The URL can be used to link to this page

Home My WebLink About220-0571. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP Swap 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 15,500 feet N/A feet true vertical 3,947 feet N/A feet Effective Depth measured 15,241 feet 6,257 feet true vertical 3,953 feet 3,789 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 / EUE 8rd 5,185' 3,504' Packers and SSSV (type, measured and true vertical depth)BOT SLZXP LTP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: Hilcorp Alaska LLC WINJ WAG 0 Water-Bbl MD 143' 2,077' 6,429' TVD 143' 2,345 Oil-Bbl measured true vertical Packer 4-1/2" 6,268' 15,244' Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 2890 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 220-057 50-029-23684-00-00 Plugs ADL025515, ADL025517, ADL025906 & ADL0315848 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-408 359 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com Size 450 MILNE PT UNIT I-38 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1,016 Gas-Mcf 300 Casing Pressure Tubing Pressure 397 N/A measured 6,268' 8,987' N/A Tieback Liner Casing Conductor Length 143' 2,077' 4,352' Surface Surface 20" 9-5/8" 9-5/8" 7-5/8" 9,020psi 1,839' 3,802' 3,790' 3,090psi 4,790psi Burst N/A 6,870psi 5,750psi 6,890psi 8,540psi 777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 4,760psi 3,947' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 2:35 pm, Sep 28, 2021 Chad Helgeson (1517) 2021.09.28 13:11:33 - 08'00' SFD 9/28/2021MGR05OCT2021 RBDMS HEW 9/29/2021 DSR-9/28/21 Well Name Rig API Number Well Permit Number Start Date End Date MP I-38 ASR #1 50-029-23684-00-00 220-057 9/2/2021 9/4/2021 Continue running in hole with Summit ESP assembly picking up 3.5, 9.3# EUE L-80 production tbg to 5,173 ft. Made up hanger and pups, P/up wt 59k slack off wt. 27k,Make up penetrate connection In hanger and make splice and connection to hanger, Take readings intake temp at 71.6 deg, f. intake pressure 905 psi, motor temp 73.1deg f., x vibration = .019 , Y vibration - .023 , discharge pressure 925 psi, Phase to phase 3.5 omhs, Phase to ground 1.20 gig at 1,000 volts for 3 minutes. Land hanger in tubing spool with 27k down on hanger, set BPV & run in lock down screws, End of assembly at 5,184' SLM. Rigging down to access well head to ND BOP and NU tree. Pull carrier off mud boat, set out rig floor, riser and BOPs, Test cable, Good. Nipple up production tree. PT to 500 / 5K psi, Good test, Test cable, Test Good. Pull BPV, Shut in and install night cap. Set out cellar house, RDMO ASR #1. to A pad. 9/4/2021 - Saturday 9/5/2021 - Sunday No operations to report. 9/3/2021 - Friday Continue rigging up to POH with Baker ESP completion. Shell test BOPE 250/2,500 psi,Test 11" 5K BOPE with fresh water and 3 1/2" Test joint, 250 / 2,500 psi. 1 fail on choke manifold, grease and work valves, pass. Perform accumulator draw down test, test gas alarm system. Test witnessed by Lou Laubenstein, AOGCC inspector. Draw down test = start 3,100 psi, ending pressure 1,650 psi. recovered 200 psi in 13 seconds, full recovery in 61 seconds. Blow down and rig down BOPE test equipment. Rig up to pull hanger. Open IA had slight gas blow, pump 15 bbl #8.3 source water down IA, pump 40 bbl down tubing, well on vac, Pull hanger to rig floor, remove cannon clamps and test cable below hanger, grounded. POH with 3 1/2", #9.3, l-80, EUE 8rd tubing, Baker ESP completion, spooling cable to spooler. Break down and lay down Baker pump assembly, Upper tandem pump section very tight to turn, discharge port showed signs of heat, no other damage to tools or cable observed. 91 canon clamps recovered. Clear floor and pipe racks, prep to pick up Summit ESP pump assembly. Pick up tools and rig up to run Summit ESP assembly, pick up Summit ESP assembly. RIH with Summit ESP assembly on 3 1/2", #9.3, l-80, EUE 8rd tubing @ 239'. 9/1/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/2/2021 - Thursday Move in, spot and rig up LRS pumping equipment for well kill. Heat up diesel, test lines 250 / 3,000 psi. Bleed gas from tubing (250 psi) and annulus. Pump 20 bbl warm diesel followed with 240 bbl hot water down IA @ 4 bpm @ 0 psi, no returns from tubing, OA pressure increased from 0 psi to 583 psi while pumping down IA. Pump 45 bbl down tubing @ 3 bpm @ 0 psi, with no returns from IA, OA pressure reduced from 583 psi to 482 psi while pumping down tubing. Shut down pumping, observed well on vac. Set BPV. Remove scaffolding, Well support blow down lines, remove choke skid and well kill equipment, disconnect pumping lines and spot mud boat. Move in spot crane, nipple down tree. Inspect well head and hanger prep for nipple up BOPE. spot pits, install BPO's, well house and rig floor. Lay containment, spot in ASR carrier and level, spot camps and fill with water. Rig up rig, install rack pins, torque BOPE flanges, rig up choke and kill lines, set in and rig up stairs, spot in pit module, rig up pumping and control lines. Rigging up, function test BOPE. make up riser spools to rig floor, set in flow line and rig up pits, pick up floor tools, set in and rig up pipe racks. Hang ESP sheave and environmental trunk, spot ESP spooler, Shell pressure test BOPE to 2,500 psi. Well Name Rig API Number Well Permit Number Start Date End Date MP I-38 ASR #1 50-029-23684-00-00 220-057 9/2/2021 9/4/2021 Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. No operations to report. 9/7/2021 - Tuesday 9/6/2021 - Monday _____________________________________________________________________________________ Revised By: DH 9/22/2021 SCHEMATIC Milne Point Unit Well: MPU I-38 Last Completed: 9/4/2021 PTD: 220-057 TD =15,500’(MD) /TD =3,953’(TVD) 4 20” Orig. KB Elev.: 60.4’ / GL Elev.: 33.8’ 7-5/8” 13 7 8&9 4 14 9-5/8” 1 2 3 See Screen/ Solid Liner Detail PBTD =15,241’(MD) /PBTD =3,947’(TVD) 9-5/8” ