP 95.2') 475 GPM, 2,160 PSI, 120 RPM, TRQ on 19K, TRQ off 18K, WOB 9-12K, ECD 11.87, MW 9.3, P/U 168K, SLK 35K, ROT 91 K. Max Gas 1,695U. MPD 465 GPM 100% open. Back ream full stand. Dynamic loss 23 bbls.;Held 89.5° dropping to 86.5° to come down into OA-3. Got back in OA-3 at 12,615' dip turned to 92° to bottom of the OA-3, crossed Fault #4 at 12,810' MD. 440' early 22' DTN, Over 20' below OA-Sand base. SPR at 12,548' MD (3,603' TVD) MW 9.25. MP #1-32-425, 48-505. MP #2 32-425. 48-500.; Drill 8.5" Production Hole F/ 12,994' to 13,502' MD ( 3,602' TVD) total 508' (AROP 947) 500 GPM, 2,520 PSI, 120 RPM, TRQ on 20K, TRQ off 18K, WOB 8-12K, ECD 12.2, MW 9.3, P/U 164K, SLK 35K, ROT 90K. Max Gas 1,435U. MPD 488 GPM 100% open. Back ream full stand. Dynamic loss 41 bbls.;Took 496' to turn around back into the OA-Sand base at 13,306' MD. Undulate back up to OA-1 starting at 13,650'. SPR at 13,313' MD (3,608' TVD) MW 9.3. MP #1-32-460, 48-545. MP #2 32- 460. 48-540.;Drill 8.5" Production Hole F/ 13,502' to 14,010' MD ( 3,586' TVD) total 508' (AROP 847) 500 GPM, 2,575 PSI, 120 RPM, TRQ on 21 K, TRQ off 20-22K, WOB 8-16K, ECD 12.3, MW 9.3, P/U 165K, SLK 35K, ROT 92K. Max Gas 2,123U. MPD 485 GPM 100% open. Back ream full stand. Loss rate 6-8 bph lost 49 bbls.;Cont 91° to OA-1 sand. Rot & Rao at 13,760' CBU due to Gas 2,100+, Shakers unloading sand. 480 GPM, Beyond 460 GPM. SPR at 13,886' MD (3,592' TVD) MW 9.35. MP #1-32-435, 48-520. MP #2 32-430. 48-515.;Side Track Point 5,175'& 9,325' MD. 59 concretions in motherbore, total footage of 298' (3.3% lateral section). OA-1 2,864', OA-2 1,048', OA-3 2,306', Cumulative OA Sand 6,962', Cumulative out 2,241'. Distance to WP #5: 105.04', 104.80' low, 7.09' left.; Daily hauled 741 bbls to G&I total = 5,084 bbls Daily hauled 1,170 bbis from L Pad total =6,020 bbls Total Hauled 160 bbis to ORT. Daily Fluid lost 191 bbls total = 416 bbis 1/18/2020 Drill 8.5" Production Hole F/ 14,010' to 14,389' MD ( 3,572' TVD) total 379' (AROP 69.9') 500 GPM, 2,685 PSI, 120 RPM, TRQ on 25K, TRQ off 22-25K, WOB 8-20K, ECD 12.7, MW 9.45, P/U 185K, SLK 35K, ROT 90K. Max Gas 2,668U. MPD 488 GPM 100% open. Back ream full stand. Loss rate 15-18 bph lost 113 bbls.;Control drill 150 fph for ECD. SPR at 14,389' MD (3,572' TVD) MW 9.45. MP #1 32-555, 48-640. MP #2 32-560, 48-650.;Targeted 92.5° to OA-1 sand. OA-1 base at 14,062' MD. Exited OA-Sand top at 14,220' MD and drilled to 14,389' MD. Decision was made to pull back to 12,050' MD for sidetrack possible 600'+ of lost pay. BROOH F/ 14,389' to 14,074' MD 500 GPM, 2,620 PSI, 120 RPM, TRQ 24K, ECD 12.4, P/U 180K, SLK 35K.;At 14,062' MD attempted to pull on elevators. P/U 250K. Pumped out F/ 14,062' to 11,978' MD. 400 GPM, 1,800 PSI, RCD 11.5, Max Gas 4270. P/U 180, SLK 35K. Dynamic losses 10-12 bph.;CBU Rot Rec F/ 11,978' to 11,914' MD. 500 GPM, 2,450 PSI, 80 RPM, TRQ 20K, ECD 12.1, Max Gas 1,580U. P/U 180K, SLK 35K, ROT 90K. Consistent sand over Shakers W/ no unloading.;Wash down F/ 11,914' to 12,035' MD. 400 GPM, 1,745 PSI, 80 RPM, TRQ 20K.;Troughed down F/ 12,035' to 12,050' 100% def and 160° TF for 10 minutes. Time drill F/ 12,050'450 GPM, 80 RPM, 1,850 PSI, 5 FPH staging up to 50 FPH 12,068' - 12,072'. 80 FPH to 12,102' MD. ABI at 12,102'89.34* Old well 92.25°. 12,050' ABI 91.28° Old well 91.37°, 12,072' ABI 90.75° Old well 91.81°;Drill 8.5" Production Hole F112,102'to 12,232' MD ( 3,592' TVD) total 130' (AROP 867) 475 GPM, 2,135 PSI, 120 RPM, TRQ 20K, TRQ off 19K, WOB 5K, ECD 11.49, MW 9.4, P/U 175K, SLK 35K, ROT 90K. Max Gas 470U. MPD 470 GPM 100% open. Back ream full stand. Loss rate 15-18 bph lost 150 bbis for tour.;Drill 8.5" Production Hole F/ 12,232' to 12,483' MD ( 3,595' TVD) total 251' (AROP 837) 500 GPM, 2,360 PSI, 120 RPM, TRQ 18.5K, TRQ off 16.51K, WOB 6-10K, ECD 11.64, MW 9.3 PIU 156K, SLK 35K, ROT 92K. Max Gas 1,936U. MPD 492 GPM 100% open. Back ream full stand.;Loss rate 13 bph lost 78 bbls for tour.. 88.7° currently in OA-1 Send. Dumped and diluted 170 bbls.;Circ at 12,483' MD 250 GPM, 760 PSI, C/O Swab on MP #1.;Drill 8.5" Production Hole F/12,483' to 12,677' MD ( 3,594' TVD) total 194' (AROP 77.6') 500 GPM, 2,115 PSI, 120 RPM, TRQ 18.5K, TRQ off 16-18K, WOB 8-14K, ECD 11.4, MW 9.2 P/U 158K, SLK 35K, ROT 92K. Max Gas 1,836U. MPD 493 GPM 100% open. Back ream full stand. Dynamic loss 78 bbls. Dumped 130 bbls.;SPR at 12,356' MD (3,592' TVD) MW 9.3. MP #1 32-320, 48-400. MP #2 32-320, 48-410.;Side Track Point 5,175'& 9,325'& 12,050' MD. 52 concretions in motherbore, total footage of 269' (3.6% lateral section). OA-1 2,972', OA-2 911', OA-3 1,708', Cumulative OA Sand 6,278', Cumulative out 1,253'. Distance to WP #5: 50.54', 44.13' low, 24.64' Right.;Daily hauled 870 bbis to G&I total = 5,954 bbls Daily hauled 1,040 bbis from L Pad total =7,060 bbis Total Hauled 160 bbls to ORT. Daily Fluid lost 312 bbis total = 728 bbls 1/19/2020 Drill 8.5" Production Hole F/ 12,677' to 13,248' MD ( 3,597 TVD) total 571' (AROP 952) 530 GPM, 2,495 PSI, 120 RPM, TRQ 19.5K, TRO off 16-18K, WOB 6-8K, ECD 11.6, MW 9.2 P/U 166K, SLK 35K, ROT 91 K. Max Gas 2,076U. MPD 516 GPM 100% open. Back ream full stand. Loss Rate 10-15 bph. Lost 66 bbls.;Stayed in OA -1 to Fault #4 at 12,802 MD 30' DTN. Out of OA 53'. SPR at 12,930' MD (3,592' TVD) MW 9.2. MP #1 32-345, 48-425. MP #2 32-345, 48- 425.;Drill 8.5" Production Hole F/ 13,248' to 13,820' MD ( 3,591' TVD) total 572' (AROP 953) 530 GPM, 2,630 PSI, 120 RPM, TRQ 21 K, TRQ off 19K, WOB 8-12K, ECD 11.94, MW 9.25 P/U 170K, SLK 35K, ROT 90K. Max Gas 1,9100. MPD 510 GPM 100% open. Back ream full stand. Dump Dilute 290 bbl.;Undulating 89.9° F/ OA -3 to OA -1 Loss Rate 10-15 bph. Lost 72 bbis. SPR at 13,349' MD (3,592' TVD) MW 9.3. MP #1 32-385, 48-470. MP #2 32-380, 48-465.;Drill 8.5" Production Hole F/ 13,820' to 14,360' MD ( 3,581' TVD) total 540' (AROP 90') 500 GPM, 2,540 PSI, 120 RPM, TRQ 23.5K, TRQ off 20.5K, WOB 8K, ECD 12.04, MW 9.3 P/U 180K, SLK 35K, ROT 90K. Max Gas 1,910U. MPD 485 GPM 100% open. Back ream full stand.; -At 13,950' MD Reduced F/ 530 GPM 2,729 PSI to 500 GPM 2,520 PSI due to dynamic loss Rate 15 to 18 bph. Lost 108 bbl. Entered OA -1 at 14,000' till TD at 14,508' MD. SPR at 14,140' MD (3,584' TVD) MW 9.3 MP #1 32-450, 48-540 MP #2 32-440, 48-524.;Drill 8.5" Production Hole F/ 14,360' to 14,508' MD ( 3,579' TVD) total 148' (AROP 987) 500 GPM, 2,565 PSI, 120 RPM, TRQ 24K, TRQ off 22-24K, WOB 6-10K, ECD 12.07, MW 9.3 P/U 174K, SLK 35K, ROT 91 K. Max Gas 1,273U, MPD 485 GPM 100% open. Back ream full stand. Loss Rate 18 bph. Lost 22 bbls.;SPR at 14,508' MD (3,579' TVD) MW 9.3. MP #1 32-465, 48-555. MP #2 32-460, 48-545.;BROOH CBU per stand 4X F/ 14,508' to 14,264' MD 500 GPM, 2,545 PSI, 140 RPM, TRQ 24K, ECD 12.11, MW 9.3 P/U 180K, SLK 35K, ROT 90K. Max Gas 1,523U. MPD 485 GPM 100% open. Dynamic loss 11-12 bph. Lost 40 bbis. SIMOPS Prep Pits and trucks for displacement.; Crossed 4 faults, Side Track Point 5,175'& 9,325'& 12,050' MD. 61 concretions in motherbore, total footage of 306' (3.2% lateral section). OA -1 3,570', OA -2 1,198', OA -3 2,427', Cumulative OA Sand 8,143', Cumulative out 1,306'. Distance to WP #5: 100.6', 87.38' low, 49.85' Right.; Daily hauled 1,087 bbis to G&I total = 7,041 bbls Daily hauled 1,170 bbls from L Pad total =8,230 bbis Total Hauled 160 bbis to ORT. Daily Fluid lost 324 bbls total = 1,052 bbls 1/20/2020 BROOH CBU per stand 4X F/ 14,508' to 14,264' MD 500 GPM, 2,545 PSI, 140 RPM, TRQ 24K, ECD 11.98, MW 9.3 P/U 180K, SLK 35K, ROT 90K. Max Gas 357U. MPD 485 GPM 100% open. Dynamic loss 8 bph. Lost 16 bbls. SIMOPS Prep Pits and trucks for displacement.;Wash and ream down F/ 14,264' to 14,508' MD 450 GPM, 2,200 PSI, 80 RPM, TRQ 23K. P/U 172K, SLK 35K, ROT 91 K. SIMOPS Finish prepping for displacement. Lost 16 bbls.;PJSM Rot & Rec F/ 14,508' to 14,453' MD Displace F/ 9.35 ppg Baridril N to 9.2 ppg Quickdril 8-10 BPM, 1,420 PSI, 80 RPM, TRQ 23K, Pump 3X 35 bbis SAPP spacer W/ 25 bbls Quickdrill in between. Pump 45 bbl Hi Vis spacer followed by 9.2 ppg Quickdril. Lost 72 bbis during displacement.; Parameters after 8 GPM, 1,095 PSI, 80 RPM, TRQ 23K, ROT 92K. SPR at 14,508' MD (3,581' TVD) MW 9.2. MP #1 32-300, 48-360. MP #2 32-290, 48-355.;PJSM Monitor well W/ MPD, Static. BROOH 1 stand and drop 2.375" OD drift on 6' wire. Cont BROOH F/ 14,455' to 12,800' MD 500 GPM, 1,760 PSI, 120 RPM, TRQ 21 K, Max Gas 550U. ECD 11.12, MPD 485 GPM. PIU 185K, SLK 35K, ROT 96KPull speed adjusted as hole dictates. Dynamic loss rate 9 bph, lost 45 bbls;PJSM Cont BROOH F/ 12,800' to 10,869' MD 500 GPM, 1,590 PSI, 140 RPM, TRQ 12.5K, ECD 10.71, MPD 467 GPM, Max Gas 480U. P/U 148K, SLK 35K, ROT 96K. Pull speed adjusted as hole dictates. Dynamic loss rate 9 bph, lost 63 bb1s.;PJSM Cont BROOH F/ 10,869' to 9,113' MD 500 GPM, 1,580 PSI, 140 RPM, TRQ 10.5K, ECD 10.68, MPD 480 GPM. Max Gas 556U. PIU 140K, SLK 35K, ROT 99K. 5' to 30' ft/min. Pull speed adjusted as hole dictates. Dynamic loss rate 6 bph, lost 36 bbls.;At 9,860' to 9,497' Reduced pulling speed to 5-10 ft/min due Shakers loading up and ECD F/ 10.59 to 11.39. Out of Zone 9,810' to Fault #2 at 9,496' MD. (314).;Daily hauled 1,949 bbls to G&I total = 8,990 bbis Daily hauled 520 bbis from L Pad total =8,750 bbis Total Hauled 160 bbls to ORT. Daily Fluid lost 268 bbis total = 1,320 bbis 1/21/2020 Cont BROOH F/ 9,113' to 6,569' MD 500 GPM, 1,415 PSI, 140 RPM, TRQ 7Kft-lbs, ECD 10.36 ppg EMW. Max Gas 910U. P/U 132K, SLK 78K, ROT 102K. 5' to 30' ft/min. Pull speed adjusted as hole dictates.;Cont BROOH F/ 6,569' to 5,042' MD 500 GPM, 1,405 PSI, 140 RPM, TRQ 5-8Kft-lbs, ECD 10.08 ppg EMW. Max Gas 1765U. PIU 120K, SLK 90K, ROT 108K, Slow pulling speed to 5-10fph from 6,380' to 5,480' due to erratic torque and slight pack -offs. Pull BHA into shoe with no rotary; 10-20K drag observed.;Pump tandem high wt/vis, Low wt/vis sweeps (10% increase) around and 2 x BU at 500 gpm/1330 psi, 100 rpms, 2700ft-lbs, reciprocating pipe. ECD 10.0 ppg EMW. Max gas 140U. Blow down top drive and geo-span.;Service rig. Grease crown sheaves, check top drive gear oil, grease and inspect welds - good. Service iron roughneck. SimOps: Monitor well though RCD drain line, Initial slight flow going static.;Pull RCD bearing, Install trip nipple. Monitor well - static.;POOH from 5042' to 4724' laying down drill pipe. No indication of swabbing, correct hole fill. Monitor well - slight loss. Pump dry job, blow down top drive. Cont. POOH from 4724' to 4394' laying down drill pipe.;Cont. POOH from 4394' to 275' laying down drill pipe, separating out flagged joints due for inspection. Calc hole fill 36.5 bbis, actual 54.5 bbls. Monitor well prior to L/D BHA - slight loss.;L/D BHA: HWDP, Jars and 2 flex collars. Retrieve 2.375" drift on top of float sub.; Daily hauled 570 bbis to G&I total= 9,560 bbls Daily water hauled 910 bbls from L Pad total =9,660 bbls Total Hauled 160 bbis to ORT. Daily Fluid lost 196 bbis total = 1,516 bbls 1/22/2020 Plug in and download MWD. L/D remaining BHA. Bit grade 2 -1 -CT -N -X -1 -NO -TD. Clean and clear rig floor of BHA components.; Rig up to RIH with 6-5/8" slotted liner. Rig up Weatherford power tongs and handling equipment. Bring centralizers to rig floor. M/U safety joint.;RIH with 6-5/8", 20#, L-80, 563W slotted liner as per tally to 7600', torque connections to 7100 ft -lbs. PUW 125K, SOW 67K.;Cont, to RIH with 6-5/8", 20#, L-80, 563W slotted liner, with 2 swell packers and 16 jnts 4-1 /2", 13.5#, L-80 625W as per tally from 7600' to to 9578'. Set down (only 20K do wt availablt) at 8503' (work through x 1), 9140' (work multiple times gaining footage each time), and 9490'.;M/U SLZXP liner top packer. Calculated displacement = 60.9 bbls, Actual 44.9 bbis.;Drift, pick up and single in hole with 2 joints HWDP. Establish circulation and obtain parameters at 1 bpm (60 psi), 2 bpm (70 psi) and 3 bpm (122 psi). Cont. to RIH with 6- 5/8" liner conveyed on HWDP. Drift, pick up and single in the hole with HWDP from 9615' to 10,625'.;Cont. to RIH with 6-5/8" liner conveyed on HWDP. Drift, pick up and single in the hole with HWDP from 10,625' to 12,800'. RIH with 6-5/8" liner conveyed on 5" DP from derrick to 14,508'. PUW 230K, SOW 85K. Calc dispi 71 bbls, Act. 61 bbis.;Tag bottom at 14,508'. Pick up to 14,505'. Drop phenallic ball and set packer as per Baker. Pump down at 4 bpm slowing down to 2 bpm 170 psi, on seat at 680 psi. Pressure up to 2800 psi, good indication of packer set, hold for 1 minute. Pressure up to 3000 psi, slack off to 100K. Continue;to pressure up to 4643 psi and observe liner hanger nuetralize, and ball seat sheared. Pick up 4' to ensure released; PUW 168K. Flood lines, shut UPR's. Test SLZXP to 1500 psi for 10 minutes - good test. 1.6 bbls pumped, 1.6 bbls returned. TOL = 1900.69'.;Daily hauled 0 bbis to G&I total = 9,560 bbis Daily water hauled 100 bbis from L Pad total =9,760 bbls Total Hauled 160 bbls to ORT. Daily Fluid lost 49 bbls total = 1 565 bbl Hilcorp Energy Company Composite Report Well Name: MP M-24 Field: Milne Point County/State: North Slope Borough, AK (LAT/LONG): :vation (RKB): API #: Spud Date: Job Name: 1915943C MPU M-24 Completion Contractor AFE #: AFE $: Activity Dake Ups Summary 1/23/2020 CBU at 6.5 bpm/903 psi; pulling out of liner top slowly, increasing rate to 9 bpm/1400 psi once above liner top. Blow down top drive, choke and kill lines. Monitor well - 2 bph static loss rate.,POOH from 4858' to 4600'- no indication of swabbing. Pump dryjob, B/D top drive. Cont. to POOH laying down drill pipe/HWDP from 4600' to 1200'; separating out joints flagged for inspection., Cont. POOH laying down HWDP from 1200' to surface. L/D liner running tool. Calc hole fill 50.6 bbls, Act. 59 bbls.,Service rig: grease crown sheaves, check top drive gear oil. Service iron roughneck. Static loss rate 3.4 bph.,M/U 3.5" EUE stinger with 8.31" no-go. RIH on elevators from surface to 4926' (No-go depth 4897'), tag TOL x 2 1OK. PUW 113K, SOW 105K., Establish circulation and stage pumps up to 10 bpm/ 285 psi. CBU pulling out of liner top slowly. Monitor well, slight loss. Pump dryjob. Blow down top drive., POOH laying down drill pipe from 4926' to 2390', separating out joints flagged for inspection. PUW 80K, SOW 78K. Calc, hole fill 19 bbls, Act. 25 bbls.,POOH laying down drill pipe from 2390' to 936', separating out joints flagged for inspection. PUW 59K, SOW 57K. Calc. hole fill 11.5 bbls, Act. 14.5 bbls.,RIH with excess drill pipe from derrick from 936' to 4224'. PUW 101 K, SOW 90K. Calc disp. 29, act. 26.,Cut and slip 86' drill line. Check brake air gaps, within specs., Daily hauled 352 bbls to G&I total = 9,912 bbls Daily water hauled 0 bbis from L Pad total =9,760 bbls Total Hauled 160 bbis to ORT. IDaily Fluid lost 40 bbls total = 1,605 bbls 1/24/2020 POOH laying down drill pipe from 4224' to surface, separating out joints due for inspection., Drain stack. Pull wear bushing.,Break down 6-5/8" safety joint. MIU test joint. Set test plug. M/U test sub to top drive.,Test BOPE 250/3000 psi with 4.5" and 5" test joint. AOGCC right to witness waived by Matt Herrera. Test high level alarm in pits, PVT sensor, and return flow paddle. Test gas alarms. Accumulator drawdown: starting pressure 2900 psi, final 1500 psi. First 200 psi recharge 30 sec. final recharge 106 sec. (6) N2 bottles at 2333 psi average., Pull test plug. Break down test joint. Clear rig floor of testing equipment. Blow down choke manifold, choke and kill lines, kelly hose.,Rig up Weatherford power tongs, C/O pipe handling equipment. M/U safety joint. Dummy run 7" casing hanger and mark landing joint.,M/U tie back seal assembly and RIH with 7", 26#, L-80, TXP casing to 900'; utilizing torque turn. PUW 49K, SOW 52K.,Cont. to RIH with 7", 26#, L-80, TXP casing from 900' to 4830'; utilizing torque turn. PUW 125K, SOW 105K.,Daily hauled 164 bbls to G&I total = 10,076 bbls Daily water hauled 100 bbls from L Pad total =9,860 bbls Total Hauled 160 bbls to ORT. IDaily Fluid lost 36 bbls total = 1,641 bbls 1/25/2020 Cont. to RIH with 7", 26#, L-80, TXP tie -back string from 4830', tag up and No -Go at 4905'. Space out 1.46' off No -Go with 6.85' pup joint. M/U hanger and land. rig up to reverse circulate. Close bag, apply 300 psi and strip up until circulation ports are exposed and pressure drops., Establish circulation staging pumps up to 3 bpm/175 psi. Displace well to 9.2 ppg corrosion inhibited brine, followed by 75 bbls diesel for freeze protect. Strip and and land hanger.,Break out landing joint. Change elevators to 5". Pick up single and M/U pack -off. Set pack-off.,RILDS. Test hanger void 500/5000 psi - good. Rig up and PT 7" x 9- 5/8" annulus to 1000 psi for 30 minutes -good. Rig down and blow down lines., Rig up power tongs, change out pipe handling equipment. Bring TEC spooler to rig floor and 80 cannon clamps.,PJSM. RIH with 4-1/2", 12.6#, L-80, TXP tubing: M/U WLEG, 11 jnts tubing, 'XN' nipple, AHR packer, 'X' Nipple, SGM, sliding sleeve, SGM. Connect TEC wire to gauge mandrel and test connection to 5000 psi. Cont. to RIH with 4-1/2" tubing to 4,553', installing cannon clamps on first 20 joints, then every other joint. PUW 90K, SOW 65K.,Cont. to RIH with 4-1/2" tubing from 4,553' to 4,711', set down (30K) - packer depth 4205'. Attempt to work through setting down same depth. Put 1/4 turn to left and pick up 10' slack off and set down same d6pth. Hut/ urn to right and pick up 20', slack off - unable to go down. Pick up 10' to collar and attempt to go down unable to. Consult with town„POOH with 4-1/2” completion from 4676' to 2933'., Daily hauled 721 bbls to G&I total = 10,797 bbls Daily water hauled 0 bbls from L Pad total =9,860 bbls Total Hauled 160 bbls to ORT. Daily Fluid lost 12 bbls total = 1,653 bbls 1/26/2020 Continue to POOH with 4-1/2" completion to surface. No visible damage to equipment.,Change out seal rings on 4-112" tubing.,RIH with 4-1/2" completion as per tally, adding joint between packer and 'X' nipple. Set down at 900'., POOH with 4-1/2" completion. L/D sheave for TEC wire., Install hydraulic elevators, C/O inserts to 4". Load and process 4" HT -38 HWDP, 4" XT -39 DP., Pickup 4" test joint, M/U test plug and set. Flood lines. Test UPR, LRP, Annular, TIW 250/3000 psi. Rig down testing equipment.,Pull test plug, set wear bushing.,Prep to M/U BHA: Bring boot baskets, casing scraper and XO's to rig floor. Process drill pipe/HWDP in shed.,Continue processing HWDP/DP in shed. Load mule shoe in shed and remove No -Go. Strap, I. D., O.D BHA components, Create tally.,Thaw out kelly hose. Remove kelly from derrick and lower into pipe shed. Steam out ice plug and verify clear.,Daily hauled 57 bbls to G&I total = 10,854 bbls Daily water hauled 0 bbls from L Pad total =9,860 bbls Total Hauled 160 bbls to ORT. Dail Fluid lost 21 bbls total = 1,674 bbls 1/27/2020 Re -install kelly hose. Blow air through top drive and kelly hose to verify clear prior to testing connections. PT connection to 4000 psi - good. Blow down top drive and kelly hose.,M/U cleanout run as per Baker rep: 3-1/2" mule shoe, boot baskets, casing scraper, bumper, jars, 10 jnts HT -38 HWDP.,RIH with clean out assembly, pick up drift and single in the hole to 4,934'. PUW 104K, SOW 74K. Lost 8 bbls during trip.,M/U XO and kelly up. Establish circulation staging up to 10 bpm/1360 psi, slowly pulling out of liner top/seal assembly to 4,886'. CBU x 2. Blow down top drive. Monitor well, slight loss., POOH with cleanout assembly, laying down drill pipe from 4,886 to 2,300'.,Continue to POOH laying down drill pipe to 374'. UD 10 jnts HWDP and BHA. Nothing recovered in boot baskets., Clean and clear rig floor of BHA components. Remove wear bushing., Rig up to RIH with completion. Change out elevators, hang sheave., M/U WLEG and RIH with 4-1/2", 12.6#, L-80, TXP completion as per tally to 571'. P/U packer assembly and inspect as per Baker Rep, P/U XN nipple, SLB SGM, Sliding sleeve, SGM. Connect TEC line and test as per SLB rep.,Daily hauled 57 bbls to G&I total = 10,911 bbis Daily water hauled 230 bbls from L Pad total =10,090 bbls Total Hauled 160 bbls to ORT. Daily Fluid lost 33 bbls total = 1,707 bbls 1/28,2020 Cont. RIH with 4.5" tubing from 571' to 4924' at 90 fpm as per Baker rep. PUW 90K,. SOW 66K. Torque connection to 6170 ft -lbs. Pick up hanger and make up landing joint. Terminate TEC line as per SLB rep. 64 cannon clamps ran. Calc displacement 21.7 bbls, actual 16.8 bbls.,Cont. terminating TEC. Drain stack and land 4.5" completion at 4949.83'. RILDS. 31 K on hanger. Back out landing joint, break XO's. M/U 20' and 5' pup joint to space out.,Drop ball and rod. R/U and set packer, pressure up to 1700 psi. Continue pressuring up to 3500 psi. PT tubing to 3500 psi for 30 minutes - good. Bleed down to 2000 psi, line up and PT IA to 3500 psi - good.,Rig down testing equipment. Remove XO's from 20' pup joint. B/D lines.,lnstall BPV. Clear rig floor of Weatherford tools, box, spooling unit. Start cleaning pits.,N/D BOPE: Flush kelly hose, choke manifold and kill line with fresh water. Blow down lines. Clean drip pan, pull riser. Remove choke and kill lines. Lower drip pan. Hook up bridge cranes. P,'U BOP and rack back on pedestal. Remove DSA. SimOps: lay herculite on M- 23. Load and process 5" drill pipe in shed.,SLB feed TEC wire through wellhead and terminate, perform final test.,N/U tree. PT hanger void 500/5000 psi - good. Pull BPV, set TWC.,Rig up to pressure test tree 250/5000 psi - good. Pull TWC. SimOps: load wireline lubricator in shed, Bring wireline valves to rig floor„Daily hauled 227 bbls to G&I total = 11,138 bbls Daily water hauled 0 bbls from L Pad total =10,090 bbls Total Hauled 160 bbls to ORT. Daily Fluid lost 5 bbls total = 1,712 bbls 1/29/2020 Continue rigging up slickline. P/U lubricators from shed. Make up side entry sub on tree and lower 20' lubricator extension. M/U wire line valve and lubricator. PT to 3000 psi.,Slickline Run 1: M/U tools, RIH and attempt to shift sleeve open and retrieve ball and rod. POOH, no ball and rod, sleeve not open -Run 2: RIH and open sliding sleeve Run 3: RIH and retrieve ball and rod. Run 4 : RIH and retrieve RHC plug Run 5: RIH and set Jet pump. SimOps: LRS Freeze protect well, bullhead 44 bbls down tubing, 46 bbls down IA. Final pressure 660 psi., Rig down and L/D lubricators, wireline valves, side entry sub. Bleed lubricator to bleed trailer and blow down lines. R/D sheave.,Pick up lubricator. Lubricate in TWC valve. Rig down and lay down lubricator. SimOps: Freeze protect test PUMP, pressure washer. R/D tongs, bridle up and prep to scope derrick down. Rig down interconnects. Rig Released @ 00:00 hrs.,Continue to rig down interconnects. Disconnect electric. Scope derrick down. Blow down stearn lines. Install jeep under gen mod. Pull break shack and envirovac away. Remove tarps and heaters from under mods.,RDMO. Pull gen mod, pit mod, pipe shed and cattle chute away from sub base. Final report for M-24.,Daily hauled 35 bbls to G&I total = 11,173 bbls Daily water hauled 0 bbls from L Pad total =10,090 bbls Total Hauled 160 bbls to ORT. Daily Fluid lost 0 bbls total = 1,712 bbls Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-24 500292365700 Sperry Drilling Definitive Survey Report 22 January, 2020 HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-24 Project: Milne Point TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Site: M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Well: MPU M-24 North Reference: True Wellbore: MPU M-24 Survey Calculation Method: Minimum Curvature Design: MPU M-24 Database: NORTH US + CANADA 3roject Milne Point, ACT, MILNE POINT Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point flap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU M-24, Slot 16 Well Position +N/ -S 0.00 usft Northing: Map 6,027,889.58 usft Latitude: 70° 29' 14.016 N Inc +E/ -W 0.00 usft Easting: TVD 533,513.90 usfi Longitude: 149'43'33.871 W Position Uncertainty 0.50 usft Wellhead Elevation: Easting 0.00 usfi Ground Level: 25.30 usft Wellbore MPU M-24 (usft) (usft) (usft) (usft) Magnetics Model Name Sample Date Declination (ft) Survey Tool Name Dip Angle Field Strength 0.00 26.65 C) 0.00 (1) (nT) 533,513.90 BGGM2019 1/20/2020 0.00 UNDEFINED 16.16 80.90 57,401.13421509 Design MPU M-24 0.22 0.02 6,027,889.80 533,513.92 Audit Notes: -0.22 3_MWD+IFR2+MS+Sag (1) 298.47 0.16 23.95 298.47 Version: 1.0 Phase: ACTUAL Tie On Depth: 12,033.82 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 389.88 (usft) (usft) (usft) 6,027,891.31 (1) 1.58 26.65 0.00 0.00 333.95 184.00 Survey Program Date 1/20/2020 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 206.41 5,001.86 MPU M-24PB1 SH MWD+IFR2+MS+Sac 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 11/27/2019 5,098.24 9,295.75 MPU M -24P62 PH MWD+IFR2+MS+Sac 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 01/13/2020 9,325.00 12,033.82 MPU M-24PB3 MWD+IFR2+MS+Sag (4) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 01/16/2020 12,050.00 14,439.90 MPU M-24 MWD+IFR2+MS+Sag (5) (MF 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 01/20/2020 Survey 1/222020 12:43:46PM Page 2 COMPASS 5000.15 Build 91E Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EAW Northing Easting DLS Section (usft) (1) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 26.65 0.00 0.00 26.65 -25.30 0.00 0.00 6,027,889.58 533,513.90 0.00 0.00 UNDEFINED 206.41 0.14 4.54 206.41 154.46 0.22 0.02 6,027,889.80 533,513.92 0.08 -0.22 3_MWD+IFR2+MS+Sag (1) 298.47 0.16 23.95 298.47 246.52 0.45 0.08 6,027,890.03 533,513.98 0.06 -0.45 3_MWD+IFR2+MS+Sag (1) 389.89 1.56 340.07 389.88 337.93 1.74 -0.29 6,027,891.31 533,513.60 1.58 -1.71 3_MWD+IFR2+MS+Sag (1) 485.26 3.85 333.95 485.13 433.18 5.83 -2.14 6,027,895.40 533,511.73 2.42 -5.67 3_MWD+IFR2+MS+Sag (1) 577.83 7.76 331.13 577.21 525.26 14.10 -6.53 6,027,903.65 533,507.31 4.23 -13.61 3_MWD+IFR2+MS+Sag (1) 671.15 10.75 328.35 669.31 617.36 27.03 -14.14 6,027,916.54 533,499.64 3.24 -25.98 3_MWD+IFR2+MS+Sag (1) 766.59 13.99 329.76 762.52 710.57 44.58 -24.62 6,027,934.04 533,489.08 3.41 -42.75 3_MWD+IFR2+MS+Sag (1) 861.85 19.14 329.56 853.80 801.85 68.01 -38.34 6,027,957.41 533,475.26 5.41 -65.17 3_MWD+IFR2+MS+Sag (1) 957.40 23.41 329.78 942.81 890.86 97.93 -55.84 6,027,987.24 533,457.63 4.47 -93.79 3_MWD+IFR2+MS+Sag (1) 1,052.12 26.82 332.20 1,028.57 976.62 133.10 -75.28 6,028,022.33 533,438.03 3.76 -127.52 3_MWD+IFR2+MS+Sag (1) 1/222020 12:43:46PM Page 2 COMPASS 5000.15 Build 91E Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-24 Wellbore: MPU M-24 Design: MPU M-24 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU 10-24 MPU M-24 Actual Lateral RKB @ 51.95usft MPU M-24 Actual Lateral RKB @ 51.95usft True Minimum Curvature NORTH US + CANADA Vertical Section (ft) Survey Tool Name -166.19 3_MWD+IFR2+MS+Sag (1) -208.84 3_MWD+IFR2+MS+Sag (1) -254.74 3_MWD+IFR2+MS+Sag (1) -302.72 3_MWD+IFR2+MS+Sag (1) -352.75 3_MWD+IFR2+MS+Sag (1) -402.44 3_MWD+IFR2+MS+Sag (1) -452.19 3_MWD+IFR2+MS+Sag (1) -500.54 3_MWD+IFR2+MS+Sag (1) -548.93 3_MWD+IFR2+MS+Sag (1) -596.95 3_MWD+IFR2+MS+Sag (1) -645.06 3_MWD+IFR2+MS+Sag (1) -692.56 3_MWD+IFR2+MS+Sag (1) -736.27 3_MWD+IFR2+MS+Sag (1) -774.46 3_MWD+IFR2+MS+Sag (1) -805.80 3_MWD+IFR2+MS+Sag (1) -830.05 3_MWD+IFR2+MS+Sag (1) -847.44 3_MWD+IFR2+MS+Sag (1) -859.24 3_MWD+IFR2+MS+Sag (1) -865.01 3_MWD+IFR2+MS+Sag (1) -863.82 3_MWD+IFR2+MS+Sag (1) -856.07 3_MWD+IFR2+MS+Sag (1) -842.44 3_MWD+IFR2+MS+Sag (1) -822.08 3_MWD+IFR2+MS+Sag (1) -795.84 3_MWD+IFR2+MS+Sag (1) -760.81 3_MWD+IFR2+MS+Sag (1) -718.35 3_MWD+IFR2+MS+Sag (1) -668.44 3_MWD+IFR2+MS+Sag (1) -613.89 3_MWD+IFR2+MS+Sag (1) -555.57 3_MWD+IFR2+MS+Sag (1) -494.31 3_MWD+IFR2+MS+Sag (1) -429.30 3_MWD+IFR2+MS+Sag (1) -361.71 3_MWD+IFR2+MS+Sag (1) -292.53 3_MWD+IFR2+MS+Sag (1) -219.33 3_MWD+IFR2+MS+Sag (1) -141.49 3_MWD+IFR2+MS+Sag (1) -59.31 3_MWD+IFR2+MS+Sag (1) 26.87 3_MWD+IFR2+MS+Sag (1) 117.00 3_MWD+IFR2+MS+Sag (1) 209.63 3_MWD+IFR2+MS+Sag (1) 301.21 3_MWD+IFR2+MS+Sag (1) 1/222020 12:43:46PM Page 3 COMPASS 5000.15 Build 91E Map Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS (usft) V) V) (usft) (usft) (usft) (usft) (ft) (ft) (-/100') 1,147.38 30.03 332.80 1,112.33 1,060.38 173.32 -96.21 6,028,062.45 533,416.92 3.38 1,242.27 33.26 333.11 1,193.10 1,141.15 217.66 -118.83 6,028,106.68 533,394.10 3.41 1,337.44 35.79 331.60 1,271.51 1,219.56 265.42 -143.88 6,028,154.32 533,368.84 2.81 1,432.40 37.67 331.72 1,347.61 1,295.66 315.40 -170.83 6,028,204.18 533,341.66 1.98 1,527.93 38.95 331.58 1,422.57 1,370.62 367.52 -198.96 6,028,256.16 533,313.31 1.34 1,622.02 39.22 330.22 1,495.60 1,443.65 419.35 -227.81 6,028,307.86 533,284.23 0.96 1,717.52 38.38 330.27 1,570.03 1,518.08 471.30 -257.50 6,028,359.67 533,254.30 0.88 1,812.81 37.49 328.97 1,645.19 1,593.24 521.84 -287.12 6,028,410.07 533,224.46 1.26 1,908.44 38.81 329.05 1,720.39 1,668.44 572.48 -317.54 6,028,460.56 533,193.82 1.38 2,003.65 36.86 329.59 1,795.58 1,743.63 622.70 -347.34 6,028,510.64 533,163.79 2.08 2,098.63 38.52 330.28 1,870.74 1,818.79 672.96 -376.42 6,028,560.77 533,134.48 1.80 2,193.29 37.80 326.37 1,945.18 1,893.23 722.72 -407.11 6,028,610.38 533,103.58 2.66 2,288.76 36.10 320.87 2,021.49 1,969.54 768.91 -441.07 6,028,656.42 533,069.41 3.89 2,384.56 33.52 315.64 2,100.16 2,048.21 809.73 -477.39 6,028,697.07 533,032.91 4.12 2,479.18 31.37 308.54 2,180.03 2,128.08 843.77 -514.94 6,028,730.94 532,995.21 4.62 2,574.22 29.36 300.00 2,262.07 2,210.12 870.85 -554.49 6,028,757.84 532,955.55 5.01 2,669.58 28.84 292.08 2,345.43 2,293.48 891.19 -596.06 6,028,777.99 532,913.89 4.07 2,765.64 28.71 285.51 2,429.65 2,377.70 906.07 -639.77 6,028,792.67 532,870.11 3.29 2,860.70 29.50 276.97 2,512.74 2,460.79 915.02 -685.03 6,028,801.42 532,824.82 4.44 2,955.75 29.00 268.01 2,595.71 2,543.76 917.06 -731.31 6,028,803.25 532,778.54 4.63 3,050.34 27.55 259.84 2,679.04 2,627.09 912.41 -775.77 6,028,798.39 532,734.10 4.37 3,145.08 28.61 252.64 2,762.65 2,710.70 901.77 -819.00 6,028,787.56 532,690.92 3.75 3,240.52 32.05 245.63 2,845.04 2,793.09 884.49 -863.91 6,028,770.08 532,646.10 5.17 3,332.54 33.85 239.21 2,922.28 2,870.33 861.29 -908.18 6,028,746.68 532,601.94 4.27 3,430.07 35.36 230.26 3,002.61 2,950.66 829.32 -953.25 6,028,714.52 532,557.02 5.43 3,525.67 38,45 222.38 3,079.09 3,027.14 789.65 -994.59 6,028,674.66 532,515.86 5.91 3,621.58 41.59 217.64 3,152.55 3,100.60 742.39 -1,034.15 6,028,627.23 532,476.52 4.56 3,716.93 44.12 215.85 3,222.44 3,170.49 690.42 -1,072.92 6,028,575.09 532,437.99 2.94 3,812.46 47.35 215.17 3,289.11 3,237.16 634.73 -1,112.64 6,028,519.23 532,398.52 3.42 3,907.31 49.61 213.59 3,351.98 3,300.03 576.12 -1,152.72 6,028,460.44 532,358.71 2.69 4,002.61 52.61 212.00 3,411.81 3,359.86 513.76 -1,192.87 6,028,397.91 532,318.84 3.41 4,098.23 53.48 211.61 3,469.30 3,417.35 448.83 -1,233.14 6,028,332.80 532,278.87 0.97 4,192.94 56.50 210.16 3,523.63 3,471.68 382.26 -1,272.94 6,028,266.06 532,239.38 3.43 4,288.13 60.94 209.54 3,573.04 3,521.09 311.71 -1,313.41 6,028,195.34 532,199.23 4.70 4,383.79 65.16 206.63 3,616.39 3,564.44 236.49 -1,353.51 6,028,119.94 532,159.48 5.18 4,478.79 69.04 201.42 3,653.37 3,601.42 156.58 -1,389.06 6,028,039.89 532,124.28 6.50 4,573.30 71.64 195.29 3,685.20 3,633.25 72.16 -1,417.03 6,027,955.34 532,096.70 6.70 4,668.56 74.89 190.10 3,712.64 3,660.69 -16.80 -1,437.04 6,027,866.31 532,077.10 6.23 4,764.38 78.31 190.56 3,734.84 3,682.89 -108.49 -1,453.75 6,027,774.55 532,060.80 3.60 4,857.59 86.23 191.67 3,747.37 3,695.42 -199.04 -1,471.55 6,027,683.93 532,043.41 8.58 Vertical Section (ft) Survey Tool Name -166.19 3_MWD+IFR2+MS+Sag (1) -208.84 3_MWD+IFR2+MS+Sag (1) -254.74 3_MWD+IFR2+MS+Sag (1) -302.72 3_MWD+IFR2+MS+Sag (1) -352.75 3_MWD+IFR2+MS+Sag (1) -402.44 3_MWD+IFR2+MS+Sag (1) -452.19 3_MWD+IFR2+MS+Sag (1) -500.54 3_MWD+IFR2+MS+Sag (1) -548.93 3_MWD+IFR2+MS+Sag (1) -596.95 3_MWD+IFR2+MS+Sag (1) -645.06 3_MWD+IFR2+MS+Sag (1) -692.56 3_MWD+IFR2+MS+Sag (1) -736.27 3_MWD+IFR2+MS+Sag (1) -774.46 3_MWD+IFR2+MS+Sag (1) -805.80 3_MWD+IFR2+MS+Sag (1) -830.05 3_MWD+IFR2+MS+Sag (1) -847.44 3_MWD+IFR2+MS+Sag (1) -859.24 3_MWD+IFR2+MS+Sag (1) -865.01 3_MWD+IFR2+MS+Sag (1) -863.82 3_MWD+IFR2+MS+Sag (1) -856.07 3_MWD+IFR2+MS+Sag (1) -842.44 3_MWD+IFR2+MS+Sag (1) -822.08 3_MWD+IFR2+MS+Sag (1) -795.84 3_MWD+IFR2+MS+Sag (1) -760.81 3_MWD+IFR2+MS+Sag (1) -718.35 3_MWD+IFR2+MS+Sag (1) -668.44 3_MWD+IFR2+MS+Sag (1) -613.89 3_MWD+IFR2+MS+Sag (1) -555.57 3_MWD+IFR2+MS+Sag (1) -494.31 3_MWD+IFR2+MS+Sag (1) -429.30 3_MWD+IFR2+MS+Sag (1) -361.71 3_MWD+IFR2+MS+Sag (1) -292.53 3_MWD+IFR2+MS+Sag (1) -219.33 3_MWD+IFR2+MS+Sag (1) -141.49 3_MWD+IFR2+MS+Sag (1) -59.31 3_MWD+IFR2+MS+Sag (1) 26.87 3_MWD+IFR2+MS+Sag (1) 117.00 3_MWD+IFR2+MS+Sag (1) 209.63 3_MWD+IFR2+MS+Sag (1) 301.21 3_MWD+IFR2+MS+Sag (1) 1/222020 12:43:46PM Page 3 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-24 Project: Milne Point TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Site: M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Well: MPU M-24 North Reference: True Wellbore: MPU M-24 Survey Calculation Method: Minimum Curvature Design: MPU M-24 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,952.37 90.74 191.01 3,749.87 3,697.92 -291.91 -1,490.17 6,027,590.98 532,025.20 4.81 395.15 3_MWD+IFR2+MS+Sag (1) 5,001.86 91.79 191.15 3,748.78 3,696.83 -340.47 -1,499.68 6,027,542.39 532,015.92 2.14 444.25 3_MWD+IFR2+MS+Sag (1) 5,098.24 91.05 190.86 3,746.39 3,694.44 -435.05 -1,518.07 6,027,447.74 531,997.95 0.82 539.88 3_MWD+IFR2+MS+Sag (2) 5,161.82 90.25 190.30 3,745.67 3,693.72 -497.54 -1,529.75 6,027,385.20 531,986.56 1.54 603.04 3_MWD+IFR2+MS+Sag (2) 5,225.55 88.14 190.68 3,746.57 3,694.62 -560.20 -1,541.35 6,027,322.50 531,975.24 3.36 666.35 3_MWD+IFR2+MS+Sag (2) 5,288.72 85.18 190.02 3,750.25 3,698.30 -622.23 -1,552.68 6,027,260.43 531,964.19 4.80 729.02 3_MWD+IFR2+MS+Sag (2) 5,351.68 82.63 189.74 3,756.93 3,704.98 -683.90 -1,563.42 6,027,198.71 531,953.73 4.07 791.29 3_MWD+IFR2+MS+Sag (2) 5,415.74 82.20 190.09 3,765.39 3,713.44 -746.45 -1,574.35 6,027,136.12 531,943.08 0.86 854.45 3_MWD+IFR2+MS+Sag (2) 5,479.65 83.07 191.77 3,773.58 3,721.63 -808.68 -1,586.37 6,027,073.84 531,931.35 2.94 917.37 3_MWD+IFR2+MS+Sag (2) 5,542.95 83.38 192.74 3,781.05 3,729.10 -870.10 -1,599.71 6,027,012.36 531,918.28 1.60 979.57 3_MWD+IFR2+MS+Sag (2) 5,606.99 84.25 194.46 3,787.95 3,736.00 -931.98 -1,614.68 6,026,950.43 531,903.59 3.00 1,042.35 3_MWD+IFR2+MS+Sag (2) 5,670.43 85.06 193.91 3,793.86 3,741.91 -993.22 -1,630.16 6,026,889.12 531,888.39 1.54 1,104.51 3_MWD+IFR2+MS+Sag (2) 5,734.10 86.11 194.05 3,798.76 3,746.81 -1,054.82 -1,645.50 6,026,827.46 531,873.33 1.66 1,167.03 3_MWD+IFR2+MS+Sag (2) 5,797.78 86.61 193.37 3,802.80 3,750.85 -1,116.56 -1,660.56 6,026,765.66 531,858.55 1.32 1,229.67 3_MWD+IFR2+MS+Sag (2) 5,861.46 87.90 193.42 3,805.85 3,753.90 -1,178.43 -1,675.30 6,026,703.73 531,844.10 2.03 1,292.43 3_MWD+IFR2+MS+Sag (2) 5,924.54 89.45 192.59 3,807.31 3,755.36 -1,239.88 -1,689.49 6,026,642.23 531,830.18 2.79 1,354.71 3_MWD+IFR2+MS+Sag (2) 5,988.63 90.74 192.15 3,807.20 3,755.25 -1,302.48 -1,703.22 6,026,579.57 531,816.74 2.13 1,418.11 3_MWD+IFR2+MS+Sag (2) 6,051.90 91.73 190.67 3,805.84 3,753.89 -1,364.48 -1,715.73 6,026,517.52 531,804.51 2.81 1,480.84 3_MWD+IFR2+MS+Sag (2) 6,115.71 92.59 190.75 3,803.44 3,751.49 -1,427.13 -1,727.58 6,026,454.82 531,792.94 1.35 1,544.17 3_MWD+IFR2+MS+Sag (2) 6,179.00 93.89 190.63 3,799.86 3,747.91 -1,489.22 -1,739.30 6,026,392.68 531,781.50 2.06 1,606.92 3_MWD+IFR2+MS+Sag (2) 6,242.79 95.82 190.18 3,794.46 3,742.51 -1,551.74 -1,750.78 6,026,330.12 531,770.30 3.11 1,670.09 3_MWD+IFR2+MS+Sag (2) 6,307.32 96.93 189.60 3,787.30 3,735.35 -1,614.91 -1,761.79 6,026,266.90 531,759.57 1.94 1,733.88 3_MWD+IFR2+MS+Sag (2) 6,370.72 97.80 188.70 3,779.17 3,727.22 -1,676.99 -1,771.79 6,026,204.79 531,749.86 1.97 1,796.50 3_MWD+IFR2+MS+Sag (2) 6,434.43 98.67 187.35 3,770.04 3,718.09 -1,739.42 -1,780.60 6,026,142.32 531,741.34 2.50 1,859.39 3_MWD+IFR2+MS+Sag (2) 6,498.18 99.60 186.87 3,759.92 3,707.97 -1,801.88 -1,788.39 6,026,079.84 531,733.83 1.64 1,922.24 3_MWD+IFR2+MS+Sag (2) 6,561.46 99.98 185.34 3,749.16 3,697.21 -1,863.88 -1,795.02 6,026,017.81 531,727.48 2.46 1,984.56 3_MWD+IFR2+MS+Sag (2) 6,624.98 98.36 183.51 3,739.04 3,687.09 -1,926.40 -1,799.85 6,025,955.28 531,722.92 3.82 2,047.26 3_MWD+IFR2+MS+Sag (2) 6,688.77 96.11 182.22 3,731.00 3,679.05 -1,989.60 -1,803.02 6,025,892.08 531,720.05 4.06 2,110.52 3_MWD+IFR2+MS+Sag (2) 6,752.56 93.27 180.65 3,725.79 3,673.84 -2,053.14 -1,804.61 6,025,828.53 531,718.74 5.08 2,174.03 3_MWD+IFR2+MS+Sag (2) 6,815.85 91.29 180.94 3,723.27 3,671.32 -2,116.37 -1,805.48 6,025,765.30 531,718.15 3.16 2,237.16 3_MWD+IFR2+MS+Sag (2) 6,879.63 90.92 181.49 3,722.04 3,670.09 -2,180.13 -1,806.84 6,025,701.55 531,717.08 1.04 2,300.86 3_MWD+IFR2+MS+Sag (2) 6,942.51 93.22 184.09 3,719.77 3,667.82 -2,242.88 -1,809.89 6,025,638.79 531,714.31 5.52 2,363.67 3_MWD+IFR2+MS+Sag (2) 7,005.99 92.90 184.21 3,716.38 3,664.43 -2,306.11 -1,814.48 6,025,575.55 531,710.01 0.54 2,427.06 3_MWD+IFR2+MS+Sag (2) 7,069.43 92.59 184.02 3,713.34 3,661.39 -2,369.31 -1,819.03 6,025,512.33 531,705.75 0.57 2,490.43 3_MWD+IFR2+MS+Sag (2) 7,132.61 92.90 183.69 3,710.32 3,658.37 -2,432.27 -1,823.27 6,025,449.35 531,701.79 0.72 2,553.53 3_MWD+IFR2+MS+Sag (2) 7,196.28 93.83 183.92 3,706.58 3,654.63 -2,495.69 -1,827.49 6,025,385.92 531,697.86 1.50 2,617.09 3_MWD+IFR2+MS+Sag (2) 7,260.09 94.58 184.15 3,701.90 3,649.95 -2,559.17 -1,831.97 6,025,322.43 531,693.67 1.23 2,680.73 3_MWD+IFR2+MS+Sag (2) 7,323.22 93.08 184.24 3,697.68 3,645.73 -2,621.99 -1,836.57 6,025,259.60 531,689.34 2.38 2,743.72 3_MWD+IFR2+MS+Sag (2) 7,386.60 92.34 185.02 3,694.69 3,642.74 -2,685.09 -1,841.68 6,025,196.48 531,684.52 1.70 2,807.02 3_MWD+IFR2+MS+Sag (2) 7,450.27 94.27 186.71 3,691.02 3,639.07 -2,748.32 -1,848.18 6,025,133.23 531,678.31 4.03 2,870.55 3_MWD+IFR2+MS+Sag (2) 11221202012:43:46PM Page 4 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-24 Project: Milne Point ND Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Site: M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Well: MPU M-24 North Reference: True Wellbore: MPU M-24 Survey Calculation Method: Minimum Curvature Design: MPU M-24 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,513.89 94.01 186.82 3,686.42 3,634.47 -2,811.33 -1,855.65 6,025,070.19 531,671.12 0.44 2,933.93 3_MWD+IFR2+MS+Sag (2) 7,577.97 94.58 185.85 3,681.62 3,629.67 -2,874.84 -1,862.70 6,025,006.66 531,664.35 1.75 2,997.77 3_MWD+IFR2+MS+Sag (2) 7,641.71 93.27 184.80 3,677.26 3,625.31 -2,938.15 -1,868.60 6,024,943.33 531,658.74 2.63 3,061.34 3_MWD+IFR2+MS+Sag (2) 7,705.41 91.79 185.44 3,674.45 3,622.50 -3,001.54 -1,874.28 6,024,879.92 531,653.35 2.53 3,124.97 3_MWD+IFR2+MS+Sag (2) 7,767.25 89.81 184.92 3,673.59 3,621.64 -3,063.11 -1,879.87 6,024,818.33 531,648.04 3.31 3,186.79 3_MWD+IFR2+MS+Sag (2) 7,831.58 88.58 184.22 3,674.49 3,622.54 -3,127.23 -1,884.99 6,024,754.19 531,643.20 2.20 3,251.10 3_MWD+IFR2+MS+Sag (2) 7,896.23 88.52 184.26 3,676.13 3,624.18 -3,191.68 -1,889.77 6,024,689.73 531,638.72 0.11 3,315.73 3_MWD+IFR2+MS+Sag (2) 7,959.80 89.14 183.53 3,677.42 3,625.47 -3,255.09 -1,894.09 6,024,626.31 531,634.69 1.51 3,379.29 3_MWD+IFR2+MS+Sag (2) 8,023.51 88.83 183.38 3,678.55 3,626.60 -3,318.68 -1,897.93 6,024,562.71 531,631.13 0.54 3,442.99 3_MWD+IFR2+MS+Sag (2) 8,087.32 88.76 182.91 3,679.89 3,627.94 -3,382.38 -1,901.43 6,024,499.00 531,627.92 0.74 3,506.78 3_MWD+IFR2+MS+Sag (2) 8,150.63 90.37 182.42 3,680.37 3,628.42 -3,445.62 -1,904.37 6,024,435.76 531,625.26 2.66 3,570.06 3_MWD+IFR2+MS+Sag (2) 8,214.38 91.61 182.48 3,679.27 3,627.32 -3,509.30 -1,907.09 6,024,372.07 531,622.83 1.95 3,633.78 3_MWD+IFR2+MS+Sag (2) 8,277.62 92.90 183.00 3,676.78 3,624.83 -3,572.41 -1,910.11 6,024,308.95 531,620.09 2.20 3,696.95 3_MWD+IFR2+MS+Sag (2) 8,341.18 93.65 183.22 3,673.15 3,621.20 -3,635.78 -1,913.56 6,024,245.58 531,616.93 1.23 3,760.40 3_MWD+IFR2+MS+Sag (2) 8,405.09 93.82 183.67 3,668.99 3,617.04 -3,699.43 -1,917.39 6,024,181.91 531,613.39 0.75 3,824.17 3_MWD+IFR2+MS+Sag (2) 8,468.68 94.20 183.67 3,664.54 3,612.59 -3,762.74 -1,921.45 6,024,118.59 531,609.61 0.60 3,887.61 3_MWD+IFR2+MS+Sag (2) 8,532.91 94.88 183.82 3,659.46 3,607.51 -3,826.63 -1,925.63 6,024,054.69 531,605.72 1.08 3,951.63 3_MWD+IFR2+MS+Sag (2) 8,596.43 95.82 184.62 3,653.54 3,601.59 -3,889.70 -1,930.29 6,023,991.61 531,601.35 1.94 4,014.88 3_MWD+IFR2+MS+Sag (2) 8,660.24 93.88 184.09 3,648.14 3,596.19 -3,953.10 -1,935.11 6,023,928.20 531,596.81 3.15 4,078.45 3_MWD+IFR2+MS+Sag (2) 8,724.00 92.40 183.77 3,644.65 3,592.70 -4,016.61 -1,939.48 6,023,864.67 531,592.73 2.37 4,142.11 3_MWD+IFR2+MS+Sag (2) 8,787.46 92.77 183.96 3,641.79 3,589.84 -4,079.86 -1,943.75 6,023,801.41 531,588.75 0.66 4,205.51 3_MWD+IFR2+MS+Sag (2) 8,850.79 93.58 184.54 3,638.28 3,586.33 -4,142.92 -1,948.43 6,023,738.33 531,584.34 1.57 4,268.74 3_MWD+IFR2+MS+Sag (2) 8,913.58 94.63 185.25 3,633.79 3,581.84 -4,205.32 -1,953.78 6,023,675.92 531,579.28 2.02 4,331.36 3_MWD+IFR2+MS+Sag (2) 8,977.43 96.07 185.06 3,627.83 3,575.88 -4,268.63 -1,959.49 6,023,612.59 531,573.86 2.27 4,394.92 3_MWD+IFR2+MS+Sag (2) 9,041.86 96.31 185.10 3,620.88 3,568.93 -4,332.43 -1,965.16 6,023,548.76 531,568.47 0.38 4,458.96 3_MWD+IFR2+MS+Sag (2) 9,105.28 95.56 184.83 3,614.33 3,562.38 -4,395.27 -1,970.62 6,023,485.90 531,563.30 1.26 4,522.03 3_MWD+IFR2+MS+Sag (2) 9,169.48 93.70 184.19 3,609.15 3,557.20 -4,459.06 -1,975.65 6,023,422.10 531,558.55 3.06 4,586.02 3_MWD+IFR2+MS+Sag (2) 9,233.22 91.35 183.99 3,606.34 3,554.39 -4,522.58 -1,980.19 6,023,358.57 531,554.30 3.70 4,649.69 3_MWD+IFR2+MS+Sag (2) 9,295.75 90.36 183.67 3,605.40 3,553.45 -4,584.96 -1,984.37 6,023,296.18 531,550.41 1.66 4,712.21 3_MWD+IFR2+MS+Sag (2) 9,325.00 89.71 183.57 3,605.39 3,553.44 -4,614.15 -1,986.22 6,023,266.98 531,548.69 2.25 4,741.46 3_MWD+IFR2+MS+Sag (3) 9,358.83 88.95 183.46 3,605.78 3,553.83 -4,647.91 -1,988.29 6,023,233.21 531,546,77 2.27 4,775.29 3_MWD+IFR2+MS+Sag (3) 9,422.83 86.23 183.30 3,608.47 3,556.52 -4,711.74 -1,992.06 6,023,169.38 531,543.29 4.26 4,839.22 3_MWD+IFR2+MS+Sag (3) 9,486.17 83.94 182.99 3,613.90 3,561.95 -4,774.75 -1,995.52 6,023,106.36 531,540.11 3.65 4,902.32 3_MWD+IFR2+MS+Sag (3) 9,550.03 83.51 182.93 3,620.88 3,568.93 -4,838.14 -1,998.80 6,023,042.96 531,537.12 0.68 4,965.78 3_MWD+IFR2+MS+Sag (3) 9,613.89 83.63 183.09 3,628.03 3,576.08 -4,901.51 -2,002.13 6,022,979.58 531,534.07 0.31 5,029.23 3_MWD+IFR2+MS+Sag (3) 9,677.94 83.82 183.33 3,635.03 3,583.08 -4,965.08 -2,005.70 6,022,916.01 531,530.79 0.48 5,092.89 3_MWD+IFR2+MS+Sag (3) 9,741.59 83.82 183.85 3,641.88 3,589.93 -5,028.23 -2,009.66 6,022,852.84 531,527.12 0.81 5,156.17 3_MWD+IFR2+MS+Sag (3) 9,805.03 83.07 184.45 3,649.13 3,597.18 -5,091.09 -2,014.22 6,022,789.97 531,522.84 1.51 5,219.20 3_MWD+IFR2+MS+Sag (3) 9,868.64 83.94 184.76 3,656.32 3,604.37 -5,154.09 -2,019.30 6,022,726.95 531,518.05 1.45 5,282.39 3_MWD+IFR2+MS+Sag (3) 9,932.17 86.11 184.63 3,661.83 3,609.88 -5,217.16 -2,024.48 6,022,663.86 531,513.15 3.42 5,345.67 3_MWD+IFR2+MS+Sag (3) 1/22/2020 12:43:46PM Page 5 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU K24 Project: Milne Point TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Site: M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Well: MPU M-24 North Reference: True Wellbore: MPU M-24 Survey Calculation Method: Minimum Curvature Design: MPU M-24 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,995.67 87.84 184.85 3,665.18 3,613.23 -5,280.36 -2,029.72 6,022,600.65 531,508.20 2.75 5,409.08 3_MWD+IFR2+MS+Sag (3) 10,059.63 89.38 184.94 3,666.73 3,614.78 -5,344.06 -2,035.17 6,022,536.93 531,503.03 2.41 5,473.01 3_MWD+IFR2+MS+Sag (3) 10,123.22 91.24 185.21 3,666.39 3,614.44 -5,407.40 -2,040.80 6,022,473.57 531,497.69 2.96 5,536.59 3_MWD+IFR2+MS+Sag (3) 10,185.84 92.96 185.56 3,664.09 3,612.14 -5,469.70 -2,046.67 6,022,411.26 531,492.10 2.80 5,599.14 3_MWD+IFR2+MS+Sag (3) 10,249.66 94.45 184.95 3,659.97 3,608.02 -5,533.11 -2,052.50 6,022,347.82 531,486.55 2.52 5,662.81 3_MWD+IFR2+MS+Sag (3) 10,313.06 96.13 185.05 3,654.13 3,602.18 -5,596.00 -2,058.00 6,022,284.91 531,481.34 2.65 5,725.93 3_MWD+IFR2+MS+Sag (3) 10,377.78 97.55 184.55 3,646.42 3,594.47 -5,660.03 -2,063.38 6,022,220.86 531,476.25 2.32 5,790.18 3_MWD+IFR2+MS+Sag (3) 10,441.43 97.74 184.33 3,637.95 3,586.00 -5,722.93 -2,068.26 6,022,157.95 531,471.65 0.45 5,853.26 3_MWD+IFR2+MS+Sag (3) 10,505.13 97.50 184.05 3,629.50 3,577.55 -5,785.90 -2,072.88 6,022,094.97 531,467.32 0.58 5,916.40 3_MWD+IFR2+MS+Sag (3) 10,568.99 96.68 183.70 3,621.62 3,569.67 -5,849.12 -2,077.16 6,022,031.73 531,463.32 1.39 5,979.77 3_MWD+IFR2+MS+Sag (3) 10,632.44 94.87 183.26 3,615.24 3,563.29 -5,912.13 -2,080.99 6,021,968.71 531,459.77 2.93 6,042.89 3_MWD+IFR2+MS+Sag (3) 10,696.23 94.51 182.52 3,610.02 3,558.07 -5,975.63 -2,084.20 6,021,905.21 531,456.86 1.29 6,106.46 3_MWD+IFR2+MS+Sag (3) 10,760.06 95.37 182.33 3,604.52 3,552.57 -6,039.16 -2,086.89 6,021,841.67 531,454.45 1.38 6,170.03 3_MWD+IFR2+MS+Sag (3) 10,824.03 93.09 181.38 3,599.81 3,547.86 -6,102.92 -2,088.95 6,021,777.91 531,452.68 3.86 6,233.77 3_MWD+IFR2+MS+Sag (3) 10,887.53 90.05 178.62 3,598.07 3,546.12 -6,166.38 -2,088.95 6,021,714.46 531,452.96 6.46 6,297.08 3_MWD+IFR2+MS+Sag (3) 10,951.31 90.43 178.84 3,597.80 3,545.85 -6,230.15 -2,087.54 6,021,650.71 531,454.66 0.69 6,360.59 3_MWD+IFR2+MS+Sag (3) 11,014.84 90.30 178.33 3,597.39 3,545.44 -6,293.66 -2,085.97 6,021,587.21 531,456.52 0.83 6,423.83 3_MWD+IFR2+MS+Sag (3) 11,078.77 90.99 178.83 3,596.67 3,544.72 -6,357.56 -2,084.38 6,021,523.32 531,458.39 1.33 6,487.47 3_MWD+IFR2+MS+Sag (3) 11,142.14 90.80 179.77 3,595.68 3,543.73 -6,420.92 -2,083.61 6,021,459.97 531,459.45 1.51 6,550.62 3_MWD+IFR2+MS+Sag (3) 11,205.90 91.60 180.38 3,594.35 3,542.40 -6,484.66 -2,083.69 6,021,396.23 531,459.65 1.58 6,614.22 3_MWD+IFR2+MS+Sag (3) 11,269.10 92.29 182.34 3,592.20 3,540.25 -6,547.81 -2,085.19 6,021,333.09 531,458.44 3.29 6,677.31 3_MWD+IFR2+MS+Sag (3) 11,333.47 92.04 182.39 3,589.77 3,537.82 -6,612.08 -2,087.85 6,021,268.82 531,456.07 0.40 6,741.61 3_MWD+IFR2+MS+Sag (3) 11,397.10 90.49 182.41 3,588.37 3,536.42 -6,675.63 -2,090.51 6,021,205.26 531,453.70 2.44 6,805.20 3_MWD+IFR2+MS+Sag (3) 11,460.50 89.51 183.36 3,588.37 3,536.42 -6,738.95 -2,093.70 6,021,141.93 531,450.79 2.15 6,868.58 3_MWD+IFR2+MS+Sag (3) 11,523.48 87.59 183.68 3,589.96 3,538.01 -6,801.79 -2,097.57 6,021,079.08 531,447.21 3.09 6,931.54 3_MWD+IFR2+MS+Sag (3) 11,586.93 88.15 184.56 3,592.32 3,540.37 -6,865.03 -2,102.12 6,021,015.83 531,442.94 1.64 6,994.94 3_MWD+IFR2+MS+Sag (3) 11,651.03 87.96 186.67 3,594.50 3,542.55 -6,928.78 -2,108.39 6,020,952.05 531,436.96 3.30 7,058.98 3_MWD+IFR2+MS+Sag (3) 11,713.26 88.52 187.74 3,596.41 3,544.46 -6,990.49 -2,116.19 6,020,890.32 531,429.44 1.94 7,121.08 3_MWD+IFR2+MS+Sag (3) 11,777.81 89.69 188.18 3,597.41 3,545.46 -7,054.41 -2,125.13 6,020,826.36 531,420.79 1.94 7,185.47 3_MWD+IFR2+MS+Sag (3) 11,842.06 91.30 188.07 3,596.86 3,544.91 -7,118.01 -2,134.21 6,020,762.73 531,412.00 2.51 7,249.55 3_MWD+IFR2+MS+Sag (3) 11,906.09 91.11 187.15 3,595.51 3,543.56 -7,181.46 -2,142.69 6,020,699.25 531,403.81 1.47 7,313.43 3_MWD+IFR2+MS+Sag (3) 11,969.83 91.79 187.20 3,593.90 3,541.95 -7,244.68 -2,150.64 6,020,636.00 531,396.13 1.07 7,377.05 3_MWD+IFR2+MS+Sag (3) 12,033.82 91.54 186.94 3,592.04 3,540.09 -7,308.16 -2,158.52 6,020,572.49 531,388.55 0.56 7,440.93 3_MWD+IFR2+MS+Sag (3) 12,050.00 90.97 187.17 3,591.69 3,539.74 -7,324.21 -2,160.50 6,020,556.43 531,386.63 3.80 7,457.08 3_MWD+IFR2+MS+Sag (4) 12,096.80 89.32 187.83 3,591.57 3,539.62 -7,370.61 -2,166.61 6,020,510.01 531,380.73 3.80 7,503.79 3_MWD+IFR2+MS+Sag (4) 12,160.02 89.14 188.51 3,592.42 3,540.47 -7,433.18 -2,175.60 6,020,447.41 531,372.03 1.11 7,566.84 3_MWD+IFR2+MS+Sag (4) 12,223.56 91.12 189.31 3,592.27 3,540.32 -7,495.95 -2,185.44 6,020,384.60 531,362.48 3.36 7,630.14 3_MWD+IFR2+MS+Sag (4) 12,287.19 90.06 190.71 3,591.62 3,539.67 -7,558.61 -2,196.50 6,020,321.90 531,351.70 2.76 7,693.41 3_MWD+IFR2+MS+Sag (4) 12,351.25 88.52 190.95 3,592.41 3,540.46 -7,621.52 -2,208.53 6,020,258.94 531,339.95 2.43 7,757.01 3_MWD+IFR2+MS+Sag (4) 12,414.69 88.70 190.54 3,593.95 3,542.00 -7,683.83 -2,220.36 6,020,196.58 531,328.41 0.71 7,819.99 3_MWD+IFR2+MS+Sag (4) 1/222020 12:43:46PM Page 6 COMPASS 5000.15 Build 91E Company: Project: Site: Well: Wellbore: Design: Survey Halliburton Definitive Survey Report Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU IW24 Milne Point TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft MPU M-24 North Reference: True MPU M-24 Survey Calculation Method: Minimum Curvature MPU M-24 Database: NORTH US + CANADA MD Inc (usft) (°) 12,478.26 89.32 12,541.64 90.43 12,605.00 91.55 12,668.26 90.68 12,731.56 90.25 12,795.29 89.50 12,858.68 90.13 12,922.55 90.12 12,986.07 88.27 13,049.46 88.76 13,113.39 89.63 13,176.76 89.88 13,240.26 88.83 13,303.96 88.70 13,366.73 89.01 13,430.60 89.01 13,494.09 89.32 13,558.14 90.06 13,621.73 91.30 13,683.19 92.48 13,748.57 93.58 13,811.47 93.95 13,875.08 91.60 13,938.53 90.80 187.89 184.82 184.50 184.10 183.15 182.92 182.58 181.30 182.44 182.24 181.94 181.96 182.44 183.17 183.75 3,592.35 3,592.49 3,592.69 3,592.55 3,593.45 3,595.09 3,595.99 3,596.26 3,596.97 3,598.34 3,599.60 3,600.70 3,601.63 3,601.97 3,601.22 3,540.40 3,540.54 3,540.74 3,540.60 3,541.50 3,543.14 3,544.04 3,544.31 3,545.02 3,546.39 3,547.65 3,548.75 3,549.68 3,550.02 3,549.27 -7,996.43 -8,059.76 -8,122.94 -8,186.63 -8,250.02 -8,313.30 -8,377.15 -8,440.48 -8,503.94 -8,567.57 -8,630.29 -8,694.11 -8,757.55 -8,821.52 -8,884.99 184.39 3,599.19 3,547.24 -8,946.26 185.11 3,595.74 3,543.79 -9,011.32 184.92 3,591.61 3,539.66 -9,073.84 183.36 3,588.53 3,536.58 -9,137.21 183.46 3,587.20 3,535.25 -9,200.53 14,002.13 91.42 183.97 3,585.97 3,534.02 -9,263.98 14,065.37 91.91 184.00 3,584.13 3,532.18 -9,327.04 14,129.10 91.54 184.77 3,582.21 3,530.26 -9,390.56 14,192.58 90.68 186.15 3,580.98 3,529.03 -9,453.74 14,256.02 89.75 185.74 3,580.74 3,528.79 -9,516.83 14,319.79 89.88 186.22 3,580.95 3,529.00 -9,580.26 14,383.44 89.93 186.36 3,581.05 3,529.10 -9,643.52 14,439.90 91.05 186.21 3,580.57 3,528.62 -9,699.64 14,508.00 91.05 186.21 3,579.32 3,527.37 -9,767.33 -2,271.80 6,019,883.78 -2,278.86 6,019,820.42 -2,284.01 6, 019, 757.23 -2,288.80 6,019,693.52 -2,292.81 6, 019, 630.13 -2,296.17 6,019,566.84 -2,299.23 6,019,502.99 -2,301.38 6,019,439.65 -2,303.45 6,019,376.19 -2,306.05 6,019,312.55 -2,308.34 6,019,249.83 -2,310.51 6,019,186.01 -2,312.95 6,019,122.57 -2,316.08 6,019,058.59 -2,319.92 6,018,995.11 -2,324.28 6,018,933.83 -2,329.69 6,018,868.74 -2,335.17 6,018,806.20 -2,339.76 6,018,742.83 -2,343.53 6,018,679.49 -2,347.65 6,018,616.03 -2,352.05 6,018,552.95 -2,356.92 6,018,489.42 -2,362.95 6,018,426.23 -2,369.53 6,018,363.11 -2,376.17 6,018,299.66 -2,383.14 6,018,236.37 -2,389.32 6,018,180.23 -2,396.69 6,018,112.52 531,278.38 531,271.61 531, 266.74 531,262.24 531,258.51 531,255.44 531,252.66 531,250.80 531,249.02 531,246.71 1.62 4.96 1.11 0.63 3.27 0.85 1.46 2.06 2.44 0.37 531,244.70 0.69 531,242.81 0.03 531,240.66 0.90 531,237.82 1.62 531,234.27 2.15 531,230.18 2.18 531,225.07 2.01 531,219.87 0.66 531,215.57 4.43 531,212.08 1.27 531,208.25 1.26 531,204.14 0.78 531,199.55 1.34 531,193.80 2.56 531,187.52 1.60 531,181.16 531,174.47 531,168.54 531.161.48 0.78 0.23 2.00 0.00 Vertical Section (ft) Survey Tool Name 7,883.17 3_MWD+IFR2+MS+Sag (4) 7,946.24 3_MWD+IFR2+MS+Sag (4) 8,009.31 3_MWD+IFR2+MS+Sag (4) 8,072.31 3_MWD+IFR2+MS+Sag (4) 8,135.43 3_MWD+IFR2+MS+Sag (4) 8,199.10 3_MWD+IFR2+MS+Sag (4) 8,262.48 3_MWD+IFR2+MS+Sag (4) 8,326.35 3_MWD+IFR2+MS+Sag (4) 8,389.86 3_MWD+IFR2+MS+Sag (4) 8,453.22 3_MWD+IFR2+MS+Sag (4) 8,517.13 3_MWD+IFR2+MS+Sag (4) 8,580.45 3_MWD+IFR2+MS+Sag (4) 8,643.90 3_MWD+IFR2+MS+Sag (4) 8,707.56 3_MWD+IFR2+MS+Sag (4) 8,770.28 3_MWD+IFR2+MS+Sag (4) 8,834.10 3_MWD+IFR2+MS+Sag (4) 8,897.56 3_MWD+IFR2+MS+Sag (4) 8,961.59 3_MWD+IFR2+MS+Sag (4) 9,025.17 3_MWD+IFR2+MS+Sag (4) 9,086.60 3_MWD+IFR2+MS+Sag (4) 9,151.88 3_MWD+IFR2+MS+Sag (4) 9,214.63 3_MWD+IFR2+MS+Sag (4) 9,278.16 3_MWD+IFR2+MS+Sag (4) 9,341.59 3_MWD+IFR2+MS+Sag (4) 9,405.18 3_MWD+IFR2+MS+Sag (4) 9,468.39 3_MWD+IFR2+MS+Sag (4) 9,532.09 3_MWD+IFR2+MS+Sag (4) 9,595.54 3_MWD+IFR2+MS+Sag (4) 9,658.94 3_MWD+IFR2+MS+Sag (4) 9,722.67 3_MWD+IFR2+MS+Sag (4) 9,786.27 3_MWD+IFR2+MS+Sag (4) 9,842.68 3_MWD+IFR2+MS+Sag (4) 9,910.72 PROJECTED to TD Checked By: Chelsea Wright Digitally signed by Chelsea Approved By: Benjamin Hand DD -200]0.0,22 13 00'd Date: 01-22-2020 Wright 1/22/2020 12:43:46PM Page 7 COMPASS 5000.15 Build 91E Map Map Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') 189.99 3,595.05 3,543.10 -7,746.37 -2,231.68 6,020,134.00 531,317.37 1.30 189.44 3,595.19 3,543.24 -7,808.84 -2,242.38 6,020,071.49 531,306.95 1.95 189.26 3,594.09 3,542.14 -7,871.35 -2,252.67 6,020,008.94 531,296.94 1.79 188.82 3,592.86 3,540.91 -7,933.81 -2,262.61 6,019,946.44 531,287.29 1.54 187.89 184.82 184.50 184.10 183.15 182.92 182.58 181.30 182.44 182.24 181.94 181.96 182.44 183.17 183.75 3,592.35 3,592.49 3,592.69 3,592.55 3,593.45 3,595.09 3,595.99 3,596.26 3,596.97 3,598.34 3,599.60 3,600.70 3,601.63 3,601.97 3,601.22 3,540.40 3,540.54 3,540.74 3,540.60 3,541.50 3,543.14 3,544.04 3,544.31 3,545.02 3,546.39 3,547.65 3,548.75 3,549.68 3,550.02 3,549.27 -7,996.43 -8,059.76 -8,122.94 -8,186.63 -8,250.02 -8,313.30 -8,377.15 -8,440.48 -8,503.94 -8,567.57 -8,630.29 -8,694.11 -8,757.55 -8,821.52 -8,884.99 184.39 3,599.19 3,547.24 -8,946.26 185.11 3,595.74 3,543.79 -9,011.32 184.92 3,591.61 3,539.66 -9,073.84 183.36 3,588.53 3,536.58 -9,137.21 183.46 3,587.20 3,535.25 -9,200.53 14,002.13 91.42 183.97 3,585.97 3,534.02 -9,263.98 14,065.37 91.91 184.00 3,584.13 3,532.18 -9,327.04 14,129.10 91.54 184.77 3,582.21 3,530.26 -9,390.56 14,192.58 90.68 186.15 3,580.98 3,529.03 -9,453.74 14,256.02 89.75 185.74 3,580.74 3,528.79 -9,516.83 14,319.79 89.88 186.22 3,580.95 3,529.00 -9,580.26 14,383.44 89.93 186.36 3,581.05 3,529.10 -9,643.52 14,439.90 91.05 186.21 3,580.57 3,528.62 -9,699.64 14,508.00 91.05 186.21 3,579.32 3,527.37 -9,767.33 -2,271.80 6,019,883.78 -2,278.86 6,019,820.42 -2,284.01 6, 019, 757.23 -2,288.80 6,019,693.52 -2,292.81 6, 019, 630.13 -2,296.17 6,019,566.84 -2,299.23 6,019,502.99 -2,301.38 6,019,439.65 -2,303.45 6,019,376.19 -2,306.05 6,019,312.55 -2,308.34 6,019,249.83 -2,310.51 6,019,186.01 -2,312.95 6,019,122.57 -2,316.08 6,019,058.59 -2,319.92 6,018,995.11 -2,324.28 6,018,933.83 -2,329.69 6,018,868.74 -2,335.17 6,018,806.20 -2,339.76 6,018,742.83 -2,343.53 6,018,679.49 -2,347.65 6,018,616.03 -2,352.05 6,018,552.95 -2,356.92 6,018,489.42 -2,362.95 6,018,426.23 -2,369.53 6,018,363.11 -2,376.17 6,018,299.66 -2,383.14 6,018,236.37 -2,389.32 6,018,180.23 -2,396.69 6,018,112.52 531,278.38 531,271.61 531, 266.74 531,262.24 531,258.51 531,255.44 531,252.66 531,250.80 531,249.02 531,246.71 1.62 4.96 1.11 0.63 3.27 0.85 1.46 2.06 2.44 0.37 531,244.70 0.69 531,242.81 0.03 531,240.66 0.90 531,237.82 1.62 531,234.27 2.15 531,230.18 2.18 531,225.07 2.01 531,219.87 0.66 531,215.57 4.43 531,212.08 1.27 531,208.25 1.26 531,204.14 0.78 531,199.55 1.34 531,193.80 2.56 531,187.52 1.60 531,181.16 531,174.47 531,168.54 531.161.48 0.78 0.23 2.00 0.00 Vertical Section (ft) Survey Tool Name 7,883.17 3_MWD+IFR2+MS+Sag (4) 7,946.24 3_MWD+IFR2+MS+Sag (4) 8,009.31 3_MWD+IFR2+MS+Sag (4) 8,072.31 3_MWD+IFR2+MS+Sag (4) 8,135.43 3_MWD+IFR2+MS+Sag (4) 8,199.10 3_MWD+IFR2+MS+Sag (4) 8,262.48 3_MWD+IFR2+MS+Sag (4) 8,326.35 3_MWD+IFR2+MS+Sag (4) 8,389.86 3_MWD+IFR2+MS+Sag (4) 8,453.22 3_MWD+IFR2+MS+Sag (4) 8,517.13 3_MWD+IFR2+MS+Sag (4) 8,580.45 3_MWD+IFR2+MS+Sag (4) 8,643.90 3_MWD+IFR2+MS+Sag (4) 8,707.56 3_MWD+IFR2+MS+Sag (4) 8,770.28 3_MWD+IFR2+MS+Sag (4) 8,834.10 3_MWD+IFR2+MS+Sag (4) 8,897.56 3_MWD+IFR2+MS+Sag (4) 8,961.59 3_MWD+IFR2+MS+Sag (4) 9,025.17 3_MWD+IFR2+MS+Sag (4) 9,086.60 3_MWD+IFR2+MS+Sag (4) 9,151.88 3_MWD+IFR2+MS+Sag (4) 9,214.63 3_MWD+IFR2+MS+Sag (4) 9,278.16 3_MWD+IFR2+MS+Sag (4) 9,341.59 3_MWD+IFR2+MS+Sag (4) 9,405.18 3_MWD+IFR2+MS+Sag (4) 9,468.39 3_MWD+IFR2+MS+Sag (4) 9,532.09 3_MWD+IFR2+MS+Sag (4) 9,595.54 3_MWD+IFR2+MS+Sag (4) 9,658.94 3_MWD+IFR2+MS+Sag (4) 9,722.67 3_MWD+IFR2+MS+Sag (4) 9,786.27 3_MWD+IFR2+MS+Sag (4) 9,842.68 3_MWD+IFR2+MS+Sag (4) 9,910.72 PROJECTED to TD Checked By: Chelsea Wright Digitally signed by Chelsea Approved By: Benjamin Hand DD -200]0.0,22 13 00'd Date: 01-22-2020 Wright 1/22/2020 12:43:46PM Page 7 COMPASS 5000.15 Build 91E Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-24PB1 500292365770 Sperry Drilling Definitive Survey Report 22 January, 2020 HALLIBURT®111 Sperry Drillint Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-24 Project: Milne Point TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Site: M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Well: MPU M-24 North Reference: True Wellbore: MPU M-24PB1 Survey Calculation Method: Minimum Curvature Design: MPU M-24PB1 Database: NORTH US + CANADA >roject Milne Point, ACT, MILNE POINT Rap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level 'eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point nap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU M-24, Slot 16 Well Position +N/ -S 0.00 usft +E/ -W 0.00 usft Position Uncertainty 0.50 usft Wellbore MPU M-24PB1 Northing: 6,027,889.58 usfl Latitude: Easting: 533,513.90 usfl Longitude: Wellhead Elevation: 0.00 usfl Ground Level: Magnetics Model Name Sample Date Declination (`) BGGM2018 11/26/2019 Design MPU M-24PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) +N/ -S (usft) (usft) 26.65 0.00 16.35 Dip Angle (1) 80.94 Tie On Depth: 26.65 +E/ -W Direction (usft) (I 0.00 184.00 70° 29'14.016 N 149° 43'33.871 W 25.30 usft Field Strength (nT) 57,406.43490786 Survey Program Date 1/13/2020 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 206.41 5,001.86 MPU M-24PB1 SH MWD+IFR2+MS+Sac 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 11/27/2019 5,098.54 5,732.50 MPU M-24PB1 PH MWD+IFR2+MS+Sac 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 01/02/2020 S u rvey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 26.65 0.00 0.00 26.65 -25.30 0.00 0.00 6,027,889.58 533,513.90 0.00 0.00 UNDEFINED 206.41 0.14 4.54 206.41 154.46 0.22 0.02 6,027,889.80 533,513.92 0.08 -0.22 3_MWD+IFR2+MS+Sag (1) 298.47 0.16 23.95 298.47 246.52 0.45 0.08 6,027,890.03 533,513.98 0.06 -0.45 3_MWD+IFR2+MS+Sag (1) 389.89 1.56 340.07 389.88 337.93 1.74 -0.29 6,027,891.31 533,513.60 1.58 -1.71 3_MWD+IFR2+MS+Sag (1) 485.26 3.85 333.95 485.13 433.18 5.83 -2.14 6,027,895.40 533,511.73 2.42 -5.67 3_MWD+IFR2+MS+Sag (1) 577.83 7.76 331.13 577.21 525.26 14.10 -6.53 6,027,903.65 533,507.31 4.23 -13.61 3_MWD+IFR2+MS+Sag (1) 671.15 10.75 328.35 669.31 617.36 27.03 -14.14 6,027,916.54 533,499.64 3.24 -25.98 3_MWD+IFR2+MS+Sag (1) 766.59 13.99 329.76 762.52 710.57 44.58 -24.62 6,027,934.04 533,489.08 3.41 -42.75 3_MWD+IFR2+MS+Sag (1) 861.85 19.14 329.56 853.80 801.85 68.01 -38.34 6,027,957.41 533,475.26 5.41 -65.17 3_MWD+IFR2+MS+Sag (1) 957.40 23.41 329.78 942.81 890.86 97.93 -55.84 6,027,987.24 533,457.63 4.47 -93.79 3_MWD+IFR2+MS+Sag (1) 1,052.12 26.82 332.20 1,028.57 976.62 133.10 -75.28 6,028,022.33 533,438.03 3.76 -127.52 3_MWD+IFR2+MS+Sag (1) 1,147.38 30.03 332.80 1,112.33 1,060.38 173.32 -96.21 6,028,062.45 533,416.92 3.38 -166.19 3_MWD+IFR2+MS+Sag (1) 1,242.27 33.26 333.11 1,193.10 1,141.15 217.66 -118.83 6,028,106.68 533,394.10 3.41 -208.84 3_MWD+IFR2+MS+Sag (1) 1122202012:52:18PM Page 2 COMPASS 5000.15 Build 91E Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-24 Wellbore: MPU M-24PB1 Design: MPU M-24PB1 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU M-24 MPU M-24 Actual Lateral RKB @ 51.95usft MPU M-24 Actual Lateral RKB @ 51.95usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) 1,337.44 35.79 331.60 1,271.51 1,219.56 265.42 -143.88 6,028,154.32 1,432.40 37.67 331.72 1,347.61 1,295.66 315.40 -170.83 6,028,204.18 1,527.93 38.95 331.58 1,422.57 1,370.62 367.52 -198.96 6,028,256.16 1,622.02 39.22 330.22 1,495.60 1,443.65 419.35 -227.81 6,028,307.86 1,717.52 38.38 330.27 1,570.03 1,518.08 471.30 -257.50 6,028,359.67 1,812.81 37.49 328.97 1,645.19 1,593.24 521.84 -287.12 6,028,410.07 1,908.44 38.81 329.05 1,720.39 1,668.44 572.48 -317.54 6,028,460.56 2,003.65 36.86 329.59 1,795.58 1,743.63 622.70 -347.34 6,028,510.64 2,098.63 38.52 330.28 1,870.74 1,818.79 672.96 -376.42 6,028,560.77 2,193.29 37.80 326.37 1,945.18 1,893.23 722.72 -407.11 6,028,610.38 2,288.76 36.10 320.87 2,021.49 1,969.54 768.91 -441.07 6,028,656.42 2,384.56 33.52 315.64 2,100.16 2,048.21 809.73 -477.39 6,028,697.07 2,479.18 31.37 308.54 2,180.03 2,128.08 843.77 -514.94 6,028,730.94 2,574.22 29.36 300.00 2,262.07 2,210.12 870.85 -554.49 6,028,757.84 2,669.58 28.84 292.08 2,345.43 2,293.48 891.19 -596.06 6,028,777.99 2,765.64 28.71 285.51 2,429.65 2,377.70 906.07 -639.77 6,028,792.67 2,860.70 29.50 276.97 2,512.74 2,460.79 915.02 -685.03 6,028,801.42 2,955.75 29.00 268.01 2,595.71 2,543.76 917.06 -731.31 6,028,803.25 3,050.34 27.55 259.84 2,679.04 2,627.09 912.41 -775.77 6,028,798.39 3,145.08 28.61 252.64 2,762.65 2,710.70 901.77 -819.00 6,028,787.56 3,240.52 32.05 245.63 2,845.04 2,793.09 884.49 -863.91 6,028,770.08 3,332.54 33.85 239.21 2,922.28 2,870.33 861.29 -908.18 6,028,746.68 3,430.07 35.36 230.26 3,002.61 2,950.66 829.32 -953.25 6,028,714.52 3,525.67 38.45 222.38 3,079.09 3,027.14 789.65 -994.59 6,028,674.66 3,621.58 41.59 217.64 3,152.55 3,100.60 742.39 -1,034.15 6,028,627.23 3,716.93 44.12 215.85 3,222.44 3,170.49 690.42 -1,072.92 6,028,575.09 3,812.46 47.35 215.17 3,289.11 3,237.16 634.73 -1,112.64 6,028,519.23 3,907.31 49.61 213.59 3,351.98 3,300.03 576.12 -1,152.72 6,028,460.44 4,002.61 52.61 212.00 3,411.81 3,359.86 513.76 -1,192.87 6,028,397.91 4,098.23 53.48 211.61 3,469.30 3,417.35 448.83 -1,233.14 6,028,332.80 4,192.94 56.50 210.16 3,523.63 3,471.68 382.26 -1,272.94 6,028,266.06 4,288.13 60.94 209.54 3,573.04 3,521.09 311.71 -1,313.41 6,028,195.34 4,383.79 65.16 206.63 3,616.39 3,564.44 236.49 -1,353.51 6,028,119.94 4,478.79 69.04 201.42 3,653.37 3,601.42 156.58 -1,389.06 6,028,039.89 4,573.30 71.64 195.29 3,685.20 3,633.25 72.16 -1,417.03 6,027,955.34 4,668.56 74.89 190.10 3,712.64 3,660.69 -16.80 -1,437.04 6,027,866.31 4,764.38 78.31 190.56 3,734.84 3,682.89 -108.49 -1,453.75 6,027,774.55 4,857.59 86.23 191.67 3,747.37 3,695.42 -199.04 -1,471.55 6,027,683.93 4,952.37 90.74 191.01 3,749.87 3,697.92 -291.91 -1,490.17 6,027,590.98 5,001.86 91.79 191.15 3,748.78 3,696.83 -340.47 -1,499.68 6,027,542.39 Well MPU M-24 MPU M-24 Actual Lateral RKB @ 51.95usft MPU M-24 Actual Lateral RKB @ 51.95usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (°/100') (ft) Survey Tool Name 533,368.84 2.81 -254.74 3_MWD+IFR2+MS+Sag (1) 533,341.66 1.98 -302.72 3_MWD+IFR2+MS+Sag (1) 533,313.31 1.34 -352.75 3_MWD+IFR2+MS+Sag (1) 533,284.23 0.96 -402.44 3_MWD+IFR2+MS+Sag (1) 533,254.30 0.88 -452.19 3_MWD+IFR2+MS+Sag (1) 533,224.46 1.26 -500.54 3_MWD+IFR2+MS+Sag (1) 533,193.82 1.38 -548.93 3_MWD+IFR2+MS+Sag (1) 533,163.79 2.08 -596.95 3_MWD+IFR2+MS+Sag (1) 533,134.48 1.80 -645.06 3_MWD+IFR2+MS+Sag (1) 533,103.58 2.66 -692.56 3_MWD+IFR2+MS+Sag (1) 533,069.41 3.89 -736.27 3_MWD+IFR2+MS+Sag (1) 533,032.91 4.12 -774.46 3_MWD+IFR2+MS+Sag (1) 532,995.21 4.62 -805.80 3_MWD+IFR2+MS+Sag (1) 532,955.55 5.01 -830.05 3_MWD+IFR2+MS+Sag (1) 532,913.89 4.07 -847.44 3_MWD+IFR2+MS+Sag (1) 532,870.11 3.29 -859.24 3_MWD+IFR2+MS+Sag (1) 532,824.82 4.44 -865.01 3_MWD+IFR2+MS+Sag (1) 532,778.54 4.63 -863.82 3_MWD+IFR2+MS+Sag (1) 532,734.10 4.37 -856.07 3_MWD+IFR2+MS+Sag (1) 532,690.92 3.75 -842.44 3_MWD+IFR2+MS+Sag (1) 532,646.10 5.17 -822.08 3_MWD+IFR2+MS+Sag (1) 532,601.94 4.27 -795.84 3_MWD+IFR2+MS+Sag (1) 532,557.02 5.43 -760.81 3_MWD+IFR2+MS+Sag (1) 532,515.86 5.91 -718.35 3_MWD+IFR2+MS+Sag (1) 532,476.52 4.56 -668.44 3_MWD+IFR2+MS+Sag (1) 532,437.99 2.94 -613.89 3_MWD+IFR2+MS+Sag (1) 532,398.52 3.42 -555.57 3_MWD+IFR2+MS+Sag (1) 532,358.71 2.69 -494.31 3_MWD+IFR2+MS+Sag (1) 532,318.84 3.41 -429.30 3_MWD+IFR2+MS+Sag (1) 532,278.87 0.97 -361.71 3_MWD+IFR2+MS+Sag (1) 532,239.38 3.43 -292.53 3_MWD+IFR2+MS+Sag (1) 532,199.23 4.70 -219.33 3_MWD+IFR2+MS+Sag (1) 532,159.48 5.18 -141.49 3_MWD+IFR2+MS+Sag (1) 532,124.28 6.50 -59.31 3_MWD+IFR2+MS+Sag (1) 532,096.70 6.70 26.87 3_MWD+IFR2+MS+Sag (1) 532,077.10 6.23 117.00 3_MWD+IFR2+MS+Sag (1) 532,060.80 3.60 209.63 3_MWD+IFR2+MS+Sag (1) 532,043.41 8.58 301.21 3_MWD+IFR2+MS+Sag (1) 532,025.20 4.81 395.15 3_MWD+IFR2+MS+Sag (1) 532,015.92 2.14 444.25 3_MWD+IFR2+MS+Sag (1) 1/22/202012:52:18PM Page 3 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-24 Project: Milne Point TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Site: M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Well: MPU M-24 North Reference: True Wellbore: MPU M-24PB1 Survey Calculation Method: Minimum Curvature Design: MPU M-24PB1 Database: NORTH US + CANADA S u rvey - Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (a) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,098.54 91.48 190.21 3,746.02 3,694.07 -435.43 -1,517.59 6,027,447.35 531,998.44 1.02 540.24 3_MWD+IFR2+MS+Sag (2) 5,162.23 89.93 190.17 3,745.24 3,693.29 -498.11 -1,528.86 6,027,384.63 531,987.45 2.43 603.55 3_MWD+IFR2+MS+Sag (2) 5,225.34 89.57 190.63 3,745.52 3,693.57 -560.19 -1,540.25 6,027,322.51 531,976.34 0.93 666.26 3_MWD+IFR2+MS+Sag (2) 5,289.19 87.53 189.31 3,747.13 3,695.18 -623.05 -1,551.30 6,027,259.61 531,965.58 3.81 729.74 3_MWD+IFR2+MS+Sag (2) 5,352.12 86.97 188.96 3,750.15 3,698.20 -685.11 -1,561.28 6,027,197.51 531,955.88 1.05 792.35 3_MWD+IFR2+MS+Sag (2) 5,415.91 86.92 187.95 3,753.55 3,701.60 -748.11 -1,570.65 6,027,134.47 531,946.80 1.58 855.85 3_MWD+IFR2+MS+Sag (2) 5,478.50 86.85 188.16 3,756.95 3,705.00 -809.99 -1,579.40 6,027,072.56 531,938.32 0.35 918.19 3_MWD+IFR2+MS+Sag (2) 5,543.22 87.03 188.59 3,760.41 3,708.46 -873.93 -1,588.82 6,027,008.58 531,929.19 0.72 982.63 3_MWD+IFR2+MS+Sag (2) 5,606.17 87.28 189.58 3,763.53 3,711.58 -936.02 -1,598.74 6,026,946.46 531,919.55 1.62 1,045.26 3_MWD+IFR2+MS+Sag (2) 5,670.73 86.54 189.13 3,767.01 3,715.06 -999.62 -1,609.22 6,026,882.81 531,909.36 1.34 1,109.44 3_MWD+IFR2+MS+Sag (2) 5,732.50 85.93 189.98 3,771.07 3,719.12 -1,060.40 -1,619.45 6,026,821.99 531,899.40 1.69 1,170.79 3_MWD+IFR2+MS+Sag (2) 5,803.00 85.93 189.98 3,776.07 3,724.12 -1,129.66 -1,631.64 6,026,752.69 531,887.53 0.00 1,240.73 PROJECTED to TD Checked By: Chelsea Wright Date: 2020.01.22209 by 32 9��•"` Approved By: Benjamin Hand Date ta202 011ysigned21409:27-0900y Benjamin 'dDate: 01-22-2020 1/22/2020 12:52:18PM Page 4 COMPASS 5000.15 Build 91E Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-24PB2 500292365771 Sperry Drilling Definitive Survey Report 22 January, 2020 HALLIBURTON Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-24 Project: Milne Point TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Site: M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Well: MPU M-24 North Reference: True Wellbore: MPU M-24PB2 Survey Calculation Method: Minimum Curvature Design: MPU M-24PB2 Database: NORTH US + CANADA )roject Milne Point, ACT, MILNE POINT Aap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Aap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU M-24, Slot 16 Well Position +N/ -S 0.00 usft Northing: 6,027,889.58 usfl Latitude: 70° 29' 14.016 N Vertical +El -W 0.00 usft Easting: 533,513.90 usfl Longitude: 149'43'33.871 W Position Uncertainty 0.50 usft Wellhead Elevation: 0.00 usfl Ground Level: 25.30 usft Wellbore MPU M-24PB2 Section (usft) V) Magnetics Model Name Sample Date Declination Dip Angle Field Strength (usfl) (ft) (1) (°) (nT) 26.65 BGGM2019 1/13/2020 16.17 80.90 57,402.12794336 Design Audit Notes: Version: Vertical Section: MPU M-24PB2 1.0 Phase: ACTUAL Depth From (TVD) +N/ -S (usfl) (usft) 26.65 0.00 Tie On Depth: 5,001.86 +E/ -W Direction (usft) (1) 0.00 184.00 Survey Program Date 1/16/2020 From To (usfl) (usft) Survey (Wellbore) Tool Name Description Survey Date 206.41 5,001.86 MPU M-24PB1 SH MWD+IFR2+MS+Sac 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 11/27/2019 5,098.24 9,729.96 MPU M-24PB2 PH MWD+IFR2+MS+Sac 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 01/13/2020 S u rvey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) V) (usft) (usfl) (usft) (usfl) (ft) (ft) (°/100') (ft) Survey Tool Name 26.65 0.00 0.00 26.65 -25.30 0.00 0.00 6,027,889.58 533,513.90 0.00 0.00 UNDEFINED 206.41 0.14 4.54 206.41 154.46 0.22 0.02 6,027,889.80 533,513.92 0.08 -0.22 3_MWD+IFR2+MS+Sag (1) 298.47 0.16 23.95 298.47 246.52 0.45 0.08 6,027,890.03 533,513.98 0.06 -0.45 3_MWD+IFR2+MS+Sag (1) 389.89 1.56 340.07 389.88 337.93 1.74 -0.29 6,027,891.31 533,513.60 1.58 -1.71 3_MWD+IFR2+MS+Sag (1) 485.26 3.85 333.95 485.13 433.18 5.83 -2.14 6,027,895.40 533,511.73 2.42 -5.67 3_MWD+IFR2+MS+Sag (1) 577.83 7.76 331.13 577.21 525.26 14.10 -6.53 6,027,903.65 533,507.31 4.23 -13.61 3_MWD+IFR2+MS+Sag (1) 671.15 10.75 328.35 669.31 617.36 27.03 -14.14 6,027,916.54 533,499.64 3.24 -25.98 3_MWD+IFR2+MS+Sag (1) 766.59 13.99 329.76 762.52 710.57 44.58 -24.62 6,027,934.04 533,489.08 3.41 -42.75 3_MWD+IFR2+MS+Sag (1) 861.85 19.14 329.56 853.80 801.85 68.01 -38.34 6,027,957.41 533,475.26 5.41 -65.17 3_MWD+IFR2+MS+Sag (1) 957.40 23.41 329.78 942.81 890.86 97.93 -55.84 6,027,987.24 533,457.63 4.47 -93.79 3_MWD+IFR2+MS+Sag (1) 1,052.12 26.82 332.20 1,028.57 976.62 133.10 -75.28 6,028,022.33 533,438.03 3.76 -127.52 3_MWD+IFR2+MS+Sag (1) 1,147.38 30.03 332.80 1,112.33 1,060.38 173.32 -96.21 6,028,062.45 533,416.92 3.38 -166.19 3_MWD+IFR2+MS+Sag(1) 1,242.27 33.26 333.11 1,193.10 1,141.15 217.66 -118.83 6,028,106.68 533,394.10 3.41 -208.84 3_MWD+IFR2+MS+Sag (1) 11222020 12:53:47PM Page 2 COMPASS 5000.15 Build 91E Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-24 Wellbore: MPU M-24PB2 Design: MPU M-24PB2 S u rvey 2,293.48 MD Inc Azi TVD (usft) (1) (1) (usft) 1,337.44 35.79 331.60 1,271.51 1,432.40 37.67 331.72 1,347.61 1,527.93 38.95 1,622.02 39.22 1,717.52 38.38 1,812.81 37.49 1,908.44 38.81 2,003.65 36.86 2,098.63 38.52 2,193.29 37.80 2,288.76 36.10 2,384.56 33.52 2,479.18 31.37 2,574.22 29.36 2,669.58 28.84 2,765.64 28.71 2,860.70 29.50 331.58 330.22 330.27 328.97 329.05 329.59 330.28 326.37 320.87 315.64 1,422.57 1,495.60 1,570.03 1,645.19 1,720.39 1,795.58 1,870.74 1,945.18 2,021.49 2,100.16 TVDSS (usft) 1,219.56 1,295.66 1,370.62 1,443.65 1,518.08 1,593.24 1,668.44 1,743.63 1,818.79 1,893.23 1,969.54 2,048.21 Halliburton Definitive Survey Report Local Co-ordinate Reference: Well MPU M-24 TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US + CANADA +N/ -S (usft) 265.42 315.40 367.52 419.35 471.30 521.84 572.48 622.70 672.96 722.72 768.91 809.73 308.54 29.00 2,180.03 2,128.08 843.77 300.00 3,050.34 2,262.07 2,210.12 870.85 292.08 912.41 2,345.43 2,293.48 891.19 285.51 2,710.70 2,429.65 2,377.70 906.07 276.97 2,845.04 2,512.74 2,460.79 915.02 2,955.75 29.00 268.01 2,595.71 2,543.76 917.06 3,050.34 27.55 259.84 2,679.04 2,627.09 912.41 3,145.08 28.61 252.64 2,762.65 2,710.70 901.77 3,240.52 32.05 245.63 2,845.04 2,793.09 884.49 3,332.54 33.85 239.21 2,922.28 2,870.33 861.29 3,430.07 35.36 230.26 3,002.61 3,525.67 38.45 222.38 3,079.09 3,621.58 41.59 217.64 3,152.55 3,716.93 44.12 215.85 3,222.44 3,812.46 47.35 215.17 3,289.11 3,907.31 49.61 213.59 3,351.98 4,002.61 52.61 212.00 3,411.81 4,098.23 53.48 211.61 3,469.30 4,192.94 56.50 210.16 3,523.63 4,288.13 60.94 209.54 3,573.04 4,383.79 65.16 206.63 3,616.39 4,478.79 69.04 201.42 3,653.37 4,573.30 71.64 195.29 3,685.20 4,668.56 74.89 190.10 3,712.64 4,764.38 78.31 190.56 3,734.84 4,857.59 86.23 191.67 3,747.37 4,952.37 90.74 191.01 3,749.87 5,001.86 91.79 191.15 3,748.78 1/22/2020 12:53:47PM 2,950.66 829.32 3,027.14 789.65 3,100.60 742.39 3,170.49 690.42 3,237.16 634.73 3,300.03 3,359.86 3,417.35 3,471.68 3,521.09 3,564.44 3,601.42 3,633.25 3,660.69 3,682.89 3,695.42 3,697.92 3,696.83 576.12 -1,152.72 6,028,460.44 513.76 -1,192.87 6,028,397.91 448.83 -1,233.14 6,028,332.80 382.26 -1,272.94 6,028,266.06 311.71 -1,313.41 6,028,195.34 236.49 -1,353.51 6,028,119.94 156.58 -1,389.06 6,028,039.89 72.16 -1,417.03 6,027,955.34 -16.80 -1,437.04 6,027,866.31 -108.49 -1,453.75 6,027,774.55 -199.04 -1,471.55 6,027,683.93 -291.91 -1,490.17 6,027,590.98 -340.47 -1,499.68 6,027,542.39 Page 3 Map Easting DLS (ft) (°/100') 533,368.84 2.81 533,341.66 1.98 533,313.31 1.34 533,284.23 0.96 533,254.30 0.88 533,224.46 1.26 533,193.82 1.38 533,163.79 533,134.48 533,103.58 533,069.41 533,032.91 532,995.21 532,955.55 532,913.89 532,870.11 532,824.82 532,778.54 532,734.10 532,690.92 532,646.10 532,601.94 532,557.02 532,515.86 532,476.52 532,437.99 532,398.52 2.08 1.80 2.66 3.89 4.12 4.62 5.01 4.07 3.29 4.44 4.63 4.37 3.75 5.17 4.27 5.43 5.91 4.56 2.94 3.42 532,358.71 2.69 532,318.84 3.41 532,278.87 0.97 532,239.38 3.43 532,199.23 4.70 532,159.48 5.18 532,124.28 6.50 532,096.70 6.70 532,077.10 6.23 532,060.80 3.60 532,043.41 8.58 532,025.20 4.81 532,015.92 2.14 Vertical Section (ft) Survey Tool Name -254.74 3_MWD+IFR2+MS+Sag (1) -302.72 3_MWD+IFR2+MS+Sag (1) -352.75 3_MWD+IFR2+MS+Sag (1) -402.44 3_MWD+IFR2+MS+Sag (1) -452.19 3_MWD+IFR2+MS+Sag (1) -500.54 3_MWD+IFR2+MS+Sag (1) -548.93 3_MWD+IFR2+MS+Sag (1) -596.95 3_MWD+IFR2+MS+Sag (1) -645.06 3_MWD+IFR2+MS+Sag (1) -692.56 3_MWD+IFR2+MS+Sag (1) -736.27 3_MWD+IFR2+MS+Sag (1) -774.46 3_MWD+IFR2+MS+Sag (1) -805.80 3_MWD+IFR2+MS+Sag (1) -830.05 3_MWD+IFR2+MS+Sag (1) -847.44 3_MWD+IFR2+MS+Sag (1) -859.24 3_MWD+IFR2+MS+Sag (1) -865.01 3_MWD+IFR2+MS+Sag (1) -863.82 3_MWD+IFR2+MS+Sag (1) -856.07 3_MWD+IFR2+MS+Sag (1) -842.44 3_MWD+IFR2+MS+Sag (1) -822.08 3_MWD+IFR2+MS+Sag (1) -795.84 3_MWD+IFR2+MS+Sag (1) -760.81 3_MWD+IFR2+MS+Sag (1) -718.35 3_MWD+IFR2+MS+Sag (1) -668.44 3_MWD+IFR2+MS+Sag (1) -613.89 3_MWD+IFR2+MS+Sag (1) -555.57 3_MWD+IFR2+MS+Sag (1) -494.31 3_MWD+IFR2+MS+Sag (1) -429.30 3_MWD+IFR2+MS+Sag (1) -361.71 3_MWD+IFR2+MS+Sag (1) -292.53 3_MWD+IFR2+MS+Sag (1) -219.33 3_MWD+IFR2+MS+Sag (1) -141.49 3_MWD+IFR2+MS+Sag (1) -59.31 3_MWD+IFR2+MS+Sag (1) 26.87 3_MWD+IFR2+MS+Sag (1) 117.00 3_MWD+IFR2+MS+Sag (1) 209.63 3_MWD+IFR2+MS+Sag (1) 301.21 3_MWD+IFR2+MS+Sag (1) 395.15 3_MWD+IFR2+MS+Sag (1) 444.25 3_MWD+IFR2+MS+Sag (1) COMPASS 5000.15 Build 91E Map +E/ -W Northing (usft) (ft) -143.88 6,028,154.32 -170.83 6,028,204.18 -198.96 6,028,256.16 -227.81 6,028,307.86 -257.50 6,028,359.67 -287.12 6,028,410.07 -317.54 6,028,460.56 -347.34 6,028,510.64 -376.42 6,028,560.77 -407.11 6,028,610.38 -441.07 6,028,656.42 -477.39 6,028,697.07 -514.94 6,028,730.94 -554.49 6,028,757.84 -596.06 6,028,777.99 -639.77 6,028,792.67 -685.03 6,028,801.42 -731.31 6,028,803.25 -775.77 6,028,798.39 -819.00 6,028,787.56 -863.91 6,028,770.08 -908.18 6,028,746.68 -953.25 6,028,714.52 -994.59 6,028,674.66 -1,034.15 6,028,627.23 -1,072.92 6,028,575.09 -1,112.64 6,028,519.23 576.12 -1,152.72 6,028,460.44 513.76 -1,192.87 6,028,397.91 448.83 -1,233.14 6,028,332.80 382.26 -1,272.94 6,028,266.06 311.71 -1,313.41 6,028,195.34 236.49 -1,353.51 6,028,119.94 156.58 -1,389.06 6,028,039.89 72.16 -1,417.03 6,027,955.34 -16.80 -1,437.04 6,027,866.31 -108.49 -1,453.75 6,027,774.55 -199.04 -1,471.55 6,027,683.93 -291.91 -1,490.17 6,027,590.98 -340.47 -1,499.68 6,027,542.39 Page 3 Map Easting DLS (ft) (°/100') 533,368.84 2.81 533,341.66 1.98 533,313.31 1.34 533,284.23 0.96 533,254.30 0.88 533,224.46 1.26 533,193.82 1.38 533,163.79 533,134.48 533,103.58 533,069.41 533,032.91 532,995.21 532,955.55 532,913.89 532,870.11 532,824.82 532,778.54 532,734.10 532,690.92 532,646.10 532,601.94 532,557.02 532,515.86 532,476.52 532,437.99 532,398.52 2.08 1.80 2.66 3.89 4.12 4.62 5.01 4.07 3.29 4.44 4.63 4.37 3.75 5.17 4.27 5.43 5.91 4.56 2.94 3.42 532,358.71 2.69 532,318.84 3.41 532,278.87 0.97 532,239.38 3.43 532,199.23 4.70 532,159.48 5.18 532,124.28 6.50 532,096.70 6.70 532,077.10 6.23 532,060.80 3.60 532,043.41 8.58 532,025.20 4.81 532,015.92 2.14 Vertical Section (ft) Survey Tool Name -254.74 3_MWD+IFR2+MS+Sag (1) -302.72 3_MWD+IFR2+MS+Sag (1) -352.75 3_MWD+IFR2+MS+Sag (1) -402.44 3_MWD+IFR2+MS+Sag (1) -452.19 3_MWD+IFR2+MS+Sag (1) -500.54 3_MWD+IFR2+MS+Sag (1) -548.93 3_MWD+IFR2+MS+Sag (1) -596.95 3_MWD+IFR2+MS+Sag (1) -645.06 3_MWD+IFR2+MS+Sag (1) -692.56 3_MWD+IFR2+MS+Sag (1) -736.27 3_MWD+IFR2+MS+Sag (1) -774.46 3_MWD+IFR2+MS+Sag (1) -805.80 3_MWD+IFR2+MS+Sag (1) -830.05 3_MWD+IFR2+MS+Sag (1) -847.44 3_MWD+IFR2+MS+Sag (1) -859.24 3_MWD+IFR2+MS+Sag (1) -865.01 3_MWD+IFR2+MS+Sag (1) -863.82 3_MWD+IFR2+MS+Sag (1) -856.07 3_MWD+IFR2+MS+Sag (1) -842.44 3_MWD+IFR2+MS+Sag (1) -822.08 3_MWD+IFR2+MS+Sag (1) -795.84 3_MWD+IFR2+MS+Sag (1) -760.81 3_MWD+IFR2+MS+Sag (1) -718.35 3_MWD+IFR2+MS+Sag (1) -668.44 3_MWD+IFR2+MS+Sag (1) -613.89 3_MWD+IFR2+MS+Sag (1) -555.57 3_MWD+IFR2+MS+Sag (1) -494.31 3_MWD+IFR2+MS+Sag (1) -429.30 3_MWD+IFR2+MS+Sag (1) -361.71 3_MWD+IFR2+MS+Sag (1) -292.53 3_MWD+IFR2+MS+Sag (1) -219.33 3_MWD+IFR2+MS+Sag (1) -141.49 3_MWD+IFR2+MS+Sag (1) -59.31 3_MWD+IFR2+MS+Sag (1) 26.87 3_MWD+IFR2+MS+Sag (1) 117.00 3_MWD+IFR2+MS+Sag (1) 209.63 3_MWD+IFR2+MS+Sag (1) 301.21 3_MWD+IFR2+MS+Sag (1) 395.15 3_MWD+IFR2+MS+Sag (1) 444.25 3_MWD+IFR2+MS+Sag (1) COMPASS 5000.15 Build 91E Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-24 Wellbore: MPU M -24P[32 Design: MPU M-24PB2 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU M-24 MPU M-24 Actual Lateral RKB @ 51.95usft MPU M-24 Actual Lateral RKB @ 51.95usft True Minimum Curvature NORTH US + CANADA Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,098.24 91.05 190.86 3,746.39 3,694.44 -435.05 -1,518.07 6,027,447.74 531,997.95 0.82 539.88 3_MWD+IFR2+MS+Sag (2) 5,161.82 90.25 190.30 3,745.67 3,693.72 -497.54 -1,529.75 6,027,385.20 531,986.56 1.54 603.04 3_MWD+IFR2+MS+Sag (2) 5,225.55 88.14 190.68 3,746.57 3,694.62 -560.20 -1,541.35 6,027,322.50 531,975.24 3.36 666.35 3_MWD+IFR2+MS+Sag (2) 5,288.72 85.18 190.02 3,750.25 3,698.30 -622.23 -1,552.68 6,027,260.43 531,964.19 4.80 729.02 3_MWD+IFR2+MS+Sag (2) 5,351.68 82.63 189.74 3,756.93 3,704.98 -683.90 -1,563.42 6,027,198.71 531,953.73 4.07 791.29 3_MWD+IFR2+MS+Sag (2) 5,415.74 82.20 190.09 3,765.39 3,713.44 -746.45 -1,574.35 6,027,136.12 531,943.08 0.86 854.45 3_MWD+IFR2+MS+Sag (2) 5,479.65 83.07 191.77 3,773.58 3,721.63 -808.68 -1,586.37 6,027,073.84 531,931.35 2.94 917.37 3_MWD+IFR2+MS+Sag (2) 5,542.95 83.38 192.74 3,781.05 3,729.10 -870.10 -1,599.71 6,027,012.36 531,918.28 1.60 979.57 3_MWD+IFR2+MS+Sag (2) 5,606.99 84.25 194.46 3,787.95 3,736.00 -931.98 -1,614.68 6,026,950.43 531,903.59 3.00 1,042.35 3_MWD+IFR2+MS+Sag (2) 5,670.43 85.06 193.91 3,793.86 3,741.91 -993.22 -1,630.16 6,026,889.12 531,888.39 1.54 1,104.51 3_MWD+IFR2+MS+Sag (2) 5,734.10 86.11 194.05 3,798.76 3,746.81 -1,054.82 -1,645.50 6,026,827.46 531,873.33 1.66 1,167.03 3_MWD+IFR2+MS+Sag (2) 5,797.78 86.61 193.37 3,802.80 3,750.85 -1,116.56 -1,660.56 6,026,765.66 531,858.55 1.32 1,229.67 3_MWD+IFR2+MS+Sag (2) 5,861.46 87.90 193.42 3,805.85 3,753.90 -1,178.43 -1,675.30 6,026,703.73 531,844.10 2.03 1,292.43 3_MWD+IFR2+MS+Sag (2) 5,924.54 89.45 192.59 3,807.31 3,755.36 -1,239.88 -1,689.49 6,026,642.23 531,830.18 2.79 1,354.71 3_MWD+IFR2+MS+Sag (2) 5,988.63 90.74 192.15 3,807.20 3,755.25 -1,302.48 -1,703.22 6,026,579.57 531,816.74 2.13 1,418.11 3_MWD+IFR2+MS+Sag (2) 6,051.90 91.73 190.67 3,805.84 3,753.89 -1,364.48 -1,715.73 6,026,517.52 531,804.51 2.81 1,480.84 3_MWD+IFR2+MS+Sag (2) 6,115.71 92.59 190.75 3,803.44 3,751.49 -1,427.13 -1,727.58 6,026,454.82 531,792.94 1.35 1,544.17 3_MWD+IFR2+MS+Sag (2) 6,179.00 93.89 190.63 3,799.86 3,747.91 -1,489.22 -1,739.30 6,026,392.68 531,781.50 2.06 1,606.92 3_MWD+IFR2+MS+Sag (2) 6,242.79 95.82 190.18 3,794.46 3,742.51 -1,551.74 -1,750.78 6,026,330.12 531,770.30 3.11 1,670.09 3_MWD+IFR2+MS+Sag (2) 6,307.32 96.93 189.60 3,787.30 3,735.35 -1,614.91 -1,761.79 6,026,266.90 531,759.57 1.94 1,733.88 3_MWD+IFR2+MS+Sag (2) 6,370.72 97.80 188.70 3,779.17 3,727.22 -1,676.99 -1,771.79 6,026,204.79 531,749.86 1.97 1,796.50 3_MWD+IFR2+MS+Sag (2) 6,434.43 98.67 187.35 3,770.04 3,718.09 -1,739.42 -1,780.60 6,026,142.32 531,741.34 2.50 1,859.39 3_MWD+IFR2+MS+Sag (2) 6,498.18 99.60 186.87 3,759.92 3,707.97 -1,801.88 -1,788.39 6,026,079.84 531,733.83 1.64 1,922.24 3_MWD+IFR2+MS+Sag (2) 6,561.46 99.98 185.34 3,749.16 3,697.21 -1,863.88 -1,795.02 6,026,017.81 531,727.48 2.46 1,984.56 3_MWD+IFR2+MS+Sag (2) 6,624.98 98.36 183.51 3,739.04 3,687.09 -1,926.40 -1,799.85 6,025,955.28 531,722.92 3.82 2,047.26 3_MWD+IFR2+MS+Sag (2) 6,688.77 96.11 182.22 3,731.00 3,679.05 -1,989.60 -1,803.02 6,025,892.08 531,720.05 4.06 2,110.52 3_MWD+IFR2+MS+Sag (2) 6,752.56 93.27 180.65 3,725.79 3,673.84 -2,053.14 -1,804.61 6,025,828.53 531,718.74 5.08 2,174.03 3_MWD+IFR2+MS+Sag (2) 6,815.85 91.29 180.94 3,723.27 3,671.32 -2,116.37 -1,805.48 6,025,765.30 531,718.15 3.16 2,237.16 3_MWD+IFR2+MS+Sag (2) 6,879.63 90.92 181.49 3,722.04 3,670.09 -2,180.13 -1,806.84 6,025,701.55 531,717.08 1.04 2,300.86 3_MWD+IFR2+MS+Sag (2) 6,942.51 93.22 184.09 3,719.77 3,667.82 -2,242.88 -1,809.89 6,025,638.79 531,714.31 5.52 2,363.67 3_MWD+IFR2+MS+Sag (2) 7,005.99 92.90 184.21 3,716.38 3,664.43 -2,306.11 -1,814.48 6,025,575.55 531,710.01 0.54 2,427.06 3_MWD+IFR2+MS+Sag (2) 7,069.43 92.59 184.02 3,713.34 3,661.39 -2,369.31 -1,819.03 6,025,512.33 531,705.75 0.57 2,490.43 3_MWD+IFR2+MS+Sag (2) 7,132.61 92.90 183.69 3,710.32 3,658.37 -2,432.27 -1,823.27 6,025,449.35 531,701.79 0.72 2,553.53 3_MWD+IFR2+MS+Sag (2) 7,196.28 93.83 183.92 3,706.58 3,654.63 -2,495.69 -1,827.49 6,025,385.92 531,697.86 1.50 2,617.09 3_MWD+IFR2+MS+Sag (2) 7,260.09 94.58 184.15 3,701.90 3,649.95 -2,559.17 -1,831.97 6,025,322.43 531,693.67 1.23 2,680.73 3_MWD+IFR2+MS+Sag (2) 7,323.22 93.08 184.24 3,697.68 3,645.73 -2,621.99 -1,836.57 6,025,259.60 531,689.34 2.38 2,743.72 3_MWD+IFR2+MS+Sag (2) 7,386.60 92.34 185.02 3,694.69 3,642.74 -2,685.09 -1,841.68 6,025,196.48 531,684.52 1.70 2,807.02 3_MWD+IFR2+MS+Sag (2) 7,450.27 94.27 186.71 3,691.02 3,639.07 -2,748.32 -1,848.18 6,025,133.23 531,678.31 4.03 2,870.55 3_MWD+IFR2+MS+Sag (2) 7,513.89 94.01 186.82 3,686.42 3,634.47 -2,811.33 -1,855.65 6,025,070.19 531,671.12 0.44 2,933.93 3_MWD+IFR2+MS+Sag (2) 7,577.97 94.58 185.85 3,681.62 3,629.67 -2,874.84 -1,862.70 6,025,006.66 531,664.35 1.75 2,997.77 3_MWD+IFR2+MS+Sag (2) 1/2212020 12:53:47PM Page 4 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-24 Project: Milne Point TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Site: M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Well: MPU M-24 North Reference: True Wellbore: MPU M-24PB2 Survey Calculation Method: Minimum Curvature Design: MPU M -24P132 Database: NORTH US + CANADA S u rvey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,641.71 93.27 184.80 3,677.26 3,625.31 -2,938.15 -1,868.60 6,024,943.33 531,658.74 2.63 3,061.34 3_MWD+IFR2+MS+Sag (2) 7,705.41 91.79 185.44 3,674.45 3,622.50 -3,001.54 -1,874.28 6,024,879.92 531,653.35 2.53 3,124.97 3_MWD+IFR2+MS+Sag (2) 7,767.25 89.81 184.92 3,673.59 3,621.64 -3,063.11 -1,879.87 6,024,818.33 531,648.04 3.31 3,186.79 3_MWD+IFR2+MS+Sag (2) 7,831.58 88.58 184.22 3,674.49 3,622.54 -3,127.23 -1,884.99 6,024,754.19 531,643.20 2.20 3,251.10 3_MWD+IFR2+MS+Sag (2) 7,896.23 88.52 184.26 3,676.13 3,624.18 -3,191.68 -1,889.77 6,024,689.73 531,638.72 0.11 3,315.73 3_MWD+IFR2+MS+Sag (2) 7,959.80 89.14 183.53 3,677.42 3,625.47 -3,255.09 -1,894.09 6,024,626.31 531,634.69 1.51 3,379.29 3_MWD+IFR2+MS+Sag (2) 8,023.51 88.83 183.38 3,678.55 3,626.60 -3,318.68 -1,897.93 6,024,562.71 531,631.13 0.54 3,442.99 3_MWD+IFR2+MS+Sag (2) 8,087.32 88.76 182.91 3,679.89 3,627.94 -3,382.38 -1,901.43 6,024,499.00 531,627.92 0.74 3,506.78 3_MWD+IFR2+MS+Sag (2) 8,150.63 90.37 182.42 3,680.37 3,628.42 -3,445.62 -1,904.37 6,024,435.76 531,625.26 2.66 3,570.06 3_MWD+IFR2+MS+Sag (2) 8,214.38 91.61 182.48 3,679.27 3,627.32 -3,509.30 -1,907.09 6,024,372.07 531,622.83 1.95 3,633.78 3_MWD+IFR2+MS+Sag (2) 8,277.62 92.90 183.00 3,676.78 3,624.83 -3,572.41 -1,910.11 6,024,308.95 531,620.09 2.20 3,696.95 3_MWD+IFR2+MS+Sag (2) 8,341.18 93.65 183.22 3,673.15 3,621.20 -3,635.78 -1,913.56 6,024,245.58 531,616.93 1.23 3,760.40 3_MWD+IFR2+MS+Sag (2) 8,405.09 93.82 183.67 3,668.99 3,617.04 -3,699.43 -1,917.39 6,024,181.91 531,613.39 0.75 3,824.17 3_MWD+IFR2+MS+Sag (2) 8,468.68 94.20 183.67 3,664.54 3,612.59 -3,762.74 -1,921.45 6,024,118.59 531,609.61 0.60 3,887.61 3_MWD+IFR2+MS+Sag (2) 8,532.91 94.88 183.82 3,659.46 3,607.51 -3,826.63 -1,925.63 6,024,054.69 531,605.72 1.08 3,951.63 3_MWD+IFR2+MS+Sag (2) 8,596.43 95.82 184.62 3,653.54 3,601.59 -3,889.70 -1,930.29 6,023,991.61 531,601.35 1.94 4,014.88 3_MWD+IFR2+MS+Sag (2) 8,660.24 93.88 184.09 3,648.14 3,596.19 -3,953.10 -1,935.11 6,023,928.20 531,596.81 3.15 4,078.45 3_MWD+IFR2+MS+Sag (2) 8,724.00 92.40 183.77 3,644.65 3,592.70 -4,016.61 -1,939.48 6,023,864.67 531,592.73 2.37 4,142.11 3_MWD+IFR2+MS+Sag (2) 8,787.46 92.77 183.96 3,641.79 3,589.84 -4,079.86 -1,943.75 6,023,801.41 531,588.75 0.66 4,205.51 3_MWD+IFR2+MS+Sag (2) 8,850.79 93.58 184.54 3,638.28 3,586.33 -4,142.92 -1,948.43 6,023,738.33 531,584.34 1.57 4,268.74 3_MWD+IFR2+MS+Sag (2) 8,913.58 94.63 185.25 3,633.79 3,581.84 -4,205.32 -1,953.78 6,023,675.92 531,579.28 2.02 4,331.36 3_MWD+IFR2+MS+Sag (2) 8,977.43 96.07 185.06 3,627.83 3,575.88 -4,268.63 -1,959.49 6,023,612.59 531,573.86 2.27 4,394.92 3_MWD+IFR2+MS+Sag (2) 9,041.86 96.31 185.10 3,620.88 3,568.93 -4,332.43 -1,965.16 6,023,548.76 531,568.47 0.38 4,458.96 3_MWD+IFR2+MS+Sag (2) 9,105.28 95.56 184.83 3,614.33 3,562.38 -4,395.27 -1,970.62 6,023,485.90 531,563.30 1.26 4,522.03 3_MWD+IFR2+MS+Sag (2) 9,169.48 93.70 184.19 3,609.15 3,557.20 -4,459.06 -1,975.65 6,023,422.10 531,558.55 3.06 4,586.02 3_MWD+IFR2+MS+Sag (2) 9,233.22 91.35 183.99 3,606.34 3,554.39 -4,522.58 -1,980.19 6,023,358.57 531,554.30 3.70 4,649.69 3_MWD+IFR2+MS+Sag (2) 9,295.75 90.36 183.67 3,605.40 3,553.45 -4,584.96 -1,984.37 6,023,296.18 531,550.41 1.66 4,712.21 3_MWD+IFR2+MS+Sag (2) 9,360.07 92.04 184.37 3,604.06 3,552.11 -4,649.10 -1,988.88 6,023,232.02 531,546.19 2.83 4,776.52 3_MWD+IFR2+MS+Sag (2) 9,423.90 93.52 185.94 3,600.96 3,549.01 -4,712.60 -1,994.61 6,023,168.51 531,540.75 3.38 4,840.25 3_MWD+IFR2+MS+Sag (2) 9,487.23 94.64 185.64 3,596.46 3,544.51 -4,775.44 -2,000.98 6,023,105.64 531,534.66 1.83 4,903.39 3_MWD+IFR2+MS+Sag (2) 9,551.01 96.01 185.64 3,590.54 3,538.59 -4,838.64 -2,007.22 6,023,042.42 531,528.70 2.15 4,966.87 3_MWD+IFR2+MS+Sag (2) 9,614.61 96.05 185.13 3,583.86 3,531.91 -4,901.61 -2,013.15 6,022,979.44 531,523.05 0.80 5,030.10 3_MWD+IFR2+MS+Sag (2) 9,677.28 97.30 185.55 3,576.57 3,524.62 -4,963.58 -2,018.95 6,022,917.44 531,517.54 2.10 5,092.32 3_MWD+IFR2+MS+Sag (2) 9,729.96 98.80 185.24 3,569.19 3,517.24 -5,015.51 -2,023.85 6,022,865.50 531,512.87 2.91 5,144.47 3_MWD+IFR2+MS+Sag (2) 9,810.00 98.80 185.24 3,556.95 3,505.00 -5,094.28 -2,031.08 6,022,786.71 531,506.00 0.00 5,223.55 PROJECTED to TD Checked By: Chelsea Wright D.t-'o,00;.22054:-900•"` Approved By: Benjamin Hand Date:202 01.22;413:11-0900'Date: 01-22-2020 1/22/2020 12:53:47PM Page 5 COMPASS 5000.15 Build 91E Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-24PB3 500292365772 Sperry Drilling Definitive Survey Report 22 January, 2020 HALLIBURTON Sperry [drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-24 Project: Milne Point TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Site: M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Well: MPU M-24 North Reference: True Wellbore: MPU M-24PB3 Survey Calculation Method: Minimum Curvature Design: MPU M-24PB3 Database: NORTH US + CANADA 'roject Milne Point, ACT, MILNE POINT lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level neo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU M-24, Slot 16 Well Position +Nl-S 0.00 usft Northing: 6,027,889.58 usfi Latitude: 70° 29' 14.016 N +El -W 0.00 usft Easting: 533,513.90 usfi Longitude: 149° 43'33.871 W Position Uncertainty 0.50 usft Wellhead Elevation: 0.00 usfi Ground Level: 25.30 usft Wellbore MPU M-24PB3 Magnetics Model Name Sample Date BGGM2019 1/16/2020 Design MPU M-24PB3 Audit Notes: Version: 1.0 Phase: Vertical Section: Depth From (TVD) (usft) 26.65 Declination Dip Angle Field Strength (°) (°) (nT) 16.17 80.90 57,401.70205395 ACTUAL +N/ -S (usft) 0.00 Tie On Depth +El -W (usft) 0.00 9,295.75 Direction (°) 184.00 Survey Program Date 1/20/2020 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 206.41 5,001.86 MPU M-24PB1 SH MWD+IFR2+MS+Sac 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 11/27/2019 5,098.24 9,295.75 MPU M-24PB2 PH MWD+IFR2+MS+Sac 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 01/13/2020 9,325.00 14,320.03 MPU M-24PB3 MWD+IFR2+MS+Sag (4) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 01/16/2020 Survey 1/222020 12:55:10PM Page 2 COMPASS 5000.15 Build 91E Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 26.65 0.00 0.00 26.65 -25.30 0.00 0.00 6,027,889.58 533,513.90 0.00 0.00 UNDEFINED 206.41 0.14 4.54 206.41 154.46 0.22 0.02 6,027,889.80 533,513.92 0.08 -0.22 3_MWD+IFR2+MS+Sag (1) 298.47 0.16 23.95 298.47 246.52 0.45 0.08 6,027,890.03 533,513.98 0.06 -0.45 3_MWD+IFR2+MS+Sag (1) 389.89 1.56 340.07 389.88 337.93 1.74 -0.29 6,027,891.31 533,513.60 1.58 -1.71 3_MWD+IFR2+MS+Sag (1) 485.26 3.85 333.95 485.13 433.18 5.83 -2.14 6,027,895.40 533,511.73 2.42 -5.67 3_MWD+IFR2+MS+Sag (1) 577.83 7.76 331.13 577.21 525.26 14.10 -6.53 6,027,903.65 533,507.31 4.23 -13.61 3_MWD+IFR2+MS+Sag (1) 671.15 10.75 328.35 669.31 617.36 27.03 -14.14 6,027,916.54 533,499.64 3.24 -25.98 3_MWD+IFR2+MS+Sag (1) 766.59 13.99 329.76 762.52 710.57 44.58 -24.62 6,027,934.04 533,489.08 3.41 -42.75 3_MWD+IFR2+MS+Sag (1) 861.85 19.14 329.56 853.80 801.85 68.01 -38.34 6,027,957.41 533,475.26 5.41 -65.17 3_MWD+IFR2+MS+Sag (1) 957.40 23.41 329.78 942.81 890.86 97.93 -55.84 6,027,987.24 533,457.63 4.47 -93.79 3_MWD+IFR2+MS+Sag (1) 1,052.12 26.82 332.20 1,028.57 976.62 133.10 -75.28 6,028,022.33 533,438.03 3.76 -127.52 3_MWD+IFR2+MS+Sag (1) 1,147.38 30.03 332.80 1,112.33 1,060.38 173.32 -96.21 6,028,062.45 533,416.92 3.38 -166.19 3_MWD+IFR2+MS+Sag (1) 1/222020 12:55:10PM Page 2 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU NI -24 Project: Milne Point TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Site: M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Well: MPU M-24 North Reference: True Wellbore: MPU M-24PB3 Survey Calculation Method: Minimum Curvature Design: MPU M-24PB3 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,242.27 33.26 333.11 1,193.10 1,141.15 217.66 -118.83 6,028,106.68 533,394.10 3.41 -208.84 3_MWD+IFR2+MS+Sag (1) 1,337.44 35.79 331.60 1,271.51 1,219.56 265.42 -143.88 6,028,154.32 533,368.84 2.81 -254.74 3_MWD+IFR2+MS+Sag (1) 1,432.40 37.67 331.72 1,347.61 1,295.66 315.40 -170.83 6,028,204.18 533,341.66 1.98 -302.72 3_MWD+IFR2+MS+Sag (1) 1,527.93 38.95 331.58 1,422.57 1,370.62 367.52 -198.96 6,028,256.16 533,313.31 1.34 -352.75 3_MWD+IFR2+MS+Sag (1) 1,622.02 39.22 330.22 1,495.60 1,443.65 419.35 -227.81 6,028,307.86 533,284.23 0.96 -402.44 3_MWD+IFR2+MS+Sag (1) 1,717.52 38.38 330.27 1,570.03 1,518.08 471.30 -257.50 6,028,359.67 533,254.30 0.88 -452.19 3_MWD+IFR2+MS+Sag (1) 1,812.81 37.49 328.97 1,645.19 1,593,24 521.84 -287.12 6,028,410.07 533,224.46 1.26 -500.54 3_MWD+IFR2+MS+Sag (1) 1,908.44 38.81 329.05 1,720.39 1,668.44 572.48 -317.54 6,028,460.56 533,193.82 1.38 -548.93 3_MWD+IFR2+MS+Sag (1) 2,003.65 36.86 329.59 1,795.58 1,743.63 622.70 -347.34 6,028,510.64 533,163.79 2.08 -596.95 3_MWD+IFR2+MS+Sag (1) 2,098.63 38.52 330.28 1,870.74 1,818.79 672.96 -376.42 6,028,560.77 533,134.48 1.80 -645.06 3_MWD+IFR2+MS+Sag (1) 2,193.29 37.80 326.37 1,945.18 1,893.23 722.72 -407.11 6,028,610.38 533,103.58 2.66 -692.56 3_MWD+IFR2+MS+Sag (1) 2,288.76 36.10 320.87 2,021.49 1,969.54 768.91 -441.07 6,028,656.42 533,069.41 3.89 -736.27 3_MWD+IFR2+MS+Sag (1) 2,384.56 33.52 315.64 2,100.16 2,048.21 809.73 -477.39 6,028,697.07 533,032.91 4.12 -774.46 3_MWD+IFR2+MS+Sag (1) 2,479.18 31.37 308.54 2,180.03 2,128.08 843.77 -514.94 6,028,730.94 532,995.21 4.62 -805.80 3_MWD+IFR2+MS+Sag (1) 2,574.22 29.36 300.00 2,262.07 2,210.12 870.85 -554.49 6,028,757.84 532,955.55 5.01 -830.05 3_MWD+IFR2+MS+Sag (1) 2,669.58 28.84 292.08 2,345.43 2,293.48 891.19 -596.06 6,028,777.99 532,913.89 4.07 -847.44 3_MWD+IFR2+MS+Sag (1) 2,765.64 28.71 285.51 2,429.65 2,377.70 906.07 -639.77 6,028,792.67 532,870.11 3.29 -859.24 3_MWD+IFR2+MS+Sag (1) 2,860.70 29.50 276.97 2,512.74 2,460.79 915.02 -685.03 6,028,801.42 532,824.82 4.44 -865.01 3_MWD+IFR2+MS+Sag (1) 2,955.75 29.00 268.01 2,595.71 2,543.76 917.06 -731.31 6,028,803.25 532,778.54 4.63 -863.82 3_MWD+IFR2+MS+Sag (1) 3,050.34 27.55 259.84 2,679.04 2,627.09 912.41 -775.77 6,028,798.39 532,734.10 4.37 -856.07 3_MWD+IFR2+MS+Sag (1) 3,145.08 28.61 252.64 2,762.65 2,710.70 901.77 -819.00 6,028,787.56 532,690.92 3.75 -842.44 3_MWD+IFR2+MS+Sag (1) 3,240.52 32.05 245.63 2,845.04 2,793.09 884.49 -863.91 6,028,770.08 532,646.10 5.17 -822.08 3_MWD+IFR2+MS+Sag (1) 3,332.54 33.85 239.21 2,922.28 2,870.33 861.29 -908.18 6,028,746.68 532,601.94 4.27 -795.84 3_MWD+IFR2+MS+Sag (1) 3,430.07 35.36 230.26 3,002.61 2,950.66 829.32 -953.25 6,028,714.52 532,557.02 5.43 -760.81 3_MWD+IFR2+MS+Sag (1) 3,525.67 38.45 222.38 3,079.09 3,027.14 789.65 -994.59 6,028,674.66 532,515.86 5.91 -718.35 3_MWD+IFR2+MS+Sag (1) 3,621.58 41.59 217.64 3,152.55 3,100.60 742.39 -1,034.15 6,028,627.23 532,476.52 4.56 -668.44 3_MWD+IFR2+MS+Sag (1) 3,716.93 44.12 215.85 3,222.44 3,170.49 690.42 -1,072.92 6,028,575.09 532,437.99 2.94 -613.89 3_MWD+IFR2+MS+Sag (1) 3,812.46 47.35 215.17 3,289.11 3,237.16 634.73 -1,112.64 6,028,519.23 532,398.52 3.42 -555.57 3_MWD+IFR2+MS+Sag (1) 3,907.31 49.61 213.59 3,351.98 3,300.03 576.12 -1,152.72 6,028,460.44 532,358.71 2.69 -494.31 3_MWD+IFR2+MS+Sag (1) 4,002.61 52.61 212.00 3,411.81 3,359.86 513.76 -1,192.87 6,028,397.91 532,318.84 3.41 -429.30 3_MWD+IFR2+MS+Sag (1) 4,098.23 53.48 211.61 3,469.30 3,417.35 448.83 -1,233.14 6,028,332.80 532,278.87 0.97 -361.71 3_MWD+IFR2+MS+Sag (1) 4,192.94 56.50 210.16 3,523.63 3,471.68 382.26 -1,272.94 6,028,266.06 532,239.38 3.43 -292.53 3_MWD+IFR2+MS+Sag (1) 4,288.13 60.94 209.54 3,573.04 3,521.09 311.71 -1,313.41 6,028,195.34 532,199.23 4.70 -219.33 3_MWD+IFR2+MS+Sag (1) 4,383.79 65.16 206.63 3,616.39 3,564.44 236.49 -1,353.51 6,028,119.94 532,159.48 5.18 -141.49 3_MWD+IFR2+MS+Sag (1) 4,478.79 69.04 201.42 3,653.37 3,601.42 156.58 -1,389.06 6,028,039.89 532,124.28 6.50 -59.31 3_MWD+IFR2+MS+Sag (1) 4,573.30 71.64 195.29 3,685.20 3,633.25 72.16 -1,417.03 6,027,955.34 532,096.70 6.70 26.87 3_MWD+IFR2+MS+Sag (1) 4,668.56 74.89 190.10 3,712.64 3,660.69 -16.80 -1,437.04 6,027,866.31 532,077.10 6.23 117.00 3_MWD+IFR2+MS+Sag (1) 4,764.38 78.31 190.56 3,734.84 3,682.89 -108.49 -1,453.75 6,027,774.55 532,060.80 3.60 209.63 3_MWD+IFR2+MS+Sag (1) 4,857.59 86.23 191.67 3,747.37 3,695.42 -199.04 -1,471.55 6,027,683.93 532,043.41 8.58 301.21 3_MWD+IFR2+MS+Sag (1) 4,952.37 90.74 191.01 3,749.87 3,697.92 -291.91 -1,490.17 6,027,590.98 532,025.20 4.81 395.15 3_MWD+IFR2+MS+Sag (1) 1/22/2020 12:55:10PM Page 3 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU NL24 Project: Milne Point TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Site: M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Well: MPU M-24 North Reference: True Wellbore: MPU M-24PB3 Survey Calculation Method: Minimum Curvature Design: MPU M-24PB3 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,001.86 91.79 191.15 3,748.78 3,696.83 -340.47 -1,499.68 6,027,542.39 532,015.92 2.14 444.25 3_MWD+IFR2+MS+Sag (1) 5,098.24 91.05 190.86 3,746.39 3,694.44 -435.05 -1,518.07 6,027,447.74 531,997.95 0.82 539.88 3_MWD+IFR2+MS+Sag (2) 5,161.82 90.25 190.30 3,745.67 3,693.72 -497.54 -1,529.75 6,027,385.20 531,986.56 1.54 603.04 3_MWD+IFR2+MS+Sag (2) 5,225.55 88.14 190.68 3,746.57 3,694.62 -560.20 -1,541.35 6,027,322.50 531,975.24 3.36 666.35 3_MWD+IFR2+MS+Sag (2) 5,288.72 85.18 190.02 3,750.25 3,698.30 -622.23 -1,552.68 6,027,260.43 531,964.19 4.80 729.02 3_MWD+IFR2+MS+Sag (2) 5,351.68 82.63 189.74 3,756.93 3,704.98 -683.90 -1,563.42 6,027,198.71 531,953.73 4.07 791.29 3_MWD+IFR2+MS+Sag (2) 5,415.74 82.20 190.09 3,765.39 3,713.44 -746.45 -1,574.35 6,027,136.12 531,943.08 0.86 854.45 3_MWD+IFR2+MS+Sag (2) 5,479.65 83.07 191.77 3,773.58 3,721.63 -808.68 -1,586.37 6,027,073.84 531,931.35 2.94 917.37 3_MWD+IFR2+MS+Sag (2) 5,542.95 83.38 192.74 3,781.05 3,729.10 -870.10 -1,599.71 6,027,012.36 531,918.28 1.60 979.57 3_MWD+IFR2+MS+Sag (2) 5,606.99 84.25 194.46 3,787.95 3,736.00 -931.98 -1,614.68 6,026,950.43 531,903.59 3.00 1,042.35 3_MWD+IFR2+MS+Sag (2) 5,670.43 85.06 193.91 3,793.86 3,741.91 -993.22 -1,630.16 6,026,889.12 531,888.39 1.54 1,104.51 3_MWD+IFR2+MS+Sag (2) 5,734.10 86.11 194.05 3,798.76 3,746.81 -1,054.82 -1,645.50 6,026,827.46 531,873.33 1.66 1,167.03 3_MWD+IFR2+MS+Sag (2) 5,797.78 86.61 193.37 3,802.80 3,750.85 -1,116.56 -1,660.56 6,026,765.66 531,858.55 1.32 1,229.67 3_MWD+IFR2+MS+Sag (2) 5,861.46 87.90 193.42 3,805.85 3,753.90 -1,178.43 -1,675.30 6,026,703.73 531,844.10 2.03 1,292.43 3_MWD+IFR2+MS+Sag (2) 5,924.54 89.45 192.59 3,807.31 3,755.36 -1,239.88 -1,689.49 6,026,642.23 531,830.18 2.79 1,354.71 3_MWD+IFR2+MS+Sag (2) 5,988.63 90.74 192.15 3,807.20 3,755.25 -1,302.48 -1,703.22 6,026,579.57 531,816.74 2.13 1,418.11 3_MWD+IFR2+MS+Sag (2) 6,051.90 91.73 190.67 3,805.84 3,753.89 -1,364.48 -1,715.73 6,026,517.52 531,804.51 2.81 1,480.84 3_MWD+IFR2+MS+Sag (2) 6,115.71 92.59 190.75 3,803.44 3,751.49 -1,427.13 -1,727.58 6,026,454.82 531,792.94 1.35 1,544.17 3_MWD+IFR2+MS+Sag (2) 6,179.00 93.89 190.63 3,799.86 3,747.91 -1,489.22 -1,739.30 6,026,392.68 531,781.50 2.06 1,606.92 3_MWD+IFR2+MS+Sag (2) 6,242.79 95.82 190.18 3,794.46 3,742.51 -1,551.74 -1,750.78 6,026,330.12 531,770.30 3.11 1,670.09 3_MWD+IFR2+MS+Sag (2) 6,307.32 96.93 189.60 3,787.30 3,735.35 -1,614.91 -1,761.79 6,026,266.90 531,759.57 1.94 1,733.88 3_MWD+IFR2+MS+Sag (2) 6,370.72 97.80 188.70 3,779.17 3,727.22 -1,676.99 -1,771.79 6,026,204.79 531,749.86 1.97 1,796.50 3_MWD+IFR2+MS+Sag (2) 6,434.43 98.67 187.35 3,770.04 3,718.09 -1,739.42 -1,780.60 6,026,142.32 531,741.34 2.50 1,859.39 3_MWD+IFR2+MS+Sag (2) 6,498.18 99.60 186.87 3,759.92 3,707.97 -1,801.88 -1,788.39 6,026,079.84 531,733.83 1.64 1,922.24 3_MWD+IFR2+MS+Sag (2) 6,561.46 99.98 185.34 3,749.16 3,697.21 -1,863.88 -1,795.02 6,026,017.81 531,727.48 2.46 1,984.56 3_MWD+IFR2+MS+Sag (2) 6,624.98 98.36 183.51 3,739.04 3,687.09 -1,926.40 -1,799.85 6,025,955.28 531,722.92 3.82 2,047.26 3_MWD+IFR2+MS+Sag (2) 6,688.77 96.11 182.22 3,731.00 3,679.05 -1,989.60 -1,803.02 6,025,892.08 531,720.05 4.06 2,110.52 3_MWD+IFR2+MS+Sag (2) 6,752.56 93.27 180.65 3,725.79 3,673.84 -2,053.14 -1,804.61 6,025,828.53 531,718.74 5.08 2,174.03 3_MWD+IFR2+MS+Sag (2) 6,815.85 91.29 180.94 3,723.27 3,671.32 -2,116.37 -1,805.48 6,025,765.30 531,718.15 3.16 2,237.16 3_MWD+IFR2+MS+Sag (2) 6,879.63 90.92 181.49 3,722.04 3,670.09 -2,180.13 -1,806.84 6,025,701.55 531,717.08 1.04 2,300.86 3_MWD+IFR2+MS+Sag (2) 6,942.51 93.22 184.09 3,719.77 3,667.82 -2,242.88 -1,809.89 6,025,638.79 531,714.31 5.52 2,363.67 3_MWD+IFR2+MS+Sag (2) 7,005.99 92.90 184.21 3,716.38 3,664.43 -2,306.11 -1,814.48 6,025,575.55 531,710.01 0.54 2,427.06 3_MWD+IFR2+MS+Sag (2) 7,069.43 92.59 184.02 3,713.34 3,661.39 -2,369.31 -1,819.03 6,025,512.33 531,705.75 0.57 2,490.43 3_MWD+IFR2+MS+Sag (2) 7,132.61 92.90 183.69 3,710.32 3,658.37 -2,432.27 -1,823.27 6,025,449.35 531,701.79 0.72 2,553.53 3_MWD+IFR2+MS+Sag (2) 7,196.28 93.83 183.92 3,706.58 3,654.63 -2,495.69 -1,827.49 6,025,385.92 531,697.86 1.50 2,617.09 3_MWD+IFR2+MS+Sag (2) 7,260.09 94.58 184.15 3,701.90 3,649.95 -2,559.17 -1,831.97 6,025,322.43 531,693.67 1.23 2,680.73 3_MWD+IFR2+MS+Sag (2) 7,323.22 93.08 184.24 3,697.68 3,645.73 -2,621.99 -1,836.57 6,025,259.60 531,689.34 2.38 2,743.72 3_MWD+IFR2+MS+Sag (2) 7,386.60 92.34 185.02 3,694.69 3,642.74 -2,685.09 -1,841.68 6,025,196.48 531,684.52 1.70 2,807.02 3_MWD+IFR2+MS+Sag (2) 7,450.27 94.27 186.71 3,691.02 3,639.07 -2,748.32 -1,848.18 6,025,133.23 531,678.31 4.03 2,870.55 3_MWD+IFR2+MS+Sag (2) 7,513.89 94.01 186.82 3,686.42 3,634.47 -2,811.33 -1,855.65 6,025,070.19 531,671.12 0.44 2,933.93 3_MWD+IFR2+MS+Sag (2) 11221202012:55:10PM Page 4 COMPASS 5000.15 Build 91E Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-24 Wellbore: MPU M-24PB3 Design: MPU M-24PB3 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU M-24 MPU M-24 Actual Lateral RKB @ 51.95usft MPU M-24 Actual Lateral RKB @ 51.95usft True Minimum Curvature NORTH US + CANADA Vertical Section (ft) Survey Tool Name 2,997.77 3_MWD+IFR2+MS+Sag (2) 3,061.34 3_MWD+IFR2+MS+Sag (2) 3,124.97 3_MWD+IFR2+MS+Sag (2) 3,186.79 3_MWD+IFR2+MS+Sag (2) 3,251.10 3_MWD+IFR2+MS+Sag (2) 3,315.73 3_MWD+IFR2+MS+Sag (2) 3,379.29 3_MWD+IFR2+MS+Sag (2) 3,442.99 3_MWD+IFR2+MS+Sag (2) 3,506.78 3_MWD+IFR2+MS+Sag (2) 3,570.06 3_MWD+IFR2+MS+Sag (2) 3,633.78 3_MWD+IFR2+MS+Sag (2) 3,696.95 3_MWD+IFR2+MS+Sag (2) 3,760.40 3_MWD+IFR2+MS+Sag (2) 3,824.17 3_MWD+IFR2+MS+Sag (2) 3,887.61 3_MWD+IFR2+MS+Sag (2) 3,951.63 3_MWD+IFR2+MS+Sag (2) 4,014.88 3_MWD+IFR2+MS+Sag (2) 4,078.45 3_MWD+IFR2+MS+Sag (2) 4,142.11 3_MWD+IFR2+MS+Sag (2) 4,205.51 3_MWD+IFR2+MS+Sag (2) 4,268.74 3_MWD+IFR2+MS+Sag (2) 4,331.36 3_MWD+IFR2+MS+Sag (2) 4,394.92 3_MWD+IFR2+MS+Sag (2) 4,458.96 3_MWD+IFR2+MS+Sag (2) 4,522.03 3_MWD+IFR2+MS+Sag (2) 4,586.02 3_MWD+IFR2+MS+Sag (2) 4,649.69 3_MWD+IFR2+MS+Sag (2) 4,712.21 3_MWD+IFR2+MS+Sag (2) 4,741.46 3_MWD+IFR2+MS+Sag (3) 4,775.29 3_MWD+IFR2+MS+Sag (3) 4,839.22 3_MWD+IFR2+MS+Sag (3) 4,902.32 3_MWD+IFR2+MS+Sag (3) 4,965.78 3_MWD+IFR2+MS+Sag (3) 5,029.23 3_MWD+IFR2+MS+Sag (3) 5,092.89 3_MWD+IFR2+MS+Sag (3) 5,156.17 3_MWD+IFR2+MS+Sag (3) 5,219.20 3_MWD+IFR2+MS+Sag (3) 5,282.39 3_MWD+IFR2+MS+Sag (3) 5,345.67 3_MWD+IFR2+MS+Sag (3) 5,409.08 3_MWD+IFR2+MS+Sag (3) 1/22/2020 12:55:10PM Page 5 COMPASS 5000.15 Build 91E Map Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') 7,577.97 94.58 185.85 3,681.62 3,629.67 -2,874.84 -1,862.70 6,025,006.66 531,664.35 1.75 7,641.71 93.27 184.80 3,677.26 3,625.31 -2,938.15 -1,868.60 6,024,943.33 531,658.74 2.63 7,705.41 91.79 185.44 3,674.45 3,622.50 -3,001.54 -1,874.28 6,024,879.92 531,653.35 2.53 7,767.25 89.81 184.92 3,673.59 3,621.64 -3,063.11 -1,879.87 6,024,818.33 531,648.04 3.31 7,831.58 88.58 184.22 3,674.49 3,622.54 -3,127.23 -1,884.99 6,024,754.19 531,643.20 2.20 7,896.23 88.52 184.26 3,676.13 3,624.18 -3,191.68 -1,889.77 6,024,689.73 531,638.72 0.11 7,959.80 89.14 183.53 3,677.42 3,625.47 -3,255.09 -1,894.09 6,024,626.31 531,634.69 1.51 8,023.51 88.83 183.38 3,678.55 3,626.60 -3,318.68 -1,897.93 6,024,562.71 531,631.13 0.54 8,087.32 88.76 182.91 3,679.89 3,627.94 -3,382.38 -1,901.43 6,024,499.00 531,627.92 0.74 8,150.63 90.37 182.42 3,680.37 3,628.42 -3,445.62 -1,904.37 6,024,435.76 531,625.26 2.66 8,214.38 91.61 182.48 3,679.27 3,627.32 -3,509.30 -1,907.09 6,024,372.07 531,622.83 1.95 8,277.62 92.90 183.00 3,676.78 3,624.83 -3,572.41 -1,910.11 6,024,308.95 531,620.09 2.20 8,341.18 93.65 183.22 3,673.15 3,621.20 -3,635.78 -1,913.56 6,024,245.58 531,616.93 1.23 8,405.09 93.82 183.67 3,668.99 3,617.04 -3,699.43 -1,917.39 6,024,181.91 531,613.39 0.75 8,468.68 94.20 183.67 3,664.54 3,612.59 -3,762.74 -1,921.45 6,024,118.59 531,609.61 0.60 8,532.91 94.88 183.82 3,659.46 3,607.51 -3,826.63 -1,925.63 6,024,054.69 531,605.72 1.08 8,596.43 95.82 184.62 3,653.54 3,601.59 -3,889.70 -1,930.29 6,023,991.61 531,601.35 1.94 8,660.24 93.88 184.09 3,648.14 3,596.19 -3,953.10 -1,935.11 6,023,928.20 531,596.81 3.15 8,724.00 92.40 183.77 3,644.65 3,592.70 -4,016.61 -1,939.48 6,023,864.67 531,592.73 2.37 8,787.46 92.77 183.96 3,641.79 3,589.84 -4,079.86 -1,943.75 6,023,801.41 531,588.75 0.66 8,850.79 93.58 184.54 3,638.28 3,586.33 -4,142.92 -1,948.43 6,023,738.33 531,584.34 1.57 8,913.58 94.63 185.25 3,633.79 3,581.84 -4,205.32 -1,953.78 6,023,675.92 531,579.28 2.02 8,977.43 96.07 185.06 3,627.83 3,575.88 -4,268.63 -1,959.49 6,023,612.59 531,573.86 2.27 9,041.86 96.31 185.10 3,620.88 3,568.93 -4,332.43 -1,965.16 6,023,548.76 531,568.47 0.38 9,105.28 95.56 184.83 3,614.33 3,562.38 -4,395.27 -1,970.62 6,023,485.90 531,563.30 1.26 9,169.48 93.70 184.19 3,609.15 3,557.20 -4,459.06 -1,975.65 6,023,422.10 531,558.55 3.06 9,233.22 91.35 183.99 3,606.34 3,554.39 -4,522.58 -1,980.19 6,023,358.57 531,554.30 3.70 9,295.75 90.36 183.67 3,605.40 3,553.45 -4,584.96 -1,984.37 6,023,296.18 531,550.41 1.66 9,325.00 89.71 183.57 3,605.39 3,553.44 -4,614.15 -1,986.22 6,023,266.98 531,548.69 2.25 9,358.83 88.95 183.46 3,605.78 3,553.83 -4,647.91 -1,988.29 6,023,233.21 531,546.77 2.27 9,422.83 86.23 183.30 3,608.47 3,556.52 -4,711.74 -1,992.06 6,023,169.38 531,543.29 4.26 9,486.17 83.94 182.99 3,613.90 3,561.95 -4,774.75 -1,995.52 6,023,106.36 531,540.11 3.65 9,550.03 83.51 182.93 3,620.88 3,568.93 -4,838.14 -1,998.80 6,023,042.96 531,537.12 0.68 9,613.89 83.63 183.09 3,628.03 3,576.08 -4,901.51 -2,002.13 6,022,979.58 531,534.07 0.31 9,677.94 83.82 183.33 3,635.03 3,583.08 -4,965.08 -2,005.70 6,022,916.01 531,530.79 0.48 9,741.59 83.82 183.85 3,641.88 3,589.93 -5,028.23 -2,009.66 6,022,852.84 531,527.12 0.81 9,805.03 83.07 184.45 3,649.13 3,597.18 -5,091.09 -2,014.22 6,022,789.97 531,522.84 1.51 9,868.64 83.94 184.76 3,656.32 3,604.37 -5,154.09 -2,019.30 6,022,726.95 531,518.05 1.45 9,932.17 86.11 184.63 3,661.83 3,609.88 -5,217.16 -2,024.48 6,022,663.86 531,513.15 3.42 9,995.67 87.84 184.85 3,665.18 3,613.23 -5,280.36 -2,029.72 6,022,600.65 531,508.20 2.75 Vertical Section (ft) Survey Tool Name 2,997.77 3_MWD+IFR2+MS+Sag (2) 3,061.34 3_MWD+IFR2+MS+Sag (2) 3,124.97 3_MWD+IFR2+MS+Sag (2) 3,186.79 3_MWD+IFR2+MS+Sag (2) 3,251.10 3_MWD+IFR2+MS+Sag (2) 3,315.73 3_MWD+IFR2+MS+Sag (2) 3,379.29 3_MWD+IFR2+MS+Sag (2) 3,442.99 3_MWD+IFR2+MS+Sag (2) 3,506.78 3_MWD+IFR2+MS+Sag (2) 3,570.06 3_MWD+IFR2+MS+Sag (2) 3,633.78 3_MWD+IFR2+MS+Sag (2) 3,696.95 3_MWD+IFR2+MS+Sag (2) 3,760.40 3_MWD+IFR2+MS+Sag (2) 3,824.17 3_MWD+IFR2+MS+Sag (2) 3,887.61 3_MWD+IFR2+MS+Sag (2) 3,951.63 3_MWD+IFR2+MS+Sag (2) 4,014.88 3_MWD+IFR2+MS+Sag (2) 4,078.45 3_MWD+IFR2+MS+Sag (2) 4,142.11 3_MWD+IFR2+MS+Sag (2) 4,205.51 3_MWD+IFR2+MS+Sag (2) 4,268.74 3_MWD+IFR2+MS+Sag (2) 4,331.36 3_MWD+IFR2+MS+Sag (2) 4,394.92 3_MWD+IFR2+MS+Sag (2) 4,458.96 3_MWD+IFR2+MS+Sag (2) 4,522.03 3_MWD+IFR2+MS+Sag (2) 4,586.02 3_MWD+IFR2+MS+Sag (2) 4,649.69 3_MWD+IFR2+MS+Sag (2) 4,712.21 3_MWD+IFR2+MS+Sag (2) 4,741.46 3_MWD+IFR2+MS+Sag (3) 4,775.29 3_MWD+IFR2+MS+Sag (3) 4,839.22 3_MWD+IFR2+MS+Sag (3) 4,902.32 3_MWD+IFR2+MS+Sag (3) 4,965.78 3_MWD+IFR2+MS+Sag (3) 5,029.23 3_MWD+IFR2+MS+Sag (3) 5,092.89 3_MWD+IFR2+MS+Sag (3) 5,156.17 3_MWD+IFR2+MS+Sag (3) 5,219.20 3_MWD+IFR2+MS+Sag (3) 5,282.39 3_MWD+IFR2+MS+Sag (3) 5,345.67 3_MWD+IFR2+MS+Sag (3) 5,409.08 3_MWD+IFR2+MS+Sag (3) 1/22/2020 12:55:10PM Page 5 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-24 Project: Milne Point TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Site: M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Well: MPU M-24 North Reference: True Wellbore: MPU M -24P133 Survey Calculation Method: Minimum Curvature Design: MPU M -24P133 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,059.63 89.38 184.94 3,666.73 3,614.78 -5,344.06 -2,035.17 6,022,536.93 531,503.03 2.41 5,473.01 3_MWD+IFR2+MS+Sag (3) 10,123.22 91.24 185.21 3,666.39 3,614.44 -5,407.40 -2,040.80 6,022,473.57 531,497.69 2.96 5,536.59 3_MWD+IFR2+MS+Sag (3) 10,185.84 92.96 185.56 3,664.09 3,612.14 -5,469.70 -2,046.67 6,022,411.26 531,492.10 2.80 5,599.14 3_MWD+IFR2+MS+Sag (3) 10,249.66 94.45 184.95 3,659.97 3,608.02 -5,533.11 -2,052.50 6,022,347.82 531,486.55 2.52 5,662.81 3_MWD+IFR2+MS+Sag (3) 10,313.06 96.13 185.05 3,654.13 3,602.18 -5,596.00 -2,058.00 6,022,284.91 531,481.34 2.65 5,725.93 3_MWD+IFR2+MS+Sag (3) 10,377.78 97.55 184.55 3,646.42 3,594.47 -5,660.03 -2,063.38 6,022,220.86 531,476.25 2.32 5,790.18 3_MWD+IFR2+MS+Sag (3) 10,441.43 97.74 184.33 3,637.95 3,586.00 -5,722.93 -2,068.26 6,022,157.95 531,471.65 0.45 5,853.26 3_MWD+IFR2+MS+Sag (3) 10,505.13 97.50 184.05 3,629.50 3,577.55 -5,785.90 -2,072.88 6,022,094.97 531,467.32 0.58 5,916.40 3_MWD+IFR2+MS+Sag (3) 10,568.99 96.68 183.70 3,621.62 3,569.67 -5,849.12 -2,077.16 6,022,031.73 531,463.32 1.39 5,979.77 3_MWD+IFR2+MS+Sag (3) 10,632.44 94.87 183.26 3,615.24 3,563.29 -5,912.13 -2,080.99 6,021,968.71 531,459.77 2.93 6,042.89 3_MWD+IFR2+MS+Sag (3) 10,696.23 94.51 182.52 3,610.02 3,558.07 -5,975.63 -2,084.20 6,021,905.21 531,456.86 1.29 6,106.46 3_MWD+IFR2+MS+Sag (3) 10,760.06 95.37 182.33 3,604.52 3,552.57 -6,039.16 -2,086.89 6,021,841.67 531,454.45 1.38 6,170.03 3_MWD+IFR2+MS+Sag (3) 10,824.03 93.09 181.38 3,599.81 3,547.86 -6,102.92 -2,088.95 6,021,777.91 531,452.68 3.86 6,233.77 3_MWD+IFR2+MS+Sag (3) 10,887.53 90.05 178.62 3,598.07 3,546.12 -6,166.38 -2,088.95 6,021,714.46 531,452.96 6.46 6,297.08 3_MWD+IFR2+MS+Sag (3) 10,951.31 90.43 178.84 3,597.80 3,545.85 -6,230.15 -2,087.54 6,021,650.71 531,454.66 0.69 6,360.59 3_MWD+IFR2+MS+Sag (3) 11,014.84 90.30 178.33 3,597.39 3,545.44 -6,293.66 -2,085.97 6,021,587.21 531,456.52 0.83 6,423.83 3_MWD+IFR2+MS+Sag (3) 11,078.77 90.99 178.83 3,596.67 3,544.72 -6,357.56 -2,084.38 6,021,523.32 531,458.39 1.33 6,487.47 3_MWD+IFR2+MS+Sag (3) 11,142.14 90.80 179.77 3,595.68 3,543.73 -6,420.92 -2,083.61 6,021,459.97 531,459.45 1.51 6,550.62 3_MWD+IFR2+MS+Sag (3) 11,205.90 91.60 180.38 3,594.35 3,542.40 -6,484.66 -2,083.69 6,021,396.23 531,459.65 1.58 6,614.22 3_MWD+IFR2+MS+Sag (3) 11,269.10 92.29 182.34 3,592.20 3,540.25 -6,547.81 -2,085.19 6,021,333.09 531,458.44 3.29 6,677.31 3_MWD+IFR2+MS+Sag (3) 11,333.47 92.04 182.39 3,589.77 3,537.82 -6,612.08 -2,087.85 6,021,268.82 531,456.07 0.40 6,741.61 3_MWD+IFR2+MS+Sag (3) 11,397.10 90.49 182.41 3,588.37 3,536.42 -6,675.63 -2,090.51 6,021,205.26 531,453.70 2.44 6,805.20 3_MWD+IFR2+MS+Sag (3) 11,460.50 89.51 183.36 3,588.37 3,536.42 -6,738.95 -2,093.70 6,021,141.93 531,450.79 2.15 6,868.58 3_MWD+IFR2+MS+Sag (3) 11,523.48 87.59 183.68 3,589.96 3,538.01 -6,801.79 -2,097.57 6,021,079.08 531,447.21 3.09 6,931.54 3_MWD+IFR2+MS+Sag (3) 11,586.93 88.15 184.56 3,592.32 3,540.37 -6,865.03 -2,102.12 6,021,015.83 531,442.94 1.64 6,994.94 3_MWD+IFR2+MS+Sag (3) 11,651.03 87.96 186.67 3,594.50 3,542.55 -6,928.78 -2,108.39 6,020,952.05 531,436.96 3.30 7,058.98 3_MWD+IFR2+MS+Sag (3) 11,713.26 88.52 187.74 3,596.41 3,544.46 -6,990.49 -2,116.19 6,020,890.32 531,429.44 1.94 7,121.08 3_MWD+IFR2+MS+Sag (3) 11,777.81 89.69 188.18 3,597.41 3,545.46 -7,054.41 -2,125.13 6,020,826.36 531,420.79 1.94 7,185.47 3_MWD+IFR2+MS+Sag (3) 11,842.06 91.30 188.07 3,596.86 3,544.91 -7,118.01 -2,134.21 6,020,762.73 531,412.00 2.51 7,249.55 3_MWD+IFR2+MS+Sag (3) 11,906.09 91.11 187.15 3,595.51 3,543.56 -7,181.46 -2,142.69 6,020,699.25 531,403.81 1.47 7,313.43 3_MWD+IFR2+MS+Sag (3) 11,969.83 91.79 187.20 3,593.90 3,541.95 -7,244.68 -2,150.64 6,020,636.00 531,396.13 1.07 7,377.05 3_MWD+IFR2+MS+Sag (3) 12,033.82 91.54 186.94 3,592.04 3,540.09 -7,308.16 -2,158.52 6,020,572.49 531,388.55 0.56 7,440.93 3_MWD+IFR2+MS+Sag (3) 12,095.49 92.22 186.25 3,590.02 3,538.07 -7,369.39 -2,165.60 6,020,511.24 531,381.75 1.57 7,502.50 3_MWD+IFR2+MS+Sag (3) 12,158.58 92.41 185.39 3,587.47 3,535.52 -7,432.10 -2,171.99 6,020,448.50 531,375.64 1.39 7,565.50 3_MWD+IFR2+MS+Sag (3) 12,223.69 90.80 184.90 3,585.65 3,533.70 -7,496.92 -2,177.82 6,020,383.66 531,370.09 2.58 7,630.57 3_MWD+IFR2+MS+Sag (3) 12,287.15 89.01 184.88 3,585.75 3,533.80 -7,560.14 -2,183.23 6,020,320.42 531,364.97 2.82 7,694.02 3_MWD+IFR2+MS+Sag (3) 12,350.76 87.16 184.32 3,587.88 3,535.93 -7,623.51 -2,188.33 6,020,257.04 531,360.16 3.04 7,757.59 3_MWD+IFR2+MS+Sag (3) 12,415.04 85.92 184.48 3,591.76 3,539.81 -7,687.48 -2,193.26 6,020,193.05 531,355.52 1.94 7,821.75 3_MWD+IFR2+MS+Sag (3) 12,478.40 85.99 184.05 3,596.23 3,544.28 -7,750.51 -2,197.96 6,020,130.01 531,351.11 0.69 7,884.95 3_MWD+IFR2+MS+Sag (3) 12,541.77 86.36 184.38 3,600.45 3,548.50 -7,813.57 -2,202.60 6,020,066.94 531,346.74 0.78 7,948.18 3_MWD+IFR2+MS+Sag (3) 1/22/2020 12:55:10PM Page 6 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-24 Project: Milne Point TVD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Site: M Pt Moose Pad MD Reference: MPU M-24 Actual Lateral RKB @ 51.95usft Well: MPU M-24 North Reference: True Wellbore: MPU M-24PB3 Survey Calculation Method: Minimum Curvature Design: MPU M-24PB3 Database: NORTH US + CANADA Survey Checked By: Chelsea Wright 0-202 01.22 Sfi09-09W Approved By: Benjamin Hand D.t..202 012214:33:51-09'00'd Date: 01-22-2020 1/2212020 12:55:10PM Page 7 COMPASS 5000.15 Build 91E Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1oo') (ft) Survey Tool Name 12,605.56 86.42 184.39 3,604.47 3,552.52 -7,877.05 -2,207.47 6,020,003.45 531,342.16 0.10 8,011.84 3_MWD+IFR2+MS+Sag (3) 12,669.34 85.92 184.17 3,608.73 3,556.78 -7,940.51 -2,212.22 6,019,939.97 531,337.70 0.86 8,075.48 3_MWD+IFR2+MS+Sag (3) 12,732.41 86.23 184.14 3,613.05 3,561.10 -8,003.26 -2,216.78 6,019,877.20 531,333.42 0.49 8,138.40 3_MWD+IFR2+MS+Sag (3) 12,795.77 86.23 184.10 3,617.21 3,565.26 -8,066.32 -2,221.32 6,019,814.13 531,329.17 0.06 8,201.62 3_MWD+IFR2+MS+Sag (3) 12,856.70 87.22 184.23 3,620.69 3,568.74 -8,126.99 -2,225.74 6,019,753.45 531,325.02 1.64 8,262.45 3_MWD+IFR2+MS+Sag (3) 12,922.31 88.40 184.30 3,623.20 3,571.25 -8,192.37 -2,230.61 6,019,688.05 531,320.44 1.80 8,328.01 3_MWD+IFR2+MS+Sag (3) 12,986.25 89.69 184.19 3,624.27 3,572.32 -8,256.12 -2,235.35 6,019,624.28 531,316.00 2.02 8,391.94 3_MWD+IFR2+MS+Sag (3) 13,049.75 90.80 184.37 3,623.99 3,572.04 -8,319.45 -2,240.09 6,019,560.95 531,311.55 1.77 8,455.44 3_MWD+IFR2+MS+Sag (3) 13,113.31 92.41 184.55 3,622.21 3,570.26 -8,382.79 -2,245.03 6,019,497.59 531,306.89 2.55 8,518.97 3_MWD+IFR2+MS+Sag (3) 13,176.94 93.52 185.09 3,618.92 3,566.97 -8,446.11 -2,250.37 6,019,434.25 531,301.84 1.94 8,582.51 3_MWD+IFR2+MS+Sag (3) 13,239.98 94.88 184.41 3,614.31 3,562.36 -8,508.76 -2,255.57 6,019,371.58 531,296.91 2.41 8,645.37 3_MWD+IFR2+MS+Sag (3) 13,303.55 95.57 184.28 3,608.52 3,556.57 -8,571.88 -2,260.37 6,019,308.45 531,292.40 1.10 8,708.68 3_MWD+IFR2+MS+Sag (3) 13,367.51 93.21 183.42 3,603.62 3,551.67 -8,635.51 -2,264.65 6,019,244.81 531,288.41 3.93 8,772.44 3_MWD+IFR2+MS+Sag (3) 13,430.62 90.43 182.53 3,601.62 3,549.67 -8,698.49 -2,267.92 6,019,181.82 531,285.42 4.62 8,835.50 3_MWD+IFR2+MS+Sag (3) 13,494.08 88.94 182.96 3,601.97 3,550.02 -8,761.88 -2,270.96 6,019,118.43 531,282.67 2.44 8,898.95 3_MWD+IFR2+MS+Sag (3) 13,558.17 89.20 183.16 3,603.01 3,551.06 -8,825.87 -2,274.38 6,019,054.43 531,279.53 0.51 8,963.02 3_MWD+IFR2+MS+Sag (3) 13,621.29 90.12 184.02 3,603.38 3,551.43 -8,888.86 -2,278.33 6,018,991.42 531,275.87 2.00 9,026.14 3_MWD+IFR2+MS+Sag (3) 13,684.99 91.36 184.38 3,602.56 3,550.61 -8,952.38 -2,283.00 6,018,927.89 531,271.49 2.03 9,089.83 3_MWD+IFR2+MS+Sag (3) 13,747.95 93.40 184.06 3,599.94 3,547.99 -9,015.11 -2,287.63 6,018,865.14 531,267.14 3.28 9,152.73 3_MWD+IFR2+MS+Sag (3) 13,811.57 93.15 184.06 3,596.31 3,544.36 -9,078.47 -2,292.12 6,018,801.77 531,262.93 0.39 9,216.25 3_MWD+IFR2+MS+Sag (3) 13,875.09 93.02 183.80 3,592.89 3,540.94 -9,141.75 -2,296.47 6,018,738.48 531,258.87 0.46 9,279.67 3_MWD+IFR2+MS+Sag (3) 13,938.93 90.92 183.71 3,590.70 3,538.75 -9,205.41 -2,300.65 6,018,674.80 531,254.98 3.29 9,343.47 3 MWD+IFR2+MS+Sag (3) 14,001.74 91.48 184.04 3,589.38 3,537.43 -9,268.06 -2,304.89 6,018,612.14 531,251.02 1.03 9,406.27 3_MWD+IFR2+MS+Sag (3) 14,064.65 92.34 184.35 3,587.28 3,535.33 -9,330.77 -2,309.49 6,018,549.42 531,246.70 1.45 9,469.14 3_MWD+IFR2+MS+Sag (3) 14,128.10 92.90 184.73 3,584.38 3,532.43 -9,393.95 -2,314.51 6,018,486.22 531,241.97 1.07 9,532.52 3_MWD+IFR2+MS+Sag (3) 14,192.22 93.33 184.50 3,580.90 3,528.95 -9,457.77 -2,319.66 6,018,422.39 531,237.11 0.76 9,596.54 3_MWD+IFR2+MS+Sag (3) 14,255.94 92.89 184.21 3,577.44 3,525.49 -9,521.21 -2,324.49 6,018,358.93 531,232.56 0.83 9,660.17 3_MWD+IFR2+MS+Sag (3) 14,320.03 91.73 184.32 3,574.86 3,522.91 -9,585.07 -2,329.26 6,018,295.06 531,228.09 1.82 9,724.20 3_MWD+IFR2+MS+Sag (3) 14,389.00 91.73 184.32 3,572.78 3,520.83 -9,653.82 -2,334.45 6,018,226.30 531,223.21 0.00 9,793.14 PROJECTED to TD Checked By: Chelsea Wright 0-202 01.22 Sfi09-09W Approved By: Benjamin Hand D.t..202 012214:33:51-09'00'd Date: 01-22-2020 1/2212020 12:55:10PM Page 7 COMPASS 5000.15 Build 91E Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No. MP M-24 County North Slope Borough State CASING RECORD Surface V TO 5.072.00 Shne Denth 5 MR 00 AK Date Run 7 -Dec -19 Supv. S. Sunderland / J. Vanderpool PRTn Csg Wt. On Hook: 180,000 Type Float Collar: Innovex No. Hrs to Run: 12 Csg Wt. On Slips: 140,000 Type of Shoe: Innovex Casing Crew: Doyon Rotate Csg X Yes _ No Recip Csg X Yes _ No Ft. Min. 9.3 PPG Fluid Description: Spud Mud Liner hanger Info (Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Floats Held X Yes _ No Centralizer Placement: 82 each 9-5/8" x 12-1/2 Expando-lizer centralizers ran. 2 each with 4 stop rings on shoe joint. 1 free floating on next joint. 1 each on joint float collar and baffle adapter joint with 4 stop rings. 1 each on joints #1 to #21 then every other joint to #61. Every joint from #64 to #73. 1 each with 1 stop ring on each pup joint above and below ESIPC between joints #68 & #69. Every otherjoint from #75 to #122. CEMENTING REPORT Shoe @ 5066 FC @ 4,985.00 Top of Liner 34 Preflush (Spacer) Type: Tuned Spacer Density (ppg) 10 Volume pumped (BBLs) 60 Lead Slurry Type: Lead Sacks: 305 Yield: 2.35 Density (ppg) 12 Volume pumped (BBLs) 128 Mixing / Pumping Rate (bpm): 5 Tail Slurry w Type: Tail Sacks: 400 Yield: 1.16 F Density (ppg) 15.8 Volume pumped (BBLs) 82 Mixing / Pumping Rate (bpm): 5 v, Post Flush (Spacer) 16 Type: Density (ppg) Rate (bpm): Volume: LL Displacement: Type: Spud Mud Density (ppg) Rate (bpm): 5 Volume (actual / calculated): 351.75/355.08 FCP (psi): Pump used for disp: Rig Bump Plug? X Yes No Bump press 1200 Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job 9 Cement returns to surface? X Yes -No Spacer retums? X Yes -No Vol to Surf. 3 Cement In Place At: 19:00 Date: 12/7/2019 Estimated TOC: 2,847 Method Used To Determine TOC: Cement to surface from ES cementer Stage Collar @ 2847 Type ES Casing (Or Liner) Detail Preflush (Spacer) Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top 1 Shoe 95/8 Density (ppg) 10.7 Volume pumped (BBLs) TXP BTC -SR Innovex 1.60 5,066.00 5,064.40 2 Casing 95/8 40.0 L-80 TXP BTC -SR Tenaris 78.90 5,064.40 4,985.50 1 Float Collar 95/8 Type: Density (ppg) TXP BTC -SR Innovex 1.31 4,985.50 4,984.19 2 Casing 95/8 40.0 L-80 TXP BTC -SR Tenaris 38.76 4,984.19 4,945.43 1 Baffle Adapter 95/8 Yes _No Spacer returns? -Yes X No Vol to Surf: 204 TXP BTC -SR HES 1.48 4,945.43 4,943.95 69 Casing 95/8 40.0 L-80 TXP BTC -SR Tenaris 2,707.86 4,943.95 2,236.09 1 Pup 95/8 L-80 TXP BTC -SR Tenaris 14.84 2,236.09 2,221.25 1 ESC 95/8 40.0 TXP BTC -SR HES 2.83 2,221.25 2,218.42 1 Pup 95/8 40.0 L-80 TXP BTC -SR Tenaris 14.67 2,218.42 2,203.75 55 Casing 95/8 40.0 L-80 TXP BTC -SR Tenaris 1 2,149.89 2,203.75 53.86 1 Cut Jt 95/8 40.0 L-80 TXP BTC -SR Tenaris 21.41 1 53.86 32.45 Csg Wt. On Hook: 180,000 Type Float Collar: Innovex No. Hrs to Run: 12 Csg Wt. On Slips: 140,000 Type of Shoe: Innovex Casing Crew: Doyon Rotate Csg X Yes _ No Recip Csg X Yes _ No Ft. Min. 9.3 PPG Fluid Description: Spud Mud Liner hanger Info (Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Floats Held X Yes _ No Centralizer Placement: 82 each 9-5/8" x 12-1/2 Expando-lizer centralizers ran. 2 each with 4 stop rings on shoe joint. 1 free floating on next joint. 1 each on joint float collar and baffle adapter joint with 4 stop rings. 1 each on joints #1 to #21 then every other joint to #61. Every joint from #64 to #73. 1 each with 1 stop ring on each pup joint above and below ESIPC between joints #68 & #69. Every otherjoint from #75 to #122. CEMENTING REPORT Shoe @ 5066 FC @ 4,985.00 Top of Liner 34 Preflush (Spacer) Type: Tuned Spacer Density (ppg) 10 Volume pumped (BBLs) 60 Lead Slurry Type: Lead Sacks: 305 Yield: 2.35 Density (ppg) 12 Volume pumped (BBLs) 128 Mixing / Pumping Rate (bpm): 5 Tail Slurry w Type: Tail Sacks: 400 Yield: 1.16 F Density (ppg) 15.8 Volume pumped (BBLs) 82 Mixing / Pumping Rate (bpm): 5 v, Post Flush (Spacer) 16 Type: Density (ppg) Rate (bpm): Volume: LL Displacement: Type: Spud Mud Density (ppg) Rate (bpm): 5 Volume (actual / calculated): 351.75/355.08 FCP (psi): Pump used for disp: Rig Bump Plug? X Yes No Bump press 1200 Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job 9 Cement returns to surface? X Yes -No Spacer retums? X Yes -No Vol to Surf. 3 Cement In Place At: 19:00 Date: 12/7/2019 Estimated TOC: 2,847 Method Used To Determine TOC: Cement to surface from ES cementer Calculated Cmt Vol @ 0% excess: 316.35 Total Volume cmt Pumped: 593.2 Cmt returned to surface: 204 Calculated cement left in wellbore: 389.2 OH volume Calculated: 307.1 OH volume actual: 379.95 Actual % Washout: 24 www.wellez.net WellEz Information Management LLC ver 04818br Stage Collar @ 2847 Type ES Closure OK Yes Preflush (Spacer) Type: Tuned Spacer Density (ppg) 10 Volume pumped (BBLs) 60 Lead Slurry Type: Permafrost L Sacks: 417 Yield: 4.41 Density (ppg) 10.7 Volume pumped (BBLs) 327 Mixing / Pumping Rate (bpm): 6 Tail Slurry w r, Type: Tail Sacks: 270 Yield: 1.17 y Density (ppg) 15.8 Volume pumped (BBLs) 56.2 Mixing / Pumping Rate (bpm): 5 z Post Flush (Spacer) u Type: Density (ppg) Rate (bpm): Volume: Lu Displacement: Type: Spud Mud Density (ppg) 9.25 Rate (bpm): 6 Volume (actual / calculated): 171/174.23 FCP (psi): 1000 Pump used for disp: Rig Bump Plug? X Yes No Bump press 1400 Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job 100 Cement returns to surface? X Yes _No Spacer returns? -Yes X No Vol to Surf: 204 Cement In Place At: 4:34 Date: 12/8/2019 Estimated TOC: 34 Method Used To Determine TOC: Cement returns to surface Post Job Calculations: Calculated Cmt Vol @ 0% excess: 316.35 Total Volume cmt Pumped: 593.2 Cmt returned to surface: 204 Calculated cement left in wellbore: 389.2 OH volume Calculated: 307.1 OH volume actual: 379.95 Actual % Washout: 24 www.wellez.net WellEz Information Management LLC ver 04818br MPU M-24 OH Sidetrack Summary PBI PB2 PB3 TD 5,803' MD / 3,776' TVD 9,810' MD / 3,557' TVD 14,389' MD / 3,573' TVD KOP 5,095' MD 9,325' MD 12,050' MD Date 1/13/2020 1/15/2020 1/18/2020 PTD: 219-160 / API: 50-029-23657-00-00 219160 Debra Oudean Hilcorp Alaska, LLC 32 3 0 9 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Aamnrp Al,,wkp, T.M E-mail: doudean@hilcorp.com DATE 03/23/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU M-24 (219-160 MAR 2020 AOGCC MPU M-24 PB1 MPU M-24 PB2 MPU M-24 PB3 Halliburton LWD FINAL 22 JAN 2020 MPU M-24 & P131 P132 PB3 CGM 1/24/2020 10:36 PM Filefolder Definitive Survey 1/24/20201036 PM Filefolder EMF 1/24/202010:36 PM Filefolder LAS 1/2412020 10:36 P M Filefolder PDF 1/241202010:36 PM Filefolder TIFF 1124/202010:36PNI Filefolder Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 03/23/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU M-24 (219-160 MPU M-24 PB1 MPU M-24 PB 2 MPU M-24 PB3 Halliburton LWD FINAL 22 JAN 2020 MPU M-24 & P11311 PB2 PB3 CGM 1124!20201036 PM Definitive Survey 1!24!202010:36 PIA EMF 1,24 120201036 PPA LAS 1; 24•''0201036 PM PDF 1 24• X02010:36 PM TIFF 1124-20201036131,4 RECEIVE MAR 2 5 2020 AOGCC File folder File fclder File folder File folder File folder File folder 219160 32310 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 03/23/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU M-24 (219-160 MPU M-24 PB1 MPU M-24 PB2 MPU M-24 PB3 Halliburton LWD FINAL 22 JAN 2020 MPU M-24 & P131 PB2 P133 CGM Definitive Survey EMF LAS PDF TEFF 1, 24'2oe^ 10:16 P1;' 1'24ri'_�H 1J:36PM 1i2a"_0 01DkHP",1 112422' 7 C;'E PM 1 aAe-,"2610:3_ Prvi RECEIVE MAR 2 5 2020 AOGCC Filefclder Filefclder Filefclder He fclder File fclder Filefclder 219160 3231 1 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 03/23/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTALI MPU M-24 (219-160 MPU M-24 PB1 MPU M-24 PB2 MPU M-24 PB3 Halliburton LWD FINAL 22 JAN 2020 MPU M-24 & P131 P132 P133 CGM Definitive Survey EMF LAS PDF TIFF 1.'2412020 10:36 PM 1/24,1202010:36 Ph1 1/24/202010:36 P M 1/24/202010:36 PM 1/24.+20201036PrV 1/241202010;36 PM RECEIVE MAR25 2020 SwVC Fife folder Fite folder File folder File folder File folder Fite folder r 32 312 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: THE STATE "ALASKA GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 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 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU M-24 Hilcorp Alaska, LLC Permit to Drill Number: 219-160 Surface Location: 5039' FSL, 651' FEL, SEC. 14, TI 3N, R9E, UM, AK Bottomhole Location: 544' FSL, 2274' FWL, SEC. 23, T13N, R9E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced development well. Per Statute AS 3 1.05.03 0(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, 4 W 4J re . Price Ch DATED this day of November, 2019. RECEIVED STATE OF ALASKA ALf.-r<A OIL AND GAS CONSERVATION COMMIbo ON PERMIT TO DRILL NOV 1 3 2019 20 AAC 25.005 _ — v. r% 1 a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. S A6 ed for: Drill Q Lateral ❑ Stratigraphic Test ❑ Development - Oil Q Service - Winj ❑ Single Zone Q Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development -Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244 MPU M-24 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 14,508' TVD: 3,499' Milne Point Field Schrader Bluff Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 5039' FSL, 651' FEL, Sec 14, T13N, R9E, UM, AK ADL025514, ADL355023 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 815' FNL, 2196' FEL, Sec 14, T13N, R9E, UM, AK LONS 16-004 11/26/2019 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 544' FSL, 2274' FWL, Sec 23, T13N, R9E, UM, AK 5815 815' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 59.0' 15. Distance to Nearest Well Open Surface: x- 533514 y- 6027890 Zone -4 GL / BF Elevation above MSL (ft): 25.1' to Same Pool: 1625' to MPU M-22 16. Deviated wells: Kickoff depth: 380 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 98.6 degrees Downhole: 1665 Surface: 1291 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) Cond 20" 215# X-42 Weld 80' Surface Surface 80' 80' 351 ft3 12-1/4" 9-5/8" 40# L-80 TXP SR 5,256' Surface Surface 5,256' 3,798' Stg 1 L- 715ft3/T-458ft3 Stg 2 L - 1937 ft3 / T - 314 ft3 Tieback 7" 26# L-80 TXP SR 5,106' Surface Surface 5,106 3,784' Tieback Assy. 8-1/2" 1 6-5/8" 20# L-80 Hyd 563 9,402' 5,106' 1 3,784' 1 14,508' 1 3,499' Cementless Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑1 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch Drilling Program e Seabed Report Time v. Depth Plot e Drilling Fluid Program e✓ Shallow Hazard Analysis8 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Joe Engel Authorized Name: Monty Myers Contact Email: �en el hlicor .coni Authorized Title: Drilling Manager Contact Phone: 777-8395 FvYZ wor�+►Y H^"Z C-�5 Authorized Signature: Date: //—/3-/f Commission Use Only Permit to Drill API Number: Permit ApprovalII See cover letter for other Number: — ( 6o 150- O ?-It3 6 �— 00 —� QQ Date: 1 21 requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: 5 `;�" j Samples req'd: Yes ❑ Noy' Mud log req'd: Yes❑ No[� H2S measures: Yes ❑ No [q" Directional svy req'd: Yes FS/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: C IS I N R THE COMMISSION Date: e1x 1 K -t1-U� 1e4iA Submit Form and FG 1 s , This permit is valid foumoat e proval per 20 AAC 25.00Attachments in oupticat` ` r j q Hilcorp Alaska, LLC Milne Point Unit (MPU) M-24 Drilling Program Version 1 11/13/2019 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.........................................................................................................11 10.0 N/U 21-1/4" 2M Diverter System.................................................................................................12 11.0 Drill 12-1/4" Hole Section.............................................................................................................14 12.0 Run 9-5/8" Surface Casing...........................................................................................................17 13.0 Cement 9-5/8" Surface Casing.....................................................................................................22 14.0 N/D Diverter, N/U Wellhead, Run Killstring, RDMO...............................................................27 15.0 MIRU Innovation, BOP N/U and Test, Pull Killstring..............................................................28 16.0 Drill 8-1/2" Hole Section...............................................................................................................29 17.0 Run 6-5/8" Production Liner.......................................................................................................34 18.0 Run 7" Tieback..............................................................................................................................38 19.0 Run Upper Completion.................................................................................................................41 20.0 Doyon 14 Diverter Schematic.......................................................................................................43 21.0 Doyon 14 BOP Schematic.............................................................................................................44 22.0 Innovation BOP Schematic..........................................................................................................45 23.0 Wellhead Schematic......................................................................................................................46 24.0 Days Vs Depth...............................................................................................................................47 25.0 Formation Tops & Information...................................................................................................48 26.0 Anticipated Drilling Hazards.......................................................................................................49 27.0 Doyon 14 Layout............................................................................................................................52 28.0 Innovation Rig Layout..................................................................................................................53 29.0 FIT Procedure...............................................................................................................................54 30.0 Doyon 14 Choke Manifold Schematic.........................................................................................55 31.0 Innovation Choke Manifold.........................................................................................................56 32.0 Casing Design................................................................................................................................57 33.0 8-1/2" Hole Section MASP............................................................................................................58 34.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................59 35.0 Surface Plat (As Built) (NAD 27).................................................................................................60 36.0 Schrader Bluff OA Sand Offset MW vs TVD Chart..................................................................61 ff Hilcorp Energy Company 1.0 Well Summary Milne Point Unit M-24 SB Producer Drilling Procedure Well MPU M-24 Pad Milne Point "M" Pad Planned Completion Tye Jet Pump on 4-1/2 tubing Target Reservoir(s) Schrader Bluff OA Sand Planned Well TD, MD / TVD 14,508' MD / 3,499' TVD PBTD, MD / TVD 14,498' MD / 3,499' TVD Surface Location (Governmental) 240' FNL, 651' FEL, Sec 14, T13N, R9E, UM, AK Surface Location (NAD 27) X= 533,513.9, Y= 6,027,889.5 Top of Productive Horizon (Governmental) 815' FNL, 2196' FEL, Sec 14, T13N, R9E, UM, AK TPH Location (NAD 27) X= 531972 Y= 6027308 BHL (Governmental) 544' FSL, 2274' FWL, Sec 23, T13N, R9E, UM, AK BHL (NAD 27) X= 5312101, Y= 6018105 AFE Number AFE Drilling Days 19 AFE Completion Days 4 AFE Drilling Amount $4,209,031 AFE Completion Amount $1,972,593 AFE Facility Amount $391,000 Maximum Anticipated Pressure (Surface) 1291 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1665 psig Work String 5" 19.5# S-135 NC 50 D14 KB Elevation above MSL: 33.7 ft + 25.1 ft = 58.8 ft Innovation KB above MSL: 26.5 ft + 25.1 ft = 51.7 ft GL Elevation above MSL: 25.1 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 2.0 Milne Point Unit M-24 SB Producer Drilling Procedure Management of Change Information 11 Hilcorp Alaska, LLC xilcorp Y C—ma: Changes to Approved Permit to Drill Date: 1111212019 Subject: Changes to Approved Permit to Drill for MPU M-24 File #: MPU M-24 Drilling and Completion Program Any modifications to MPU M-24 Drilling lis Completion Program will be documented and approved below. Changes to an approved RPD will be approved in advance to the AQGCC. Sec Page Date Procedure Change Approved av Approved By Approval. Drilling Manager Date Prepared: Drilling Engineer Page 3 3.0 Tubular Program: Milne Point Unit M-24 SB Producer Drilling Procedure Hole Section OD (in) ID (in) Drift in Conn OD its Wt (./ft Gracie Conn Burst (si) Collapse Tension (k -lbs) Cond 20" 19.25'' - - - X-52 Weld (Min) Max) (k -lbs) 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 TXP 5,750 3,090 916 Tieback 7" 6.276" 6.151" 7.656 26 L-80 TXP 7,240 5410 604 8-1/2" 6-5/8" Slotted 6.049 5.924 7.390 20 L-80 Hydril563 6,090 3,470 459 4.0 Drill Pipe Information: Hole OD ID (in) TJ ID TJ OD Wt Gracie Conn M/U M/U Tension Section (in) (in) (in) (#/ft) (Min) Max) (k -lbs) Surface & 5" 4.276" 3.25" 6.625" 19.5 5-135 DS50 36,100 43,100 560k1b Production 5" 4.276" 3.25" 6.625" 19.5 5-135 NC50 30,730 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 ff Hilcorp Enemy C—pmy 5.0 Internal Reporting Requirements Milne Point Unit M-24 SB Producer Drilling Procedure 5.1 Fill out daily drilling report and cost report on WellEz. • Report covers operations from 6am to 6am • 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. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolinighilcorp.com, mm ers ,hilcoM iengel@hilcorp.com and cdin er dhilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by lam on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 5.4 EHS Incident Reporting • Health and Safety: Notify EHS field coordinator. • Environmental: Drilling Environmental Coordinator • Notify Drilling Manager & Drilling Engineer on all incidents • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Rud' Casing tally to mmyersAhilcorp,com jengel a,hilcorp.com and cdin . eg_rghilcorp.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyersghilcorp.com jen ell c�hilcorp.com and cdin er e,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 ien�el@hilcorp.com Completion Engineer Taylor Wellman 907.777.8449 907.947.9533 tweliman@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 kfiemine@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 calones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcl .com Page 5 ff Hilcorp Energy Company 6.0 Milne Point Unit M-24 SB Producer Drilling Procedure Planned Wellbore Schematic Milne Point Unvt Well: I-APLI Pa1-24 Proposed SCHEMATIC Last Corripleted: Futwe FTl); TBEj Orig. KB Elev.: %9/61-Eler.: 25T Nin ID 2.75D" TREE & WELLHEAD Tree Cameron 41 16 5M 12-1/4"15tstage, FMC 11" 5M TC -1i w/11`x 4 i/2" TGII Top and BDttcm ,'ubing v,'elihead Hanger with 3" C1W "H" BPV profile. Zea 3/B" NFT ca^trol linEs. OPEN HOLE/ CEMENT DETAIL 4Y• 54 f toYards I;ik;Tiia dumped dmvn backside) 12-1/4"15tstage, L - 715 ft3 / T- 458 ft3 12.1/4"2ndrap L-1937€t31T-314ft3 B-112" yE^�eCilesislctted Liner in 8-11r hale CASING DETAIL : Type /Grade/Cann Drift IC Top 9Lrrn BPF 10`r1_1' conductcr (Insulated) 215.5 / X-52 /Weld N/A Surface 80' N/A 9-5r5' Surface 401 L-BQ/TXP 8-679'• Surface 5,256' Q.0758 Tieback 251L-8Q/TXP 6-151" Surface 5,106' 0.0383 6-5.8" Slotted Liner 201 L-30/ Wft5M 5-924" 5, ice' 1450V 0.0355 0 TUBING DETAIL ow,,F 12.6/L-80%TXF 3.958" Sura 1'6,0.nCY Q:QC�7 i Tubing WELL INCLINATION DETAIL KOP @ BW Max Hole Angle - @ let Pump Max tale Angle = @ XN prcft Max tole Angle Ttb,,rgtail Max Hole Angle = JEWELRY DETAIL ND. Top MD item Drift ID TBD (MDj Capper CDmp etiDn (MD) (TVD;: 1 24' TUbirg Hanger (4dVV TC41 Top & Sim) 3-970" 3 =5,709' 4.5" Discharge PressureGauge Mrel (Discharge Gauge] ' 3.674" 4 _5,7 4.5 XD ing5eeve 3.613 5 25,724 4.5 Gauge Man re- w 1.7 Wire (In!aka Gauge) 3.669 6 _5,749' 4.5'" X NiWe {3.613" Packirg ECrel 3.613'• 7 T_5,77D T x4.5 PHLAetrieva Padcc, 3- B *5,79 4.5" XN Nrpp E RHC -P set 3-613 9 5,131301 4.5 I,VLEG 3-936 Lower COmpievm 10 6,395 BOT S17 -1(P Liner Tap Packer yr 8D Vips 7'x 9-518 6.1 11 6,395 7 e ac Asst. 8.25 OD NO-GO) &151- 12 6,395 T F„yi ! n 563 L -8Q x 6-5 n 563 L -taco XO 13 14,94D' fry/B°ShCe - 41/2" SOLID LINER DETAIL �IIII� &112" Shoe IIIIII ................ TD=145W (M0j/TD--3,499M0) GENERAL WELL INFO PBTD=I4,S0S(MDI/TD=3,493'(iVD) API: TBD Drilled and Completed by ocean 14 & Iri - R,Rure Page 6 41/2" Slotted LINER DETAIL PEopSTop Tap Top TBD (MDj lam) (MD) (TVD;: TBD �IIII� &112" Shoe IIIIII ................ TD=145W (M0j/TD--3,499M0) GENERAL WELL INFO PBTD=I4,S0S(MDI/TD=3,493'(iVD) API: TBD Drilled and Completed by ocean 14 & Iri - R,Rure Page 6 41/2" Slotted LINER DETAIL PEopSTop (TVD) ftm (101)) TBD Hilcorp E—U C—wZ, 7.0 Drilling / Completion Summary Milne Point Unit M-24 SB Producer Drilling Procedure MPU M-24 is a grassroots jet pump producer planned to be drilled in the Schrader Bluff OA sand. M-24 is part of a multi well program targeting the Schrader Bluff sand on M -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 OA sand. An 8.5" lateral section will then be drilled. A 6-5/8" slotted liner will be run in the open hole section and the well produced with a jet pump assembly. The M-24 directional plan has the surface hole crossing the unity boundary to the north, in to KRU, and then returning to MPU before landing in the target zone. M-24 will not be producing hydorcarbons from KRU and no pay zone will be open with 500 feet of the MPU boundary, in compliance with AOGCC regulations. A wellbore easement application has been approved. The Doyon 14 will be used to drill the surface hole. Once surface hole is cased and cemented, D14 will run a killstring, freeze protect the well, and RDMO. Innovation rig will then MIRU, drill the lateral and complete the wellbore. ---- Drilling operations are expected to commence approximately November 26, 2019, pending rig schedule. Surface casing will be run to 5,256' MD / 3,798' 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 Doyon 14 to well site 2. N/U & Test 21-1/4" Diverter and 16" diverter line 3. Drill 12-1/4" hole to TD of surface hole section. Run and cement 9-5/8" surface casing 4. N/D diverter, N/U wellhead, run kill string, freeze protect. RDMO Doyon 14. 5. MIRU Innovation Rig. NU 13-5/8" 5M BOP & Test, pull kill string 6. Drill 8-1/2" lateral to well TD. Run 6-5/8" production liner 7. Run 7" tieback 8. Run Upper Completion 9. N/D BOP, N/U Tree, RDMO Innovation 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) Page 7 V Milne Point Unit M-24 SB Producer Hilco E� 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. • BOPs shall be tested at (2) week intervals during the drilling and completion of MPU M-24. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • 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. • 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. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • 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 • 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. See note in Section 7 regarding wellbore easement application. Page 8 Milne Point Unit M-24 SB Producer Drilling Procedure Summary of Doyon 14 BOP Equipment & Test Requirements Hole Section Equipment Test Pressure (psi) 12 1/4" • 21-1/4" 2M Diverter w/ 16" Diverter Line Function Test Only • 13-5/8" x 5M Hydril "GK" Annular BOP • 13-5/8" x 5M Hydril MPL Double Gate N/A o Blind ram in btm cavity • Mud cross w/ 3" x 5M side outlets For Reference 0 13-5/8" x 5M Hydril MPL Single ram • 3-1/8" x 5M Choke Line N/A • 3-1/8" x 5M Kill line 250/3000 • 3-1/8" x 5M Choke manifold • Standpipe, floor valves, etc Primary closing unit: NL Shaffer, 6 station, 3000 psi, 180 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air pump, and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Summary of Innovation BOP Equipment & Test Requirements Hole Section Equipment Test Pressure(psi) For Reference 13-5/8" 5M CTI Annular BOP w/ 16" diverter line N/A • 13-5/8" x 5M Control Technology Inc Annular BOP • 13-5/8" x 5M Control Technology Inc Double Gate Initial Test: 250/3000 o Blind ram in btm cavity • Mud cross w/ 3" x 5M side outlets 13-5/8" x 5M Control Technology Single ram • 3-1/8" x 5M Choke Line Subsequent Tests: • 3-1/8" x 5M Kill line 250/3000 • 3-1/8" x 5M Choke manifold • Standpipe, floor valves, etc 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. Page 9 0 Hilcorp E—W Company Milne Point Unit M-24 SB Producer Drilling Procedure Required AOGCC Notifications: • Well control event (BOPs utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPS. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: jim.regggalaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz cgalaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria.loeppgalaska.gov Mel Rixse / Petroleum Engineer / (0): 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/oge/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 j 9.0 RX and Preparatory Work 9.1 M-24 will utilize a newly set 20" conductor on M -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 Doyon 14. 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 (<80°F). 9.10 Ensure 6" liners in mud pumps. • Continental EMSCO FB -1600 mud pumps are rated at 4665 psi, 462 gpm @ 110 spm @ 95% volumetric efficiency. Page 11 Milne Point Unit M-24 SB Producer Hilco�+/�� Energy Company Drilling Procedure 9.0 RX and Preparatory Work 9.1 M-24 will utilize a newly set 20" conductor on M -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 Doyon 14. 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 (<80°F). 9.10 Ensure 6" liners in mud pumps. • Continental EMSCO FB -1600 mud pumps are rated at 4665 psi, 462 gpm @ 110 spm @ 95% volumetric efficiency. Page 11 ff Hilcorp E.W comv.Er 10.0 N/U 21-1/4" 2M Diverter System Milne Point Unit M-24 SB Producer Drilling Procedure 10.1 N/U 21-1/4" Hydril MSP 2M Diverter System (Diverter Schematic attached to program). • N/U 16-3/4" 3M x 21-1/4" 2M DSA on 16-3/4" 3M wellhead. • N/U 21-1/4" diverter "T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). • Diverter line must be 75 ft from nearest ignition source • Place drip berm at the end of diverter line. 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: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. Page 12 10.4 Rig & Diverter Orientation: • May change on location M -S8 M-22 M-17 M-23 ■ ■ M-16 M-24 75' Radius Clear of ignition Sources ---- Diverter Line Drawing Not To Scale MPU M - Pad Diverter Line May Be Oriented Different On Location Page 13 Milne Point Unit M-24 SB Producer Hilcorp E-� C-PZY Drilling Procedure 10.4 Rig & Diverter Orientation: • May change on location M -S8 M-22 M-17 M-23 ■ ■ M-16 M-24 75' Radius Clear of ignition Sources ---- Diverter Line Drawing Not To Scale MPU M - Pad Diverter Line May Be Oriented Different On Location Page 13 ff Hilcorp Energy Company 11.0 Drill 12-1/4" Hole Section Milne Point Unit M-24 SB Producer Drilling Procedure 11.1 PIU 12-1/4" directional drilling assembly: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Be sure to run a UBHO sub for wireline gyro • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# 5-135. • 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. • 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 OA sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6 deg / 100. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. • 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 • Slow in/out of slips and while tripping to keep swab and surge pressures low • Ensure shakers are functioning properly. Check for holes in screens on connections. • 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. • 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). • Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. Page 14 I/ Milne Point Unit M-24 SB Producer Drilling Procedure • Gas hydrates have not been seen on M -Pad. However, be prepared for them. In MPU they have been encountered typically around 2100-2400' TVD (just below permafrost). Be prepared for hydrates: • Gas hydrates can be identified by the gas detector and a decrease in MW or ECD • Monitor returns for hydrates, checking pressurized & non -pressurized scales • 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. Consider adding Lecithin to allow the gas to break out. • 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. • Surface Hole AC: • There are no wells with a clearance factor of <1.0 11.4 12-1/4" hole mud program summary: • 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 f5MW heeded -'f6 • PVT System: MD Totco PVT will be used throughout the drilling and completion phase. t Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. • 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. • 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. • 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. 1/ Page 15 Hilcorp E.-WC—vmr Milne Point Unit M-24 SB Producer Drilling Procedure • 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). System Type: 8.8 - 9.2 ppg Pre -Hydrated Aquagel/freshwater spud mud Properties: Section t Density Viscosi Plastic Viscosity Yield Point API FL H 4Tem 25 Surface 8.8-9.8/ 75-175 1 20-40 25-45 1 <10 1 8.5-9.0 5 70 F System Formulation: Gel + FW spud mud Product- Surface hole Size Pkg ppb or (% liquids) M -I Gel 50 lb sx 25 Soda Ash 50 lb sx 0.25 Pol Pac Supreme LTL 50 lb sx 0.08 Caustic Soda 50 lb sx 0.1 SCREENCLEEN 1 55 1 gal dm 1 0.5 11.5 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity. 1 l .6 RIH t/ bottom, proceed to BROOH t/ HWDP • Pump at full drill rate (400-600 gpm), and maximize rotation. • Pull slowly, 5 — 10 ft / minute, adjust as dictated by hole conditions • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • 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. rl Page 16 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull wearbushing. Milne Point Unit M-24 SB Producer Drilling Procedure 12.2 R/U Weatherford 9-5/8" casing running equipment (CRT & Tongs) • Ensure 9-5/8" TXP x DS50 XO on rig floor and M/U to FOSV. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.75" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • 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 lockiniz 120' shoe track assemblv consisting of - 9 -5/8" f 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 • Ensure bypass baffle is correctly installed on top of float collar. This end up. Bypass Baffle • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. Page 17 ff Hilcorp Energy Company 12.5 Float equipment and Stage tool equipment drawings: Type H ES Cementer Part No. SO No. Closing Sleeve No. Shear Pans Opening Sleeve No. Shear Pins ES Cementer Depth Baffle Adapter ("ii used ID Depth Bypass or Shut-off Baffle ID Depth Float Collar Depth Float Shoe Depth Hole TD -Reference Casing Sales Llanual Section 5 Page 18 "A Hikorp ES -B Running Order Part No. &,erall Length B Shut Off Plug mw, FD After Deallou9 C OD Max. Tool OD Opening Plug By -Pass Plug — Openfmg Seas JD E OD closing Seat ID Plug Set Hikorp ES -B Running Order Part No. ES41 Cementer SO No. Shut Off Plug Closing Plug OD Opening Plug By -Pass Plug — OD OD Shut-off Plug OD Bypass Plug (if used) I OD Milne Point Unit M-24 SB Producer Drilling Procedure Hikorp ES -B Running Order ES41 Cementer Shut Off Plug Baffle Adapter By -Pass Plug By Pass Baffle Float Colhv Float Shoe Hilcom Energy Company Milne Point Unit M-24 SB Producer Drilling Procedure 12.6 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: • 1 centralizer every joint t/ — 1000' MD from shoe • 1 centralizer every 2 joints to 2,000' above shoe (Top of Ugnu) • Verify depth of lowest Ugnu water sand for isolation with Geologist • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. • 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). • Install centralizers over couplings on 5 joints below and 5 joints above stage tool. • Do not place tongs on ES cementer, this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. • 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" 404 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 Page 19 0 Hilcorp E --W C-mrffy TX[—F, BTC C Milne Point Unit M-24 SB Producer Drilling Procedure ,,-- 1VOW2016 Outside Diameter AmEd 9.625 in. Miry. wan 67-545 Thickness ('j Ga de L80 Type 9 Udall Thickness D-395 m. Connection OD REGULAR Option cOUPLtN'u PIPE BODY Body: Red 1st Band: Red Grade LSO Type 1` [3rift API standard 1st Bard: Brown 2nc 63nd- 2nd Baal: - Brown Type Casing 3rd Sand:- 3rd Sand: - 41h Banti: - GEOMETRY Nominal 00 9.6.75 in. Nominal)tykight 40 lbsI LU t 8.679 it Nominal C 8.835 in. 91all Thickness 0..3.95 s^. %in End Weight 38.97 lbs' t OD 1 4-r,;nce API PERFORMANCE Body Yze+d Stye^yah 916 x 1000 tts 5750 ps; SMYS St3La06i psi ca�a::.se 3090 psi Page 20 ccr'7'ec.tw OC 10.825 in. Coupling Lsxgih 10.825 m_ Connection 11) 8.823 in - Make -up Loss 9.832 in. Threa--s per s* 5 Connection 00 Option REGULAR PERFORMANCE Tension ElStiance 100.9 % t a•: strs^s-h 916.000 x1000 Internal Pressure Capacity Itt 5750.000 psi lbs compression Eff6ency 100% Compression Stre7 h 916.000 x.1000 Max. Alimvable Bending 38 =100 ft lbs Ex emal rr-_sss;e Capacity 3090.600 Ps MAKE-UP TORQUES M^+imurr 18860 ft �s Optirnum 20960 Nibs Maximum 2309D rt -lbs OPERATION LIMIT TORQUES Operw g 1lz-a - 35600 ft -its Yield Torque 43400 ft-ibs Notes This connection is fully interchangeable with: TXPJ BTC - 9.625 in. - 36143-5147153-5158.4 IbVd [1] Internal Pressure Capacity related to structural resistance onI ,. Internal pressure leak resistance as per section 10.3 API 5031150 10400-2007. Datasheet is also valid for Special Bevel option when applicable - except for Coupling Face Load, which will be reduced. Please contact a local Tenaris technical sales representative. ff Hilcorp Energy Compmy Milne Point Unit M-24 SB Producer Drilling Procedure 12.8 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: o 1 centralizer every 2 joints to base of conductor 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.10 Slow in and out of slips. 12.11 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. 12.12 Lower casing to setting depth. Confirm measurements. 12.13 Have slips staged in cellar, along with necessary equipment for the operation. 12.14 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. V/ Page 21 0 Hilcorp E -W C—pay 13.0 Cement 9-5/8" Surface Casing Milne Point Unit M-24 SB Producer Drilling Procedure 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. • How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pumps will be utilized for displacement, and how fluid will be fed to displacement PUMP. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • 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 • Review test reports and ensure pump times are acceptable. • 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. L1� Estimated 1St Stage Total Cement Volume: Page 22 Section Calculation Vol (bbl) Vol (ft3) 12-1/4" OH x 9-5/8" ro (4,256'- 2500') x .0558 bpf x 1.3 = 127.4 715.2 J, Casing Total Lead 127.4 715.2 f' 12-1/4" OH x 9-5/8" (5,256'- 4,256') x .0558 bpf x 1.3 = 72.5 407 — Casing ~ 9-5/8" Shoe Track 120'x .0758 bpf = 9.1 51.09 Total Tail 1 81.6 458 Page 22 Milne Point Unit M-24 SB 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. • 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: 5,136' x.0758 bpf= 389.3 bbls 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 Page 23 Lead Slurry Tail Slurry System ExtendaCEM TM System SwiftCEM TM System Density 11.7 Ib/gal 15.8 Ib/gal Yield 4.298 ft3/sk 1.16 ft3/sk Mixed Water 21.13 gal/sk 5.04 gal/sk 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. • 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: 5,136' x.0758 bpf= 389.3 bbls 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 Page 23 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. Page 24 Milne Point Unit M-24 SB Producer Hilcorp E-W c - 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. Page 24 Hilcorp F W Company Second Stage Surface Cement Job: Milne Point Unit M-24 SB Producer Drilling Procedure 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. • 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 2"1 Stage Total Cement Volume: Cement Slurry Design (2nd stage cement job): Section Calculation Vol (bbl) Vol (ft3) SwiftCEM TM System (Hal Cem) 20" Conductorx 9-5/8" Casing (110') x .26 bpf x 1= 28.6 161 J 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 55.8 314 Cement Slurry Design (2nd stage cement job): Page 25 s Lead Slurry Tail Slurry System Permafrost L SwiftCEM TM System (Hal Cem) Density 10.7 Ib/gal 15.8 Ib/gal Yield 4.3279 ft3/sk 1.16 ft3/sk Mixed Water 21.405 gal/sk 5.08 gal/sk Page 25 s Hilcorp E -w C—P.HY Milne Point Unit M-24 SB 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: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • 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 flnal "As -Run " casing tally & casing and cement report to iengelghilcow. com and cdin er hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 26 0 Hilcorp C-PEY Milne Point Unit M-24 SB Producer Drilling Procedure 14.0 N/D Diverter, N/U Wellhead, Run Killstring, RDMO 14.1 N/D the diverter T, knife gate, diverter line & N/U 11" x 13-5/8" 5M casing spool. 14.2 RIH w/ 3.5" Killstring to 2,500' TVD 14.3 Land tubing hanger. 14.4 RILDS and test hanger. LD landing joint. 14.5 Install BPV. 14.6 N/U tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. 14.7 Freeze protect well. 14.8 Set BPV dart. Test tree to 250 psi low / 5000 psi high. Pull BPV dart and BPV 14.9 MO Doy n 1, -V1 , . Page 27 15.0 MIRU Innovation, BOP NX and Test, Pull Killstring 15.1 MIRU Innovation Rig • NOTE DIFFERENCE IN RKB for surface casing equipment depths 15.2 N/U 13-5/8" x 5M BOP as follows: • BOP configuration from top down: 13-5/8" x 5M annular / 13-5/8" x 5M double gate / U- 5/8" x 5M mud cross / 13-5/8" x 5M single gate • Double gate ram should be dressed with 2-7/8" x 5" VBRs in top cavity, blind ram in bottom cavity. • Single ram can be dressed with 2-7/8" x 5" VBRs • N/U bell nipple, install flowline. • Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). • Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve 15.3 RU MPD RCD and related equipment 15.4 Run 5" BOP test plug 15.5 Test BOP to 250/329�ysi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Test 5" test joints J� Confirm test pressures with PTD ��"" • Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug • Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 15.6 R/D BOP test equipment 15.7 R/U circ lines and circulaatte out diesel freeze protect 15.8 POOH, L/D killstring `' 15.9 Mix 8.9 ppg F1oPro fluid for production hole. 15.10 Set wearbushing in wellhead. 15.11 If needed, rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 15.12 Ensure 5" liners in mud pumps. Page 28 Milne Point Unit M-24 SB Producer Hilco �c Drilling Procedure 15.0 MIRU Innovation, BOP NX and Test, Pull Killstring 15.1 MIRU Innovation Rig • NOTE DIFFERENCE IN RKB for surface casing equipment depths 15.2 N/U 13-5/8" x 5M BOP as follows: • BOP configuration from top down: 13-5/8" x 5M annular / 13-5/8" x 5M double gate / U- 5/8" x 5M mud cross / 13-5/8" x 5M single gate • Double gate ram should be dressed with 2-7/8" x 5" VBRs in top cavity, blind ram in bottom cavity. • Single ram can be dressed with 2-7/8" x 5" VBRs • N/U bell nipple, install flowline. • Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). • Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve 15.3 RU MPD RCD and related equipment 15.4 Run 5" BOP test plug 15.5 Test BOP to 250/329�ysi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Test 5" test joints J� Confirm test pressures with PTD ��"" • Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug • Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 15.6 R/D BOP test equipment 15.7 R/U circ lines and circulaatte out diesel freeze protect 15.8 POOH, L/D killstring `' 15.9 Mix 8.9 ppg F1oPro fluid for production hole. 15.10 Set wearbushing in wellhead. 15.11 If needed, rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 15.12 Ensure 5" liners in mud pumps. Page 28 ff HilcoN E -W Compmy 16.0 Drill 8-1/2" Hole Section 16.1 M/U 8.5" Cleanout BHA (Milltooth Bit & 1.220 PDM) Milne Point Unit M-24 SB Producer Drilling Procedure 16.2 TIH w/ 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool. 16.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 16.4 R/U and test casing to 2500 psi / 30 min. Ensure to record volume / pressure (every'/4 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. 16.5 Drill out shoe track and 20' of new formation. l 16.6 CBU and condition mud for FIT. 16.7 Conduct FIT to 12.0 ppz EW. Chart Test. Ensure test is recorded on same chart as FIT. Document incremental volume pumped (and subsequent pressure) and volume returned. 16.8 POOH & LD Cleanout BHA 16.9 P/U 8-1/2" directional BHA. • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# S-135 DS50 & NC50. • Run a ported float in the production hole section. 16.10 8-1/2" hole section mud program summary: 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. • 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 Page 29 Milne Point Unit M-24 SB Producer Drilling Procedure 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. • 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 • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • 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 I YP LSYP Total Solids MBT HPHT Hardness Production 1 8.9-9.5 1 15-25 - ALAP 1 15-30 4-6 <10% <8 <1 1.0 <100 System Formulation: Product Concentration Water 0.955 bbl KCL 11 ppb KOH 0.1 ppb N -VIS 1.0 — 1.5 ppb DEXTRID LT 5 ppb BARACARB 5 4 ppb BARACARB 25 4 ppb BARACARB 50 2 ppb BARACOR 700 1.0 ppb BARASCAV D 0.5 ppb X-CIDE 207 0.015 ppb 16.11 TIH with 8-1/2" directional assembly to bottom 16.12 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid Page 30 Milne Point Unit M-24 SB Producer Drilling Procedure 16.13 Begin drilling 8.5" hole section, on -bottom staging technique: • Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8k. • Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations • If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to P/U off bottom and restart on bottom staging technique. If stick slip continues, consider adding .5% lubes 16.14 Drill 8-1/2" hole section to section TD per Geologist and Drilling Engineer. • Flow Rate: 350-550 gpm, target min. AV's 200 ft/min, 385 gpm • RPM: 120+ • 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. • Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low • Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection • Monitor Torque and Drag with pumps on every 5 stands • Monitor ECD, pump pressure & hookload trends for hole cleaning indication • Surveys can be taken more frequently if deemed necessary. • 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. • Use ADR to stay in section. Reservoir plan is to undulate between Schrader OA1 & OA3 lobes in 1000-1500' MD increments, and keeping DLS <3° when moving between lobes • 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. / • Target ROP is as fast as we can clean the hole without having to backream connections V • Schrader Bluff OA Concretions: 5-10% of lateral • L-47: 6%, L-50 9.5% • F-106: 6.1 %, F-107: 4.7%, F-018: 9.9%, F-109: 10%, F-110: 10.1 % • Offset injection and abnormal pressure has been seen on M-10, -11, -12. MPD will be utilized to monitor pressure build up on connections. • 8.5" Lateral A/C: • There are no wells with a clearance factor < 1.0 • Kup S2 is placeholder directional for a future target 16.15 Reference: Open hole sidetracking practice: • 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. • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. Page 31 Milne Point Unit M-24 SB Producer Drilling Procedure Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 16.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ gpm) and rotation (120+ rpm). Pump tandem sweeps if needed • Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary • If seepage losses are seen while drilling, consider reducing MW at TD to 9.Oppg minimum 16.17 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. 16.18 Displace 1.5 OH + Liner volume with viscosified brine. • Proposed brine blend (same as used on M-16, aiming for an 8 on the 6rpm reading) - KCl: 7.1 bbp 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 Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if further discussion needed prior to BROOH. 16.19 BROOH with the drilling assembly to the 9-5/8" casing shoe • Circulate at full drill rate (less if losses are seen, 350 gpm min). • Rotate at maximum rpm that can be sustained. `• Pulling speed 5 —10 min/std (slip to slip time, not including connections), adjust as dictated by hole conditions • If backreaming operations are commenced, continue backreaming to the shoe 16.20 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while BROOH. 16.21 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. Page 32 f Milne Point Unit M-24 SB Producer Hilco+rp F—Ty Company Drilling Procedure 16.22 Monitor well for flow / monitor for pressure build up with MPD. Increase fluid weight if necessary Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to determine if well is breathing, treat all flow as an influx until proven otherwise 16.23 POOH and LD BHA. 16.24 Continue to POH and stand back BHA if possible. Rabbit DP on TOH, 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 I Minimum Optimum Maximum Yield Torque 6-5/8 Milne Point Unit 7,100 ft -lbs 10,300 ft -lbs 1 36,000 ft -lbs M-24 SB Producer Hilcorp Drilling Procedure 17.0 Run 6-5/8" Production Liner 17.1 Well control preparedness: In the event of an influx of formation fluids while running the 6- 5/8" pre drilled liner, the following well control response procedure will be followed: • P/U & M/U the 5" safety joint (with 6-5/8" crossover installed on bottom, TIW valve in open position on top, 6-5/8" handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 6-5/8" Predrilled liner. • Slack off and with 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW. • Proceed with well kill operations. 17.2 R/U 6-5/8" liner running equipment. • Ensure 6-5/8" 20# Hydril 563 x DS -50 crossover is on rig floor and M/U to FOSV. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 17.3 Run 6-5/8" slotted production liner • Use API Modified or "Best O Life 2000 AG" thread compound. Dope pin end only w/ paint brush. Wipe off excess. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Run round nose float shoe on bottom. • 6-5/8" slotted liner will auto —fill • 6-5/8" Liner will be centralized with 1/joint free floating • If needed, install swell packers as per the lower completion tally. • Remove protective packaging on swell packers just prior to picking up • Do not place tongs or slips on the packer element 6-5/8" 20 # Hvdril 563 Torque OD Minimum Optimum Maximum Yield Torque 6-5/8 5,900 ft -lbs 7,100 ft -lbs 10,300 ft -lbs 1 36,000 ft -lbs Page 34 Wedge 5639 oulswe Diameter 6-m n. Wall Thic*nV53 02118 m. Grade Lao Type I Milne Point Unit 1:;1 Dann Red 1• : rjme: , Brown 2r4 Dan:l: M-24 SB Producer Brown Hilcorp E -,V Comp—y Drilling Procedure Wedge 5639 oulswe Diameter 6-m n. Wall Thic*nV53 02118 m. Grade Lao Type I min- Wall 875% Thickness Cormx-rtimmOD REGULAR cotion Drift AN Standard Type Casing 1—.— 1110&'2018 I') Grade IM 4muo- Type I COWUNG PMEBOUY Si Red 1:;1 Dann Red 1• : rjme: , Brown 2r4 Dan:l: 2rA lsxw. Brown jTd 3r%', UmU. REGULAR ,lifi Bind G E 0 MET RY — --------- C o n n e Co 7390 n GEOMETRY p Lttx 4.030 err Thf.A�p, rrs 3.25 rK, 0t--i,, REGULAR 6.615'6 No qw'.0 Wc.!N 3ti,1M L�;h :)r111 5324 40 6.049 Wal 17 h " k 0-20Z F'A 99-51.L,1! it's 00 Apt Take C 439-M -10X, Ma, Ak,&alk, gk:-,,:, res 52.0 ",M:01 PERFORMANCE 1^S Stprnzl caj,za, 3470.M p� Lead 3180fflr MAKE-UP TORQUES 3470 op4m.ril TA GO 103ft IIA"I OPERATION LIMIT TORQUES OP,fatvf4 Tcxua 31001: IDa YwlcZ�f�j. 36040 t ia,. G E 0 MET RY C o n n e Co 7390 n p Lttx 4.030 err Thf.A�p, rrs 3.25 rK, 0t--i,, REGULAR PERFORMANCE it's Take C 439-M -10X, Ma, Ak,&alk, gk:-,,:, res 52.0 ",M:01 1^S Stprnzl caj,za, 3470.M p� Lead 3180fflr MAKE-UP TORQUES 59001:-bs op4m.ril TA GO 103ft IIA"I OPERATION LIMIT TORQUES OP,fatvf4 Tcxua 31001: IDa YwlcZ�f�j. 36040 t ia,. BUCK -ON 10000 300 Notes This connection is fully interchangeaUe with: Wedge 56-'v:', - 6.625 in. - 24 } 28 Y 1-2 lbs;.ft Connections with Dopeles--S,, Technology are fully compatible vith the same connection in its Standard version Page 3 5 0 Hilcorp Energy Company Milne Point Unit M-24 SB Producer Drilling Procedure 16.6. Ensure to run enough liner to provide for approx 150' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. • 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 assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.8. M/U Baker SLZXP liner top packer to 6-5/8" liner. 16.9. Note PUW, SOW, ROT and torque of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.10. RIH w/ liner on 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. • Ensure 5" HWDP has been drifted • 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. 16.11. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + S/O depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.12. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, & 20 rpm 16.13. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.14. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.15. Rig up to pump down the work string with the rig pumps. 16.16. 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. 16.17. 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. Page 36 Milne Point Unit M-24 SB Producer Drilling Procedure 16.18. 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. 16.19. Continue pressuring up to 2700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the ZXP liner hanger to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4500 psi to release the HRDE running tool. 16.20. Bleed DP pressure to zero. 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, 16.21. PU to neutral weight, close BOP and test annulus to 1500 psi for 10 min and chart record same. 16.22. 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. 16.23. P/U pulling running tool free of the packer and displace with at max rate to wash the liner top. Pump sweeps as needed. 16.24. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOM 16.25. M/U 3.5" wash tool & RIH w/ remaining DP out of derrick to liner top. 16.26. Wash through liner top at max rate & circulate hole clean. Pump sweeps around. Displace well to clean filtered brine after no solids are returned. 16.27. POOH & L/D remaining 5" HWDP 16.28. Once running tool is L/D, swap to the completion AFE Page 3 7 Hilcorp E -W Company 18.0 IM Run 7" Tieback RIH w/ 3.5" washpipe on 5" dp to clean out liner top. POOH LDDP. Milne Point Unit M-24 SB Producer Drilling Procedure 18.2 R/U 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 and test 7" (250/3000 psi) solid body casing rams. 18.3 RX 7" casing handling equipment. • Ensure XO to DP made up to FOSV and ready on rig floor. • Rig up computer torque monitoring service. • String should stay full while running, r/u fill up line and check as appropriate. 18.4 P/U tieback seal assembly and set in rotary table. Ensure 7" seal assembly has x4 1" holes above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8" x 7" annulus. 18.5 M/U first joint of 7" to seal assy. 18.6 Run 7" 26# TXP tieback to position seal assembly two joints above tieback sleeve. Record up & down weights. 7" 26# TXP MUT OD Minimum Optimum Maximum Yield Torque 7" 13,280 ft -lbs 14,750 ft -lbs 16,230 ft -lbs 23,400 ft -lbs Page 3 8 TXPO BTC Compression'Sirength 604V0OXG1 h4ax Mewable Berdng 52 -,'100 h Milne Point Unit M-24 SB Producer Hilco E -W c..R Drilling Procedure TXPO BTC Compression'Sirength 604V0OXG1 h4ax Mewable Berdng 52 -,'100 h 12106,12018 Outside Diameter 7.000 in. Min. WaN MAKE-UP TORQUES Minirnum, 13280 ft-ts- OptrriLm Thickness OPERATION LIMIT TORQUES Grade LBO Operafing Torque 200W ft-4bs Yield TorqT 23400 #t -lbs Type I Wall Thickness 0.362 in Connection OD REGULAR Option COUPLING PIPE BODY Body: Red I st Band: Red Grade L80 Type V Drift API Standard tst Band: Brown 2nd Band 2nd Band, - Brown Type Casing 3rd Band - 3rd Band:- and--4th 4thBand: - GEOMETRY florrinal OD 7-000 in, Nominal IqVght 25 lbs+'ft ctift 6-1511 r" Norrinal M 6-276 in. Wall Ttidmess 0.362 in. Plain Erd lWight 25-69 tsR! OD Tclerarr-- APO PERFORMANCE Bxb• Y6-ld Slrenglh M xT000 lbs Interna: Yield 7240 psi ShIlys 80000 poi Collapse 5410 psi GEOMETRY Conre-Jon OD TI 56 in. CDShng LeVh 10-21)(1 in- 0--nnec6cri ID PF"Zo Make-up Loss 4.5N in, Threads 11*r in 5 C-crinertcri GO CrAcri REGULAR PERFORMANCE Tension Effixiwzy 100.0 % JoirA Ypid StTength 6134 DOO x 1,' XCL m k4c--mal F'ressum Capacity 1 7240.000 psi It's Cri7pressicri E!S-iercy too 1, Compression'Sirength 604V0OXG1 h4ax Mewable Berdng 52 -,'100 h Exl�mal Pressure Capazi1, 5410.00 psi MAKE-UP TORQUES Minirnum, 13280 ft-ts- OptrriLm 14750 1—t lbs rase-MIX11 16230 f -113 OPERATION LIMIT TORQUES Operafing Torque 200W ft-4bs Yield TorqT 23400 #t -lbs Notes This connection is fully interchangeable "fith: TXPGr0 BTC - 7 in. - 23 129 / 32135138 lbslft [1] Intemai Pressure Capacity related to structural resistance only. Intemal pressure leak resistance as per section 10,.3 API 5C3 I ISO 10400 - 2007. Page 39 0 18.7 M/U 7" to DP crossover. 18.8 M/U stand of DP to string, and M/U top drive. 18.9 Break circulation at 1 bpm and begin lowering string. Milne Point Unit M-24 SB Producer Drilling Procedure 18.10 Note seal assembly entering tieback sleeve with a pressure increase, Stop pumping and bleed off pressure, leave standpipe bleed off valve open. 18.11 Continue lowering string and land out on no-go. Set down 5 — l Ok lbs. Mark the pipe at this depth as "NO-GO DEPTH". 18.12 P/U string & remove unnecessary 7" joints. 18.13 P/U hanger assembly and space out. M/U (or L/D) necessary joints and pup joints to position seal assembly 1 ft above "NO-GO DEPTH" when tie -back hanger lands out in wellhead. 18.14 Ensure circulation is possible through 7" string. 18.15 RU and circulation corrosion inhibited brine in the 9-5/8" x 7" annulus. 18.16 With seals stabbed into SBE, Spot diesel freeze protection from 2500' to surface in 7" x 9-5/8" annulus by reverse circulating through the holes in the seal assembly. Ensure annular pressure are limited to prevent casing collapse of 7", verify collapse pressure of 7" tie back. 18.17 Slack off and land hanger. 18.18 Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning rpt. 18.19 Back out landing joint. M/U packoff running tool and install packoff on bottom of landing joint. Set tubing hanger pack off. RILDS. Test void to 3000 psi / 10 min. 18.20 R/D casing running tools. L< �_- Ik 18.21 Test 7" x 9-5/8" production annulus to 1000 psi / 30 min. 18.22 Set test plug and change top rams from 7" to 2-7/8" x 5-1/2" VBR. Test annular and lower rains to 2-7/8" test joint, 250 low / 3000 psi high. Page 40 19.0 Run Upper Completion 19.1 Change upper pipe rams back to 2-7/8" x 5" VBR. Test same. Verify the Jet pump components. 19.2 Run the 4-1/2" Jet Pump Completion as per the following, verify with Operations Engineer: 4-1/2" Multi -drop Gauge Mandrel 5' pup joint 4-1/2" Sliding Sleeve 5' pup joint 4-1/2" Gauge Mandrel 4' pup joint 10' pup joint 4-1/2" X Nipple (ID=3.813") 10' pup joint 10' pup joint 7"x4-1/2" Retrievable Packer 10' pup joint 10' pup joint 4-1/2" XN Nipple (113=3.75") — set shallower than 70deg deviation. Preload RHC plug body. 10' pup joint 4-1/2" full joints (# joints to be determined by on deviation survey) 4-1/2" WLEG Confirm depths with OE post drilling and final directional survey (reference updated schematic). 19.3 M/U Jet Pump assembly and RIH to setting depth. i. Ensure appropriate well control crossovers on rig floor and ready. ii. Monitor displacement from wellbore while RIH. 19.4 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 19.5 MU tubing hanger and landing joint. Terminate control lines. 19.6 Land tubing hanger. / 19.7 Drop ball and rod, pressure up to 1,700 psi to start setting of PHL packer. 19.8 Continue to pressure up to 3,000 psi to set packer. l19.9 Pressure up to 3,500 psi to test tubing for 30 minutes and chart. I 19.10 Bleed tubing to 2,000 psi. 19.11 Pressure up annulus to 3,500 psi to test casing/packer for 30 minutes and chart. 19.12 Bleed tubing and IA down to 0 psi. 19.13 RILDS and test hanger. LD landing joint. 19.14 Install BPV. N/D BOP. Page 41 Milne Point Unit M-24 SB Producer Hilco � SPP Drilling Procedure 19.0 Run Upper Completion 19.1 Change upper pipe rams back to 2-7/8" x 5" VBR. Test same. Verify the Jet pump components. 19.2 Run the 4-1/2" Jet Pump Completion as per the following, verify with Operations Engineer: 4-1/2" Multi -drop Gauge Mandrel 5' pup joint 4-1/2" Sliding Sleeve 5' pup joint 4-1/2" Gauge Mandrel 4' pup joint 10' pup joint 4-1/2" X Nipple (ID=3.813") 10' pup joint 10' pup joint 7"x4-1/2" Retrievable Packer 10' pup joint 10' pup joint 4-1/2" XN Nipple (113=3.75") — set shallower than 70deg deviation. Preload RHC plug body. 10' pup joint 4-1/2" full joints (# joints to be determined by on deviation survey) 4-1/2" WLEG Confirm depths with OE post drilling and final directional survey (reference updated schematic). 19.3 M/U Jet Pump assembly and RIH to setting depth. i. Ensure appropriate well control crossovers on rig floor and ready. ii. Monitor displacement from wellbore while RIH. 19.4 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 19.5 MU tubing hanger and landing joint. Terminate control lines. 19.6 Land tubing hanger. / 19.7 Drop ball and rod, pressure up to 1,700 psi to start setting of PHL packer. 19.8 Continue to pressure up to 3,000 psi to set packer. l19.9 Pressure up to 3,500 psi to test tubing for 30 minutes and chart. I 19.10 Bleed tubing to 2,000 psi. 19.11 Pressure up annulus to 3,500 psi to test casing/packer for 30 minutes and chart. 19.12 Bleed tubing and IA down to 0 psi. 19.13 RILDS and test hanger. LD landing joint. 19.14 Install BPV. N/D BOP. Page 41 Milne Point Unit M-24 SB Producer Drilling Procedure 19.15 N/U tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. Terminate the cap strings. 19.16 We won't be able to freeze protect the well with the rig. SL will be required to open the sliding sleeve to do this. Notify Wells Foreman of timing to ensure as close of coordination for SL from rig departure as possible. 19.17 Set BPV plug. Test tree to 250 psi low / 5000 psi high. Pull BPV plug and BPV. 19.18 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 19.19 Notify AOGCC of SVS testing. Test SVS on horizontal run of tree within 5 days of the start of production. Set low pressure trip below 275 psi Moose Pad header & separator pressure. 19.20 RDMO Innovation Rig Page 42 Hilcorp Eney Company 20.0 Doyon 14 Diverter Schematic 21 -VV Al R ser - 21.114' 2M-^ Divertw `r 21.943` A Sparer Srxx 16-3t4' W) 21 _ 1,,4.2fA 0--J Page 43 Milne Point Unit M-24 SB Producer Drilling Procedure —1{i' ea91 ppenm,g Knde V.,Jvt 16' Demon Uno Hilcorp Enema Compmy 21.0 Doyon 14 BOP Schematic K+ti Line -------- Page 44 Milne Point Unit M-24 SB Producer Drilling Procedure 2-7/8"" x 5" VBR Blind Rams x 5NI HCR of Gate VaNe 2-7/8"" x 5" VBR 22.0 Innovation BOP Schematic 3-1/8" Kill Line 9-5/8" DBL D Seal Casing Hanger S-22 13-5/8" NOM 9-5/8" BTC Btm x 10.5"-4 SA Pin Top W/ Primary Seat Page 45 Milne Point Unit M-24 SB Producer Drilling Procedure 13-5/8" 5M Control Technology Annular BOP �`'�---13-5/8" 5M Control j Technology Double Ram 3-1/8" Choke Line �"`--13-5/8" 5M Control Technology Single Ram 13-5/8" x 5M —11" x 5M 2-1/16" x 5M 13-5/8" x 5M \-2-1/16" x 5M -20" Casing 9-5/8" Casing ff Hilcorp e.e. gy c—p.oy 23.0 Wellhead Schematic It Milne Point Unit M-24 SB Producer Drilling Procedure Page 46 Hilcorp E—gy Company 24.0 Days Vs Depth 9 f 4000 6000 p 8000 v 10000 14000 16000 Page 47 Milne Point Unit M-24 SB Producer Drilling Procedure MPU M-24 SB OA Producer Days vs Depth 0 5 10 15 20 25 Days l 25.0 Formation Tops & Information MPU M-24 Formations (wp05) MD (ft) TVDss (ft) TVD (ft) Formation Pressure (psi) EMW (ppg) Milne Point Unit 2090 -1797 1856 M-24 SB Producer 8.46 Hilcorp Encrgy Company Drilling Procedure 25.0 Formation Tops & Information MPU M-24 Formations (wp05) MD (ft) TVDss (ft) TVD (ft) Formation Pressure (psi) EMW (ppg) Base Permafrost 2090 -1797 1856 816.64 8.46 LA3 3548 -3042 3101 1364.44 8.46 Schrader Bluff NA 4353 -3551 3610 1588.4 8.46 Schrader Bluff OA 5095 -3725 3784 1664.96 8.46 L -Pad Data Sheet Formation Description (Closest & Most Analogous MPU Pad to Moose Pad) GENERALIZED GEOLOGICAL FORECAST SS GEOLOGICAL TVD FM LITH DESCRIPTION COMMENTS Aa G4s NOTE: Soo individual Well Program for D.Plh..m Gubik specific casing design, depths, sizes, C00 weights, grades and connections. • Unconsolidated coarse to rn edium sand and small grovel • with minor siltstone. IF SIGNIFICANT AMOUNTS OF GRAVEL 1,000' a ARE ENCOUNTERED WHEN DRILLING THE -44*111 SURFACE HOLE, THE VISCOSITY OF THE MUD SYSTEM SHOULD IMMEDIATELY BE RAISED TO 150 SEC TO ENSURE EFFECTIVE HOLE CLEANING. 1750• Base permafrost htorbods of sand• clays and siltsmnes with occasional 2,000' show of coal. Watch possible sidetracking white wasldng7reaming. L33 E L-75. Saga .irktok .40= No hydrates encountered on L -Pad wells drilled to date. Continued Intorbods of sand. clays and siltstones with occasional shows of coal. Traces of pyrite at H- 3104 It 3,000, interval at -/.. 3400 It can be sticky and tight (L-01). Clay thterbeds between 3004 and 4500 t1 C 3472. L A 3657' kaanesv UGNU: Series of coarsening upward sands which are I AB,CA1 t made up of: (from top to bottom) coarse sand fine sand. silty shalo. Bober developed intervening stales as you UGNU progress into the Land M (deeper). Ugnu and Schrader Bluff: Possible hydrocarbons limited L.aanes to SW corner of Milne development Northernarea Is t•ABi downstructure and wet. •3738. K --da aAa.ci '4040' (NA) Schrader Bluff Sands: 4,000' (-AB.C.D. Continued layering coarsening upward sands as above .t�lri Schrader Bluff: Possible lost circulation E.F) except more condensed and with occasional coal. zone while drilling long strings and funning •4170' O -S noa Clay rich shale interval 4300 to 4604 ft. Ugmn and Schrader Bluff: Possible hydrocarbons limited casing. Recommend deep setting surface (CIA) t-AlIX to SW corner of Milne dewlopr ent Lal and L-45 are casing for Kuparuk long strings. Also, the D.E,N completed In the Schrader Bluff sand. Northern area of Schrader Bluff sands are a potential Schrader L -Pad is downstructure and wet. differential stuck pipe internal if left un -cased Bluff C Surface casing point In stale below for Kuparuk long Strings. Sands: I l Schrader Bluff OB sand for longer reach welly. Page 48 I'/ M 26.0 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. 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. Page 49 / Milne Point Unit M-24 SB Producer Hilcorp E.. gy C- Drilling Procedure 26.0 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. 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. Page 49 / 0 Hilm� Milne Point Unit M-24 SB Producer Drilling Procedure 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 50 8-1/2" Hole Section: Milne Point Unit M-24 SB Producer Drilling Procedure 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 1-12S. 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 1-12S 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. 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. Page 51 11 HilmiT En«gy Comp 27.0 Milne Point Unit M-24 SB Producer Drilling Procedure Doyon 14 Layout Page 52 Hilcorp E—gy company 28.0 Innovation Rig Layout Milne Point Unit M-24 SB Producer Drilling Procedure Page 53 Hilcorp E -V C-emr 29.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Milne Point Unit M-24 SB Producer Drilling Procedure 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 54 30.0 Doyon 14 Choke Manifold Schematic VY�Z 0 O p ro 17- M Milne Point Unit M-24 SB Producer Hilcorp Enema Compmy Drilling Procedure 30.0 Doyon 14 Choke Manifold Schematic VY�Z 0 O p ro 17- M A A 1=7 M w w u E o r p< p,O ,tA OD to 3 v+ Q w u CL N 3 > 3 c w e 0 ie O Gl;3 o a °_' < `ri N Z N ti r o co F L A Page 55 Hilcoip EnerW Compmy 31.0 Innovation Choke Manifold Milne Point Unit M-24 SB Producer Drilling Procedure Page 56 32.0 Casing Design 11 Calculation & Casing Design Factors Hilcorp DATE: 11/12/2019 WELL: MPU M-24 DESIGN BY: Joe Engel Hole Size 12-1/4" Hole Size 8-1/2" Hole Size Design Criteria: Mud Density: 9.2 ppg Mud Density: 9.2 ppg Mud Density: Drilling Mode MASP: 1291 psi (see attached MASP determination & calculation MASP: Production Mode MASP: 1291 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Milne Point Unit 9-5/8" 6-5/8" Top (MD) M-24 SB Producer 5,256 Hilco E -Sy com� Drilling Procedure 32.0 Casing Design 11 Calculation & Casing Design Factors Hilcorp DATE: 11/12/2019 WELL: MPU M-24 DESIGN BY: Joe Engel Hole Size 12-1/4" Hole Size 8-1/2" Hole Size Design Criteria: Mud Density: 9.2 ppg Mud Density: 9.2 ppg Mud Density: Drilling Mode MASP: 1291 psi (see attached MASP determination & calculation MASP: Production Mode MASP: 1291 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress Page 57 Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/8" 6-5/8" Top (MD) 0 5,256 Top (TVD) 0 3,798 Bottom (MD) 5,256 14,508 Bottom (TVD) 3,798 3,499 Length 5,256 9,252 Weight (ppf) 40 20 Grade L-80 L-80 Connection TXP H563 Weight w/o Bouyancy Factor (lbs) 210,240 185,040 Tension at Top of Section (lbs) 210,240 185,040 Min strength Tension (1000 lbs) 916 459 Worst Case Safety Factor (Tension) 4.36 v 2.48 Collapse Pressure at bottom (Psi) 1,876 1,729 Collapse Resistance w/o tension (Psi) 3,090 3,470 Worst Case Safety Factor (Collapse) 1.65 2.01 MASP (psi) 1,291 1,291 Minimum Yield (psi) 5,750 6,090 Worst case safety factor (Burst) 4.45 4.72 Page 57 Hilcorp E -w Company Milne Point Unit M-24 SB Producer Drilling Procedure 33.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation Hilcorp l 8-1/2" Hole Section F "� sy MPU M-24 Milne Point Unit MD TVD Planned Top: 5256 3798 Planned TD: 14508 3499 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OB Sand 3,798 1671 1 Oil 8.46 0.440 Offset Well Mud Densities Well MW ranee Too (TVD) Bottom (TVDI Date L-50 8.8-9.1 Surface 4125 2015 L-49 9.0-9.2 Surface 4196 2015 L-48 8.9-9.2 Surface 4147 2015 L-47 8.8-9.0 Surface 4158 2015 L-46 9.0-9.3 Surface 4177 2015 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 2. Maximum planned mud density for the 8-1/2" hole section is 9.5 ppg. 3. Calculations assume full evacuation of wellbore togas Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 3798 (ft) x 0.78(psi/ft)= 2962 2962(psi) - [0.1(psi/ft)*3798(ft)]= 2582 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff OA sand) 3798 (ft) x 0.44(psi/ft)= 1671 psi \ 1671(psi) - 0.1(psi/ft)*3798(ft) 1291 psi Summary: 1. MASP while drilling 8-1/2" production hole is governed by pore pressure and evacuation of entire wellbore togas at 0.1 psi/ft. Page 58 n Hilcorp Energy Company 34.0 Spider Plot (NAD 27) (Governmental Sections) Milne Point Unit M-24 SB Producer Drilling Procedure Milne Point Unit Alaska State Plane Zone 4LAD 1927 MPU M-24 Well 0 750 1,500 wpO5 Feet Page 59 Sec. I I Sec. 10' r¢ Ser. 12 j4&L3554023 ADL�88235- o. 1PUNI-24SHIL 22-14 Legend f MPU M -24 -SHL X MPU M-24_7PH 0 + MPU M-24-BHL Other Surface Holes (SHL) Sec. 14 0 IN Sec. 13 Other Bottom Holes (B HL) rl - - - Other Well Paths Coastline (USGS 1:53k) OX and Gas Unit Boundary Pad Footprint MILNE a OINT UNIT 0 ADL6255113 ADL025514 t N% —KUPARUK � &131N[009E— $1 Rliik NIT IIT 0 q L 14' o r Sec. 22 ry Bec.23 Sec. 24 lxze=si z n 14 --8L YF -- 20 L Sec 2AIkO 203,52!1 ADL025519 Sec. 25 71 Sec.. 25 Milne Point Unit Alaska State Plane Zone 4LAD 1927 MPU M-24 Well 0 750 1,500 wpO5 Feet Page 59 Hilcorp Energy Company 35.0 Surface Plat (As Built) (NAD 27) Milne Point Unit M-24 SB Producer Drilling Procedure Page 60 :. .i1 12 GRI— �.�,�r- THS PROJECT — MDOSc � I -M- PAD { SEC. T2 SEC. 13 _ -14 SEC. � I L i � � Ae-[D ■ v PQ ■ W-13 � ^"�' � T N-12 ■ i ■ W-14 23� W-20 ■ 41NE SITE E I. AI -57 ■ ■ M-13 k fl ■ M-16 VICINITY MAP M-56 ■ NTS U-22 w M-23+ ■ M -1e 1.4_24 w W-15 �.'' '•.9 I = mlathy F art: W_03 ■ � M-05` 1 t00 MOOSE PAD "�tSSICT7►L� GRAPHIC SCALE G too 200 400 SURVEYOR'S CERTIFICATE ( IN FEET ) t HEREBY WIT" THAT I AAI h& m: 2;0 t!. PROPERLY RECISTEAE7 AND LICENSED1 Ta PRACTICE LAND SURVEYNo :''N 74E STATE OF ALAStA AND THAT T%S AS -QUILT REPRESENTS A SURVEY �r+C��fy� MADE BY ME OR UNDER MY DIRECT LEGEND: w�ryT��' NOTES: SUPER -!"Ch AXO THAT ALL + AS -BUILT CONDUCTOR '' ALASKA STAT FldWE COORDINATES ARE NAD27. ZONE A. DINENS N5 AND 07HER DE-141LS ARE CORRECT AS OF MAY 31, 2015, 2. GEOCm PCSTI0p5 ANE NADV. ■ EIC'3TLNG CCMDUCT0IY y SAMS 0= 140FZ2CNTAL AND VERTICAL C.ONTRC4 IS S -ALCAP SM NE k SN_ALCAP MO M 4, NPU YOGSE AVERW PAO SLA1E FACTOR I5: Ct438Bt11 5_ DATE Cf "VEY. NAY 31, 2018. 0, FiEFEFENCE FIELD SOCK: / 5-a3 PG. 88-$8. LOCATED WITHIN PROTRACTED SEC. 14, T. :3 N., R. 9 E., UWAT PAERVAN, ALASKA WELL A. &P. PLANT GEODETIC GEODETIC SECTION PAD CELLAR NO. COORDINATES COORDINATES POSITION DIUS POSITION(D.DQ) OFFSETS ELEVATION BOX EL M-5 Y= 6027,765.67 Y= N= 1,168,03 70'29'12,805" 74.4868303' 4,9161' F5L 24.9' 25.D' 533,333.85 E= 1,334.97 149'43`39.385" 149.7275514' 831` FEL M-23 , Y= 6,027,889.67 IV= 1,292.04 74'29'14,013" 74.4872258' 5,435' F5L 25.0 25.2' X= 533,603.87 E= 1,605.92 149'43'31,224" 149-7253399' 561' FEL M-24 Y— 6,027,889.58 N= 1,29'x.95 70'29'14.016" 70.4872266' 5,039' FSL 25.1' 25.3' X= 533,51.3.90 E- 1,515.04 149'43'33.871' 149.7260753' 651' FET, ,' wN utrzea Yh HHJilcorpAlaska �...�.. f cA�w c VPIi MOOSE PAD AS—BUILT CONDUCTORS WELLS 5, 23 & 24 wA. Harz nnen, w. as Page 60 Hilcorp Energy C—pmy Milne Point Unit M-24 SB Producer Drilling Procedure 36.0 Schrader Bluff OA Sand Offset MW vs TVD Chart Schrader Bluff OA Sand Offset MW vs TVD MW, PP8 8.5 8.7 8.9 9.1 9.3 9.5 9.7 9.9 10.110.3 10.5 0 1 &fill 500 1000 1500 2000 a 2500 3000 3500 4000 4500 Page 61 MPU L-46 (2015) MPU L-47 (2015) MPU L-48 (2015) MPU L-49 (2015) MPU L-50 (2015) MPU F-106 (2017) MPU F-107 (2017) MPU F-108 (2017) MPU F-109 (2017) MPU F-110 (2017) Hilcorp Alaska, LLC Milne Point M Pt Moose Pad Plan: MPU M-24 MPU M-24 Plan: MPU M-24 wp05 Standard Proposal Report 11 November, 2019 HALLIBURTON Sperry Drilling Services (�0 (Cy O C CL O=NN cD ca IL 11 112!5 CL Qe C L L 0 ❑ ❑ ❑ ❑ > >❑ >❑ >❑ ❑ m 1 00 rZr (D m U) C')b M;p M� r b r�D V) ;;j. 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I m.l 0 0 0 N M (ui/4sn 0051) 43dad leoipaA anal ami Q O ml 0 0 V O N 0 0 O O O O cn 0 co 0 O LoO O O m ONI ,I- 00 O M Ln O O CD U Oo 'E V HALLIBURTON Spbrry Orilling Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPU M-24 Wellbore: MPU M-24 Plan: MPU M-24 wp05 TVD TVDSS MD Size Name 3798.00 3739.00 5256.13 9-5/8 9 5/8" x 12 1/4" 3499.00 3440.00 14508.68 6-5/8 6 5/8" x 8 1/2" WELL DETAILS: Plan: MPU M-24 Ground Level: 25.30 +N/ -S +E/ -W Northing Fasting Latitude Longitude 0.00 0.00 6027889.58 533513.90 701 29' 14.016 N 149° 43' 33.871 W REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan: MPU M-24, True North Vertical (TVD) Reference: MPU M-24 Planned RKB @ 59.00usft Measured Depth Reference: MPU M-24 Planned RKB @ 59.00usfl Calculation Method: Minimum Curvature 1500 I o I N I p0 I 750 J2SO \ oo J I 0 MPU 500' Butler - Full Start Dir 30/1001: 380' MD, 380'TVD -- - - - - - _ - - - - - - - - - - - 375 - o - - - - - - - - _ Start Di \4°/100' : 550' MD, 549.78'TVD 9 5/8" x 12 1/4" _ - Start Dir 4°/100' : 2081.57' MD, 1849.43'TVD _ M-24 04 Hee - :4956.13' MD, 3771.85' TVD I -750 _E_nd_Dir Start Dir 41/100': 5256.13' MD, 3798'TVD I - M-24 wp05 CPJ End Dir : 5440.04' MD, 3802.24' TVD Start Dir 4o/100': 6005.32' MD, 3779'TVD -1500 - M-24 wp05 CP - - - _End Dir : 6127.01' MD, 3770.1' TVD Start Dir 4°/100' : 6232.59' MD, 3759'TVD I End Dir : 6312.33' MD, 3751.99' TVD -2250- 2250-3000Start -3000- StartDir 40/100' : 8070.34' MD, 3627.9l'TVD _ End Dir : 8109.02' MD, 3625.71' TVD w I -3750 o I � I -4500 Start Dir 41/100': 9409.02' MD, 35691TVD - 7 M-24 wp05 CP3 _ _ End Dir : 9575.93' MD, 3570.58' TVD C_ Start Dir 4'/100': 9807.63' MD, 3585.07'TVD I -- -5250 - - - End Dir : 9938.42' MD, 3587.45' TVD O I � I I StartDir 4°/100' : 11088.42' MD, 3557.35'TVD -6000 - - ' End Dir : 11133.36' MD, 3556.76' TVD I M-24 wp05 CP4 - _ - - - - -6750 I -7500- I Start Dir 40/100': 13158.41' MD, 35571TVD ' -8250 M-24 wp05 CP5 _ End Dir : 13374.25' MD, 3540.84' TVD _ _ Start Dir 4°/100' : 13524.59' NO, 3518.35'TVD I -9000 - - - -End Dir : 13733.68' MD, 3502.25' TVD I I 6 5/8" x 8 1/2" Total Depth : 14508.68' MD, 3499' TVD -9750 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- ----- -- �� 3499 M-24 wp04 Toe MPU Lease tine -full MPU M-24 wpOS -10500 -6000 -5250 -4500 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 West( -)/East(+) (1500 usft/in) Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPU M-24 Wellbore: MPU M-24 Design: MPU M-24 wp05 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU M-24 TVD Reference: MPU M-24 Planned RKB @ 59.00usft MD Reference: MPU M-24 Planned RKB @ 59.00usft North Reference: True Survey Calculation Method: Minimum Curvature Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt Moose Pad Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 usft Slot Radius: Well Plan: MPU M-24, Slot 16 Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation Wellbore MPU M-24 Magnetics Model Name Sample Date BGGM2018 11/26/2019 Design MPU M-24 wp05 Audit Notes: Version: Vertical Section: 6,027,877.65usft Latitude: 533,363.92 usft Longitude: 13-3/16" Grid Convergence: 6,027,889.58 usf Latitude: 533,513.90 usf Longitude: 0.00 usf Ground Level: Declination Dip Angle (0) (o) 16.35 80.94 Phase: PLAN Tie On Depth: 33.70 Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 33.70 0.00 0.00 184.00 70° 29' 13.905 N 149° 43'38.286 W 0.26 ° 70° 29' 14.016 N 149° 43' 33.871 W 25.30 usft Field Strength (nT) 57,406.43490786 11/11/2019 5:38.51PM Page 2 COMPASS 5000.15 Build 91 Database: NORTH US + CANADA Dogleg Company: Hilcorp Alaska, LLC +N/ -S +E/ -W Project: Milne Point Rate Tool Face (usft) Site: M Pt Moose Pad (°/100usft) V) Well: Plan: MPU M-24 0.00 0.00 Wellbore: MPU M-24 0.00 0.00 0.00 Design: MPU M-24 wp05 0.00 6.55 Plan Sections 3.00 3.00 0.00 330.00 Measured -163.42 4.00 Vertical TVD Depth Inclination Azimuth Depth System (usft) (1) (1) (usft) usft 33.70 0.00 0.00 33.70 -25.30 380.00 0.00 0.00 380.00 321.00 550.00 5.10 330.00 549.78 490.78 1,417.83 39.81 330.82 1,339.59 1,280.59 2,081.57 39.81 330.82 1,849.43 1,790.43 4,956.13 85.00 190.73 3,771.85 3,712.85 5,256.13 85.00 190.73 3,798.00 3,739.00 5,440.04 92.36 190.73 3,802.24 3,743.24 6,005.32 92.36 190.73 3,779.00 3,720.00 6,127.01 96.03 187.53 3,770.10 3,711.10 6,232.59 96.03 187.53 3,759.00 3,700.00 6,312.33 94.05 185.02 3,751.99 3,692.99 8,070.34 94.05 185.02 3,627.91 3,568.91 8,109.02 92.50 185.02 3,625.71 3,566.71 9,409.02 92.50 185.02 3,569.00 3,510.00 9,575.93 86.41 182.27 3,570.58 3,511.58 9,807.63 86.41 182.27 3,585.07 3,526.07 9,938.42 91.50 183.50 3,587.45 3,528.45 11,088.42 91.50 183.50 3,557.35 3,498.35 11,133.36 89.99 184.48 3,556.76 3,497.76 13,158.41 89.99 184.48 3,557.00 3,498.00 13,374.25 98.60 183.83 3,540.84 3,481.84 13,524.59 98.60 183.83 3,518.35 3,459.35 13,733.68 90.24 183.95 3,502.25 3,443.25 14,508.68 90.24 183.95 3,499.00 3,440.00 Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU M-24 MPU M-24 Planned RKB @ 59.00usft MPU M-24 Planned RKB @ 59.00usft True Minimum Curvature 11/11/2019 5:38:51PM Page 3 COMPASS 5000.15 Build 91 Dogleg Build Turn +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) (usft) (°/100usft) (°/100usft) (°/100usft) V) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6.55 -3.78 3.00 3.00 0.00 330.00 291.30 -163.42 4.00 4.00 0.10 0.93 662.36 -370.58 0.00 0.00 0.00 0.00 -281.05 -1,489.02 4.00 1.57 -4.87 -135.17 -574.68 -1,544.66 0.00 0.00 0.00 0.00 -755.20 -1,578.86 4.00 4.00 0.00 -0.02 -1,310.13 -1,683.99 0.00 0.00 0.00 0.00 -1,429.92 -1,703.24 4.00 3.02 -2.63 -40.83 -1,534.01 -1,717.00 0.00 0.00 0.00 0.00 -1,612.96 -1,725.68 4.00 -2.49 -3.14 -128.40 -3,359.85 -1,879.23 0.00 0.00 0.00 0.00 -3,398.31 -1,882.61 4.00 -4.00 -0.01 -179.87 -4,692.10 -1,996.26 0.00 0.00 0.00 0.00 -4,858.57 -2,006.87 4.00 -3.65 -1.65 -155.71 -5,089.63 -2,016.04 0.00 0.00 0.00 0.00 -5,220.19 -2,022.63 4.00 3.89 0.94 13.57 -6,367.65 -2,092.81 0.00 0.00 0.00 0.00 -6,412.48 -2,095.94 4.00 -3.35 2.18 146.94 -8,431.34 -2,254.14 0.00 0.00 0.00 0.00 -8,645.80 -2,269.73 4.00 3.99 -0.30 -4.26 -8,794.11 -2,279.67 0.00 0.00 0.00 0.00 -9,001.92 -2,293.82 4.00 -4.00 0.06 179.21 -9,775.07 -2,347.20 0.00 0.00 0.00 0.00 11/11/2019 5:38:51PM Page 3 COMPASS 5000.15 Build 91 Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPU M-24 Wellbore: MPU M-24 Design: MPU M-24 wp05 Planned Survey Measured Map Vertical Depth Inclination Azimuth Depth TVDss (usft) (°) (°) (usft) usft 33.70 0.00 0.00 33.70 -25.30 100.00 0.00 0.00 100.00 41.00 200.00 0.00 0.00 200.00 141.00 300.00 0.00 0.00 300.00 241.00 380.00 0.00 0.00 380.00 321.00 Start Dir 31/100' : 380' MD, 380'TVD 0.00 400.00 0.60 330.00 400.00 341.00 500.00 3.60 330.00 499.92 440.92 550.00 5.10 330.00 549.78 490.78 Start Dir 41/100' : 550' MD, 549.78'TVD -3.12 600.00 7.10 330.26 599.49 540.49 700.00 11.10 330.50 698.21 639.21 800.00 15.10 330.62 795.59 736.59 900.00 19.10 330.69 891.15 832.15 1,000.00 23.10 330.73 984.43 925.43 1,100.00 27.10 330.76 1,074.97 1,015.97 1,200.00 31.10 330.79 1,162.33 1,103.33 1,300.00 35.10 330.81 1,246.08 1,187.08 1,382.28 38.39 330.82 1,312.00 1,253.00 SV5 4.00 -173.55 228.75 -128.48 1,400.00 39.10 330.82 1,325.82 1,266.82 1,417.83 39.81 330.82 1,339.59 1,280.59 End Dir : 1417.83' MD, 1339.59' ND 533,354.76 1,500.00 39.81 330.82 1,402.71 1,343.71 1,600.00 39.81 330.82 1,479.52 1,420.52 1,700.00 39.81 330.82 1,556.34 15497.34 1,800.00 39.81 330.82 1,633.15 1,574.15 1,900.00 39.81 330.82 1,709.97 1,650.97 2,000.00 39.81 330.82 1,786.78 1,727.78 2,081.57 39.81 330.82 1,849.44 1,790.44 Start Dir 40/100' : 2081.57' MD, 1849.43'TVD 616.76 2,090.10 39.57 330.45 1,856.00 1,797.00 BPRF -370.59 6,028,550.20 533,140.37 0.00 2,100.00 39.29 330.00 1,863.65 1,804.65 2,200.00 36.58 325.22 1,942.53 1,883.53 2,300.00 34.09 319.81 2,024.12 1,965.12 2,400.00 31.86 313.70 2,108.03 2,049.03 2,500.00 29.96 306.84 2,193.85 2,134.85 2,600.00 28.46 299.23 2,281.16 2,222.16 2,700.00 27.42 290.98 25369.54 2,310.54 2,800.00 26.89 282.29 2,458.55 2,399.55 2,900.00 26.91 273.44 2,547.76 2,488.76 3,000.00 27.48 264.77 2,636.74 2,577.74 3,100.00 28.56 256.56 2,725.05 2,666.05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU M-24 MPU M-24 Planned RKB @ 59.00usft MPU M-24 Planned RKB @ 59.00usft True Minimum Curvature 11/11/2019 5:38:51PM Page 4 COMPASS 5000.15 Build 91 Map Map +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) -25.30 0.00 0.00 6,027,889.58 533,513.90 0.00 0.00 0.00 0.00 6,027,889.58 533,513.90 0.00 0.00 0.00 0.00 6,027,889.58 533,513.90 0.00 0.00 0.00 0.00 6,027,889.58 533,513.90 0.00 0.00 0.00 0.00 6,027,889.58 533,513.90 0.00 0.00 0.09 -0.05 6,027,889.67 533,513.85 3.00 -0.09 3.26 -1.88 6,027,892.83 533,512.00 3.00 -3.12 6.55 -3.78 6,027,896.11 533,510.09 3.00 -6.27 11.16 -6.42 6,027,900.71 533,507.43 4.00 -10.68 24.91 -14.23 6,027,914.42 533,499.56 4.00 -23.85 44.64 -25.37 6,027,934.10 533,488.33 4.00 -42.76 70.27 -39.77 6,027,959.66 533,473.81 4.00 -67.32 101.66 -57.38 6,027,990.97 533,456.07 4.00 -97.41 138.66 -78.11 6,028,027.87 533,435.18 4.00 -132.87 181.09 -101.85 6,028,070.19 533,411.25 4.00 -173.55 228.75 -128.48 6,028,117.73 533,384.40 4.00 -219.23 271.72 -152.48 6,028,160.58 533,360.21 4.00 -260.42 281.40 -157.89 6,028,170.24 533,354.76 4.00 -269.70 291.30 -163.42 6,028,180.11 533,349.19 4.00 -279.19 337.23 -189.06 6,028,225.92 533,323.34 0.00 -323.22 393.14 -220.28 6,028,281.68 533,291.88 0.00 -376.81 449.04 -251.49 6,028,337.44 533,260.42 0.00 -430.41 504.95 -282.70 6,028,393.20 533,228.95 0.00 -484.00 560.85 -313.91 6,028,448.96 533,197.49 0.00 -537.59 616.76 -345.13 6,028,504.72 533,166.03 0.00 -591.18 662.36 -370.59 6,028,550.20 533,140.37 0.00 -634.90 667.11 -373.26 6,028,554.93 533,137.68 4.00 -639.44 672.57 -376.38 6,028,560.38 533,134.53 4.00 -644.67 724.48 -409.22 6,028,612.14 533,101.46 4.00 -694.17 770.38 -444.32 6,028,657.87 533,066.16 4.00 -737.51 810.03 -481.50 6,028,697.36 533,028.80 4.00 -774.47 843.25 -520.58 6,028,730.39 532,989.58 4.00 -804.88 869.87 -561.38 6,028,756.82 532,948.67 4.00 -828.59 889.76 -603.68 6,028,776.52 532,906.27 4.00 -845.48 902.82 -647.30 6,028,789.38 532,862.60 4.00 -855.47 908.99 -692.01 6,028,795.36 532,817.87 4.00 -858.51 908.25 -737.60 6,028,794.41 532,772.29 4.00 -854.58 900.59 -783.84 6,028,786.54 532,726.09 4.00 -843.72 11/11/2019 5:38:51PM Page 4 COMPASS 5000.15 Build 91 Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPU M-24 Wellbore: MPU M-24 Design: MPU M-24 wp05 Planned Survey Local Co-ordinate Reference ND Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU M-24 MPU M-24 Planned RKB @ 59.00usft MPU M-24 Planned RKB @ 59.00usft True Minimum Curvature Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) 2,725.00 3,167.42 29.54 251.39 2,784.00 2,725.00 891.54 -815.27 6,028,777.35 532,694.70 4.00 -832.49 UG_COAL1 3,200.00 30.09 249.01 2,812.27 2,753.27 886.05 -830.51 6,028,771.79 532,679.49 4.00 -825.96 3,300.00 32.01 242.21 2,897.96 2,838.96 864.70 -877.38 6,028,750.23 532,632.72 4.00 -801.39 3,400.00 34.26 236.15 2,981.71 2,922.71 836.65 -924.23 6,028,721.98 532,586.00 4.00 -770.14 3,500.00 36.78 230.79 3,063.12 3,004.12 802.03 -970.82 6,028,687.15 532,539.57 4.00 -732.36 3,547.69 38.05 228.46 3,101.00 3,042.00 783.26 -992.89 6,028,668.28 532,517.59 4.00 -712.09 LA3 3,600.00 39.50 226.05 3,141.78 3,082.78 761.02 -1,016.93 6,028,645.93 532,493.65 4.00 -688.23 3,700.00 42.40 221.84 3,217.31 3,158.31 713.81 -1,062.34 6,028,598.52 532,448.46 4.00 -637.96 3,800.00 45.44 218.08 3,289.35 3,230.35 660.62 -1,106.81 6,028,545.15 532,404.23 4.00 -581.81 3,900.00 48.58 214.70 3,357.54 3,298.54 601.73 -1,150.15 6,028,486.07 532,361.17 4.00 -520.04 3,935.87 49.73 213.57 3,381.00 3,322.00 579.27 -1,165.37 6,028,463.54 532,346.05 4.00 -496.57 UGNU MB 4,000.00 51.82 211.64 3,421.55 3,362.55 537.42 -1,192.12 6,028,421.57 532,319.48 4.00 -452.95 4,100.00 55.13 208.84 3,481.08 3,422.08 468.00 -1,232.54 6,028,351.97 532,279.38 4.00 -380.88 4,200.00 58.49 206.26 3,535.82 3,476.82 393.81 -1,271.21 6,028,277.62 532,241.06 4.00 -304.17 4,300.00 61.91 203.86 3,585.51 3,526.51 315.20 -1,307.92 6,028,198.86 532,204.70 4.00 -223.20 4,353.63 63.76 202.64 3,610.00 3,551.00 271.36 -1,326.75 6,028,154.93 532,186.07 4.00 -178.15 S13 NA 4,400.00 65.36 201.61 3,629.92 3,570.92 232.58 -1,342.52 6,028,116.08 532,170.48 4.00 -138.36 4,500.00 68.85 199.48 3,668.82 3,609.82 146.32 -1,374.82 6,028,029.69 532,138.57 4.00 -50.06 4,600.00 72.36 197.45 3,702.02 3,643.02 56.87 -1,404.67 6,027,940.11 532,109.13 4.00 41.26 4,700.00 75.89 195.50 3,729.37 3,670.37 -35.36 -1,431.92 6,027,847.78 532,082.29 4.00 135.16 4,800.00 79.44 193.60 3,750.72 3,691.72 -129.90 -1,456.45 6,027,753.13 532,058.19 4.00 231.18 4,900.00 83.00 191.75 3,765.99 3,706.99 -226.30 -1,478.13 6,027,656.65 532,036.95 4.00 328.86 4,956.13 85.00 190.73 3,771.85 3,712.85 -281.05 -1,489.02 6,027,601.86 532,026.31 4.00 384.23 End Dir : 4956.13' MD, 3771.85' TVD 5,000.00 85.00 190.73 3,775.68 3,716.68 -323.98 -1,497.15 6,027,558.88 532,018.37 0.00 427.63 5,095.50 85.00 190.73 3,784.00 3,725.00 -417.46 -1,514.86 6,027,465.34 532,001.08 0.00 522.11 SB_OA (heel) 5,100.00 85.00 190.73 3,784.39 3,725.39 -421.86 -1,515.70 6,027,460.93 532,000.27 0.00 526.56 5,200.00 85.00 190.73 3,793.11 3,734.11 -519.74 -1,534.25 6,027,362.98 531,982.16 0.00 625.50 5,256.13 85.00 190.73 3,798.00 3,739.00 -574.68 -1,544.66 6,027,308.00 531,972.00 0.00 681.03 Start Dir 40/100' : 5256.13' MD, 37987VD - 9 5/8" x 12 1/4" 5,300.00 86.75 190.73 3,801.15 3,742.15 -617.67 -1,552.80 6,027,264.98 531,964.05 4.00 724.48 5,400.00 90.75 190.73 3,803.33 3,744.33 -715.88 -1,571.41 6,027,166.70 531,945.89 4.00 823.75 5,440.04 92.36 190.73 3,802.24 3,743.24 -755.20 -1,578.86 6,027,127.35 531,938.61 4.00 863.50 End Dir : 5440.04' MD, 3802.24' ND 5,500.00 92.36 190.73 3,799.77 3,740.77 -814.06 -1,590.01 6,027,068.44 531,927.73 0.00 922.99 5,600.00 92.36 190.73 3,795.66 3,736.66 -912.23 -1,608.61 6,026,970.20 531,909.58 0.00 1,022.22 5,700.00 92.36 190.73 3,791.55 3,732.55 -1,010.40 -1,627.21 6,026,871.95 531,891.42 0.00 1,121.45 5,800.00 92.36 190.73 3,787.44 3,728.44 -1,108.57 -1,645.80 6,026,773.71 531,873.27 0.00 1,220.68 5,900.00 92.36 190.73 3,783.33 3,724.33 -1,206.74 -1,664.40 6,026,675.47 531,855.12 0.00 1,319.91 11/11/2019 5:38:51PM Page 5 COMPASS 5000.15 Build 91 Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPU M-24 Wellbore: MPU M-24 Design: MPU M-24 wp05 Planned Survey Measured TVD Reference: Vertical M-24 Planned Depth Inclination Azimuth Depth TVDss (usft) (°) (1) (usft) usft 6,005.32 92.36 190.73 3,779.00 3,720.00 Start Dir 4°/100' : 6005.32' MD, 3779'TVD 6,100.00 95.22 188.24 3,772.75 3,713.75 6,127.01 96.03 187.53 3,770.10 3,711.10 End Dir : 6127.01' MD, 3770.1' TVD (usft) 6,200.00 96.03 187.53 3,762.43 3,703.43 6,232.59 96.03 187.53 3,759.00 3,700.00 Start Dir 40/100' : 6232.59' MD, 3759'TVD -1,699.55 6,300.00 94.36 185.41 3,752.90 3,693.90 6,312.33 94.05 185.02 3,751.99 3,692.99 End Dir : 6312.33' MD, 3751.99' TVD 6,026,380.14 6,400.00 94.05 185.02 3,745.81 3,686.81 6,500.00 94.05 185.02 3,738.75 3,679.75 6,600.00 94.05 185.02 3,731.69 3,672.69 6,700.00 94.05 185.02 3,724.63 3,665.63 6,800.00 94.05 185.02 3,717.57 3,658.57 6,900.00 94.05 185.02 3,710.52 3,651.52 7,000.00 94.05 185.02 3,703.46 3,644.46 7,100.00 94.05 185.02 3,696.40 3,637.40 7,200.00 94.05 185.02 3,689.34 3,630.34 7,300.00 94.05 185.02 3,682.28 3,623.28 7,400.00 94.05 185.02 3,675.23 3,616.23 7,500.00 94.05 185.02 3,668.17 3,609.17 7,600.00 94.05 185.02 3,661.11 3,602.11 7,700.00 94.05 185.02 3,654.05 3,595.05 7,800.00 94.05 185.02 3,646.99 3,587.99 7,900.00 94.05 185.02 3,639.94 3,580.94 8,000.00 94.05 185.02 3,632.88 3,573.88 8,070.34 94.05 185.02 3,627.91 3,568.91 Start Dir 411100': 8070.34' MD, 3627.917VD -2,892.48 8,109.02 92.50 185.02 3,625.71 3,566.71 End Dir : 8109.02' MD, 3625.71' ND 531,680.70 8,200.00 92.50 185.02 3,621.74 3,562.74 8,300.00 92.50 185.02 3,617.37 3,558.37 8,400.00 92.50 185.02 3,613.01 3,554.01 8,500.00 92.50 185.02 3,608.65 3,549.65 8,600.00 92.50 185.02 3,604.29 3,545.29 8,700.00 92.50 185.02 3,599.93 3,540.93 8,800.00 92.50 185.02 3,595.57 3,536.57 8,900.00 92.50 185.02 3,591.20 3,532.20 9,000.00 92.50 185.02 3,586.84 3,527.84 9,100.00 92.50 185.02 3,582.48 3,523.48 9,200.00 92.50 185.02 3,578.12 3,519.12 9,300.00 92.50 185.02 3,573.76 3,514.76 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU M-24 TVD Reference: MPU M-24 Planned RKB @ 59.00usft MD Reference: MPU M-24 Planned RKB @ 59.00usft North Reference: True Survey Calculation Method: Minimum Curvature Map Map +N/_S +E/_W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) 3,720.00 -1,310.13 -1,683.99 6,026,572.00 531,836.00 0.00 1,424.41 -1,403.30 -1,699.55 6,026,478.78 531,820.85 4.00 1,518.43 -1,429.92 -1,703.24 6,026,452.14 531,817.29 4.00 1,545.25 -1,501.88 -1,712.75 6,026,380.14 531,808.10 0.00 1,617.70 -1,534.01 -1,717.00 6,026,348.00 531,804.00 0.00 1,650.05 -1,600.71 -1,724.56 6,026,281.27 531,796.74 4.00 1,717.11 -1,612.96 -1,725.68 6,026,269.02 531,795.68 4.00 1,729.41 -1,700.07 -1,733.34 6,026,181.88 531,788.41 0.00 1,816.84 -1,799.44 -1,742.07 6,026,082.48 531,780.13 0.00 1,916.58 -1,898.81 -1,750.81 6,025,983.09 531,771.84 0.00 2,016.31 -1,998.18 -1,759.54 6,025,883.69 531,763.55 0.00 2,116.05 -2,097.54 -1,768.28 6,025,784.30 531,755.27 0.00 2,215.78 -2,196.91 -1,777.01 6,025,684.90 531,746.98 0.00 2,315.52 -2,296.28 -1,785.74 6,025,585.50 531,738.70 0.00 2,415.25 -2,395.65 -1,794.48 6,025,486.11 531,730.41 0.00 2,514.99 -2,495.01 -1,803.21 6,025,386.71 531,722.13 0.00 2,614.72 -2,594.38 -1,811.95 6,025,287.32 531,713.84 0.00 2,714.46 -2,693.75 -1,820.68 6,025,187.92 531,705.55 0.00 2,814.19 -2,793.12 -1,829.42 6,025,088.52 531,697.27 0.00 2,913.93 -2,892.48 -1,838.15 6,024,989.13 531,688.98 0.00 3,013.66 -2,991.85 -1,846.89 6,024,889.73 531,680.70 0.00 3,113.40 -3,091.22 -1,855.62 6,024,790.34 531,672.41 0.00 3,213.13 -3,190.59 -1,864.35 6,024,690.94 531,664.12 0.00 3,312.87 -3,289.95 -1,873.09 6,024,591.54 531,655.84 0.00 3,412.60 -3,359.85 -1,879.23 6,024,521.63 531,650.01 0.00 3,482.75 -3,398.32 -1,882.61 6,024,483.15 531,646.80 4.00 3,521.36 -3,488.86 -1,890.57 6,024,392.58 531,639.26 0.00 3,612.24 -3,588.38 -1,899.31 6,024,293.03 531,630.97 0.00 3,712.13 -3,687.90 -1,908.05 6,024,193.48 531,622.67 0.00 3,812.02 -3,787.43 -1,916.79 6,024,093.93 531,614.38 0.00 3,911.91 -3,886.95 -1,925.54 6,023,994.38 531,606.09 0.00 4,011.80 -3,986.47 -1,934.28 6,023,894.83 531,597.80 0.00 4,111.69 -4,085.99 -1,943.02 6,023,795.28 531,589.50 0.00 4,211.58 -4,185.51 -1,951.76 6,023,695.73 531,581.21 0.00 4,311.46 -4,285.03 -1,960.50 6,023,596.18 531,572.92 0.00 4,411.35 -4,384.56 -1,969.25 6,023,496.63 531,564.63 0.00 4,511.24 -4,484.08 -1,977.99 6,023,397.08 531,556.33 0.00 4,611.13 -4,583.60 -1,986.73 6,023,297.53 531,548.04 0.00 4,711.02 11/11/2019 5.38:51PM Page 6 COMPASS 5000.15 Build 91 HALLIBURTt' N Halliburton Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU M-24 Company: Hilcorp Alaska, LLC ND Reference: MPU M-24 Planned RKB @ 59.00usft Project: Milne Point MD Reference: MPU M-24 Planned RKB @ 59.00usft Site: M Pt Moose Pad North Reference: True Well: Plan: MPU M-24 Survey Calculation Method: Minimum Curvature Wellbore: MPU M-24 Design: MPU M-24 wp05 Planned Survey - _- Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,510.00 9,409.02 92.50 185.02 3,569.00 3,510.00 -4,692.10 -1,996.26 6,023,189.00 531,539.00 0.00 4,819.92 Start Dir 41/100' : 9409.02' MD, 3569'TVD 9,500.00 89.18 183.52 3,567.66 3,508.66 -4,782.80 -2,003.03 6,023,098.28 531,532.63 4.00 4,910.87 9,575.93 86.41 182.27 3,570.58 3,511.58 -4,858.57 -2,006.87 6,023,022.50 531,529.14 4.00 4,986.72 End Dir : 9575.93' MD, 3570.58' ND 9,600.00 86.41 182.27 3,572.09 3,513.09 -4,882.57 -2,007.82 6,022,998.49 531,528.30 0.00 5,010.74 9,700.00 86.41 182.27 3,578.34 3,519.34 -4,982.30 -2,011.78 6,022,898.76 531,524.79 0.00 5,110.50 9,807.63 86.41 182.27 3,585.07 3,526.07 -5,089.63 -2,016.04 6,022,791.42 531,521.01 0.00 5,217.87 Start Dir 4°/100' : 9807.63' MD, 3585.07'TVD 9,900.00 90.01 183.14 3,587.96 3,528.96 -5,181.84 -2,020.40 6,022,699.20 531,517.07 4.00 5,310.15 9,938.42 91.50 183.50 3,587.45 3,528.45 -5,220.19 -2,022.63 6,022,660.85 531,515.01 4.00 5,348.56 End Dir : 9938.42' MD, 3587.45' ND 10,000.00 91.50 183.50 3,585.84 3,526.84 -5,281.63 -2,026.39 6,022,599.39 531,511.53 0.00 5,410.12 10,100.00 91.50 183.50 3,583.22 3,524.22 -5,381.41 -2,032.49 6,022,499.60 531,505.88 0.00 5,510.08 10,200.00 91.50 183.50 3,580.61 3,521.61 -5,481.19 -2,038.59 6,022,399.80 531,500.23 0.00 5,610.04 10,300.00 91.50 183.50 3,577.99 3,518.99 -5,580.97 -2,044.69 6,022,300.00 531,494.58 0.00 5,710.01 10,400.00 91.50 183.50 3,575.37 3,516.37 -5,680.75 -2,050.80 6,022,200.21 531,488.92 0.00 5,809.97 10,500.00 91.50 183.50 3,572.75 3,513.75 -5,780.53 -2,056.90 6,022,100.41 531,483.27 0.00 5,909.93 10,600.00 91.50 183.50 3,570.14 3,511.14 -5,880.31 -2,063.00 6,022,000.62 531,477.62 0.00 6,009.89 10,700.00 91.50 183.50 3,567.52 3,508.52 -5,980.09 -2,069.11 6,021,900.82 531,471.97 0.00 6,109.85 10,800.00 91.50 183.50 3,564.90 3,505.90 -6,079.87 -2,075.21 6,021,801.02 531,466.31 0.00 6,209.82 10,900.00 91.50 183.50 3,562.28 3,503.28 -6,179.65 -2,081.31 6,021,701.23 531,460.66 0.00 6,309.78 11,000.00 91.50 183.50 3,559.66 3,500.66 -6,279.43 -2,087.41 6,021,601.43 531,455.01 0.00 6,409.74 11,088.42 91.50 183.50 3,557.35 3,498.35 -6,367.65 -2,092.81 6,021,513.19 531,450.01 0.00 6,498.13 Start Dir 411100': 11088.42' MD, 3557.35'TVD 11,100.00 91.11 183.75 3,557.09 3,498.09 -6,379.20 -2,093.54 6,021,501.64 531,449.33 4.00 6,509.70 11,133.36 89.99 184.48 3,556.76 3,497.76 -6,412.48 -2,095.94 6,021,468.36 531,447.09 4.00 6,543.06 End Dir : 11133.36' MD, 3556.76' ND 11,200.00 89.99 184.48 3,556.77 3,497.77 -6,478.91 -2,101.14 6,021,401.91 531,442.18 0.00 6,609.70 11,300.00 89.99 184.48 3,556.78 3,497.78 -6,578.61 -2,108.95 6,021,302.19 531,434.82 0.00 6,709.69 11,400.00 89.99 184.48 3,556.80 3,497.80 -6,678.30 -2,116.77 6,021,202.47 531,427.46 0.00 6,809.69 11,500.00 89.99 184.48 3,556.81 3,497.81 -6,778.00 -2,124.58 6,021,102.75 531,420.09 0.00 6,909.69 11,600.00 89.99 184.48 3,556.82 3,497.82 -6,877.69 -2,132.39 6,021,003.03 531,412.73 0.00 7,009.68 11,700.00 89.99 184.48 3,556.83 3,497.83 -6,977.38 -2,140.20 6,020,903.31 531,405.37 0.00 7,109.68 11,800.00 89.99 184.48 3,556.84 3,497.84 -7,077.08 -2,148.02 6,020,803.59 531,398.01 0.00 7,209.68 11,900.00 89.99 184.48 3,556.85 3,497.85 -7,176.77 -2,155.83 6,020,703.87 531,390.65 0.00 7,309.67 12,000.00 89.99 184.48 3,556.87 3,497.87 -7,276.47 -2,163.64 6,020,604.16 531,383.28 0.00 7,409.67 12,100.00 89.99 184.48 3,556.88 3,497.88 -7,376.16 -2,171.45 6,020,504.44 531,375.92 0.00 7,509.67 12,200.00 89.99 184.48 3,556.89 3,497.89 -7,475.86 -2,179.26 6,020,404.72 531,368.56 0.00 7,609.66 12,300.00 89.99 184.48 3,556.90 3,497.90 -7,575.55 -2,187.08 6,020,305.00 531,361.20 0.00 7,709.66 12,400.00 89.99 184.48 3,556.91 3,497.91 -7,675.24 -2,194.89 6,020,205.28 531,353.83 0.00 7,809.66 12,500.00 89.99 184.48 3,556.92 3,497.92 -7,774.94 -2,202.70 6,020,105.56 531,346.47 0.00 7,909.65 12,600.00 89.99 184.48 3,556.94 3,497.94 -7,874.63 -2,210.51 6,020,005.84 531,339.11 0.00 8,009.65 12,700.00 89.99 184.48 3,556.95 3,497.95 -7,974.33 -2,218.32 6,019,906.12 531,331.75 0.00 8,109.65 12,800.00 89.99 184.48 3,556.96 3,497.96 -8,074.02 -2,226.14 6,019,806.41 531,324.39 0.00 8,209.64 11/11/2019 5.38.51PM Page 7 COMPASS 5000.15 Build 91 HALLIGURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPU M-24 Wellbore: MPU M-24 Design: MPU M-24 wp05 Planned Survey Measured Map Vertical Depth Inclination Azimuth Depth TVDss (usft) (°) (°) (usft) usft 12,900.00 89.99 184.48 3,556.97 3,497.97 13,000.00 89.99 184.48 3,556.98 3,497.98 13,100.00 89.99 184.48 3,556.99 3,497.99 13,158.41 89.99 184.48 3,557.00 3,498.00 Start Dir 40/100' : 13158.41' MD, 3557'TVD -8,431.34 13,200.00 91.65 184.36 3,556.40 3,497.40 13,300.00 95.64 184.06 3,550.04 3,491.04 13,374.25 98.60 183.83 3,540.84 3,481.84 End Dir : 13374.25' MD, 3540.84' TVD 8,709.40 13,400.00 98.60 183.83 3,536.99 3,477.99 13,500.00 98.60 183.83 3,522.03 3,463.03 13,524.59 98.60 183.83 3,518.35 3,459.35 Start Dir 40/100' : 13524.59' MD, 3518.35'TVD 13,600.00 95.59 183.88 3,509.04 3,450.04 13,700.00 91.59 183.93 3,502.78 3,443.78 13,733.68 90.24 183.95 3,502.25 3,443.25 End Dir : 13733.68' MD, 3502.25' TVD 531,263.06 13,800.00 90.24 183.95 3,501.97 3,442.97 13,900.00 90.24 183.95 3,501.55 3,442.55 14,000.00 90.24 183.95 3,501.13 3,442.13 14,100.00 90.24 183.95 3,500.71 3,441.71 14,200.00 90.24 183.95 3,500.29 3,441.29 14,300.00 90.24 183.95 3,499.87 3,440.87 14,400.00 90.24 183.95 3,499.46 3,440.46 14,508.68 90.24 183.95 3,499.00 3,440.00 Total Depth: 14508.68' MD, 3499' TVD 531,224.44 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU M-24 MPU M-24 Planned RKB @ 59.00usft MPU M-24 Planned RKB @ 59.00usft True Minimum Curvature 11/11/2019 5:38:51PM Page 8 COMPASS 5000.15 Build 91 Map Map +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) 3,497.97 -8,173.72 -2,233.95 6,019,706.69 531,317.02 0.00 8,309.64 -8,273.41 -2,241.76 6,019,606.97 531,309.66 0.00 8,409.63 -8,373.11 -2,249.57 6,019,507.25 531,302.30 0.00 8,509.63 -8,431.34 -2,254.14 6,019,449.00 531,298.00 0.00 8,568.04 -8,472.80 -2,257.34 6,019,407.53 531,294.98 4.00 8,609.62 -8,572.31 -2,264.66 6,019,308.00 531,288.11 4.00 8,709.40 -8,645.80 -2,269.73 6,019,234.49 531,283.37 4.00 8,783.07 -8,671.20 -2,271.44 6,019,209.09 531,281.78 0.00 8,808.53 -8,769.86 -2,278.05 6,019,110.41 531,275.62 0.00 8,907.40 -8,794.12 -2,279.68 6,019,086.15 531,274.10 0.00 8,931.72 -8,868.77 -2,284.71 6,019,011.48 531,269.40 4.00 9,006.54 -8,968.32 -2,291.50 6,018,911.91 531,263.06 4.00 9,106.32 -9,001.92 -2,293.82 6,018,878.31 531,260.90 4.00 9,140.00 -9,068.08 -2,298.38 6,018,812.13 531,256.63 0.00 9,206.32 -9,167.84 -2,305.27 6,018,712.35 531,250.19 0.00 9,306.32 -9,267.60 -2,312.16 6,018,612.57 531,243.75 0.00 9,406.32 -9,367.36 -2,319.05 6,018,512.79 531,237.31 0.00 9,506.31 -9,467.13 -2,325.94 6,018,413.00 531,230.87 0.00 9,606.31 -9,566.89 -2,332.83 6,018,313.22 531,224.44 0.00 9,706.31 -9,666.65 -2,339.72 6,018,213.44 531,218.00 0.00 9,806.31 -9,775.07 -2,347.20 6,018,105.00 531,211.00 0.00 9,914.99 11/11/2019 5:38:51PM Page 8 COMPASS 5000.15 Build 91 HALLIE3URTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPU M-24 Wellbore: MPU M-24 Design: MPU M-24 wp05 Targets Target Name hit/miss target Dip Angle Dip Dir. Shape (°) (°) M-24 wp05 CP2 0.00 0.00 plan hits target center Point M-24 wp04 Toe 0.00 plan hits target center Point M-24 wp05 CP4 0.00 plan hits target center Point M-24 wp05 CP3 0.00 plan hits target center Point M-24 wp05 CPI 0.00 plan hits target center Point M-24 wp05 CP5 0.00 plan hits target center Point M-24 wp04 Heel 0.00 0.00 plan hits target center Circle (radius 30.00) Casing Points Measured Vertical Depth Depth (usft) (usft) 5,256.13 3,798.00 9 5/8" x 12 1/4" 14,508.68 3,499.00 6 5/8" x 8 1/2" Formations Measured Vertical Vertical Depth Depth Depth SS (usft) (usft) 1,382.28 1,312.00 SV5 3,547.69 3,101.00 LA3 5,095.50 3,784.00 SB—OA (heel) 3,935.87 3,381.00 UGNU MB 4,353.63 3,610.00 SB NA 2,090.10 1,856.00 BPRF 3,167.42 2,784.00 UG COAL1 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU M-24 TVD Reference: MPU M-24 Planned RKB @ 59.00usft MD Reference: MPU M-24 Planned RKB @ 59.00usft North Reference: True Survey Calculation Method: Minimum Curvature TVD +N/ -S +E/ -W Northing Easting (usft) (usft) (usft) (usft) (usft) 3,759.00 -1,534.01 -1,717.00 6,026,348.00 531,804.00 0.00 3,499.00 -9,775.07 -2,347.20 6,018,105.00 531,211.00 0.00 3,557.35 -6,367.65 -2,092.81 6,021,513.19 531,450.01 0.00 3,569.00 -4,692.10 -1,996.26 6,023,189.00 531,539.00 0.00 3,779.00 -1,310.13 -1,683.99 6,026,572.00 531,836.00 0.00 3,557.00 -8,431.34 -2,254.14 6,019,449.00 531,298.00 3,798.00 -574.68 -1,544.66 6,027,308.00 531,972.00 Casing Hole Diameter Diameter Name (') (11) 9-5/8 12-1/4 6-5/8 8-1/2 Dip Dip Direction Name Lithology (°) (°) 11/11/2019 5:38:51PM Page 9 COMPASS 5000.15 Build 91 Plan Annotations Measured Vertical Halliburton H,ALLIBURTON Depth Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU M-24 Company: Hilcorp Alaska, LLC ND Reference: MPU M-24 Planned RKB @ 59.00usft Project: Milne Point MD Reference: MPU M-24 Planned RKB @ 59.00usft Site: M Pt Moose Pad North Reference: True Well: Plan: MPU M-24 Survey Calculation Method: Minimum Curvature Wellbore: MPU M-24 -3.78 Start Dir 40/100' : 550' MD, 549.78'TVD Design: MPU M-24 wp05 1,339.59 291.30 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 380.00 380.00 0.00 0.00 Start Dir 30/100' : 380' MD, 380'TVD 550.00 549.78 6.55 -3.78 Start Dir 40/100' : 550' MD, 549.78'TVD 1,417.83 1,339.59 291.30 -163.42 End Dir : 1417.83' MD, 1339.59' TVD 2,081.57 1,849.44 662.36 -370.59 Start Dir 41/100' : 2081.57' MD, 1849.43'TVD 4,956.13 3,771.85 -281.05 -1,489.02 End Dir : 4956.13' MD, 3771.85' TVD 5,256.13 3,798.00 -574.68 -1,544.66 Start Dir 41/100' : 5256.13' MD, 3798'TVD 5,440.04 3,802.24 -755.20 -1,578.86 End Dir : 5440.04' MD, 3802.24' TVD 6,005.32 3,779.00 -1,310.13 -1,683.99 Start Dir 41/100' : 6005.32' MD, 3779'TVD 6,127.01 3,770.10 -1,429.92 -1,703.24 End Dir : 6127.01' MD, 3770.1' TVD 6,232.59 3,759.00 -1,534.01 -1,717.00 Start Dir 41/100' : 6232.59' MD, 3759'TVD 6,312.33 3,751.99 -1,612.96 -1,725.68 End Dir : 6312.33' MD, 3751.99' TVD 8,070.34 3,627.91 -3,359.85 -1,879.23 Start Dir 40/100' : 8070.34' MD, 3627.91'TVD 8,109.02 3,625.71 -3,398.32 -1,882.61 End Dir :8109.02' MD, 3625.71' TVD 9,409.02 3,569.00 -4,692.10 -1,996.26 Start Dir 40/100' : 9409.02' MD, 3569'TVD 9,575.93 3,570.58 -4,858.57 -2,006.87 End Dir : 9575.93' MD, 3570.58' TVD 9,807.63 3,585.07 -5,089.63 -2,016.04 Start Dir 40/100' : 9807.63' MD, 3585.07'TVD 9,938.42 3,587.45 -5,220.19 -2,022.63 End Dir : 9938.42' MD, 3587.45' TVD 11,088.42 3,557.35 -6,367.65 -2,092.81 Start Dir 41/100' : 11088.42' MD, 3557.35'TVD 11,133.36 3,556.76 -6,412.48 -2,095.94 End Dir : 11133.36' MD, 3556.76' TVD 13,158.41 3,557.00 -8,431.34 -2,254.14 Start Dir 41/100' : 13158.41' MD, 3557'TVD 13,374.25 3,540.84 -8,645.80 -2,269.73 End Dir : 13374.25' MD, 3540.84' TVD 13,524.59 3,518.35 -8,794.12 -2,279.68 Start Dir 4°/100' : 13524.59' MD, 3518.35'TVD 13,733.68 3,502.25 -9,001.92 -2,293.82 End Dir : 13733.68' MD, 3502.25' TVD 14,508.68 3,499.00 -9,775.07 -2,347.20 Total Depth : 14508.68' MD, 3499' TVD 11/11/2019 5:38:51PM Page 10 COMPASS 5000.15 Build 91 N 7 O O O O N N C O � U rrrr a a 3 N w L) It O N M N d �M d O � a x r 2 z o ? N Z a + r+ N « O p0 m T c w o> J O Z N N 3 N w y poi Q s lJJ 0 t.7 ■\ ME E i a N m U M i ■ rnr L vii Q c aM°o mI- o r. C ' M W 2, a cacl) O nl."O�2 v�azd N m m Q Q ClG �! ■� 'A a y a u00i o a U W N V ■= p o��N Nv nQ1J r'L� a Q 3 i N o��ssomQo aid �,�, i N : =S 12 0 Cd A N L .� 2 d M � M N C� N C C C C ; a_ m Q o c a g cIL v o god11,£�� _ (� Q Z .2Uw�20W0U0a �CL 0 (7> ) ia co 'o Q m Q r o GL s, m u d cn N N N N N N N N N N N N N N N N N N N N N N N N N N N m N N N N N m m m m m N N N N N N m m m m m m N N N N N N m m m m m m N N N N N N m m m m m m N N m m a a a a a a a a a a a a a a a a a a a a a a a a a 0- 0 0 a c c c c c c c c c N E O O a) _O a) c- O N '� O 'c2 O U O p U O `O U O `O U O m 7 U (6 U C N U C (` U (6 U (6 U C m U C (6 U C (` U C (0 00 E LL 0- m Q. 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Then click on the appropriate arrow button to transform the points to the desired coordinate system. < Back Finish Cancel Help TRANSMITTAL LETTER CHECKLIST WELL NAME: M P('L M — a L�- PTD: _ a 19 — d co _✓Development — Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: _M POI h -f' POOL: JAG Ir'0. 2I�' Q t Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. API No. 50- (If last two digits Production should continue to be reported as a fimction of the original in API number are API number stated above. between 60-69) Per Statute AS 31.05.030(d)(2)(13) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 In accordance with 20 AAC 25.005(f), all records, data and logs Pilot Hole acquired for the pilot hole must be clearly differentiated in both well name ( PIS and API number (50-___7 - from records, data and logs acquired for well namD on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Exception Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (Com an Name) 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 sam les are first caught and 10' sample intervals throutar et zones. Please note the following special condition of this permit: Non -Conventional production or production testing of coal bed methane is not allowed for (name of well) until after (Compare Name) has Well designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Qmpany Name must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Compare Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(13) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 _ Well Name: MILNE PT UNIT M-24 _ _ -- Program DEV _ _-_ Well bore seg ❑ PTD#:2191600 Company Hil_corp Alaska LLC Initial Class/Type DEV/PEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate_ Yes 3 Unique well name and number - - - - - Yes 4 Well located in a defined pool - Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells_ Yes - 7 Sufficient acreage available in drilling unit Yes - - 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit Gan be issued without conservation order Yes Appr Date Permit can be issued without administrative approval Yes �12 13 Can permit be approved before 15 -day wait Yes DLB 11/14/2019 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA_ 15 All wellswithin1/4 mile area of review identified (For service well only) - - NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) NA 18 Conductor string provided Yes 20_" conductor set at 80 ft Engineering 19 �20 Surface casing protects all known USDWs NA No aquifers .. . CMT vol_ adequate to circulate on conductor_ & surf csg Yes 9 5/8" surface casing will have 2 stage cement job. ES at 2500 ft. 21 CMT vol_ adequate to tie-in long string to surf csg_ Yes - - - 22 CMT will cover all known -productive horizons Yes - 23 Casing designs adequate for C, T, B &_permafrost Yes BTC ca_Ic_s are provided. 24 Adequate tankage or reserve pit Yes - - Rig have steel pits. If a re -drill, has_a 10-403 for abandonment been approved NA �25 26 Adequate wellbore separation proposed Yes 27 If_diverter required, does it meet _regulations Yes Doyon 14 has 16" diverter_line... will drill surface hole. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes GLS 11/21/2019 BOPEs, do they meet regulation - Yes Innovation rig drilling production lateral ... 13 5/8" BOPE 50000 psi WP �29 30 BOPE press rating appropriate; test to _(put psig in comments)_ Yes MASP= 1291 psi _Will test BOPE to 3000 psi 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown No Doyon 14 drilling surface hole... Move off then Innovation to drill production lateral. 33 Is presence of H2S gas probable No 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen_ sulfide measures Yes H2S not anticipated from drilling of offset wells; however, rig will have H2S sensors and alarms. Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas zones NA DLB 11/14/2019 138 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports_ [exploratory only] NA_ Geologic Engineering Public Doyon 14 drilling surface hole only. Planned OP shutdown followed by Innovation drilling lateral. GIs Commissioner: Date: Commissioner: Date `Commis ' ne� Date 6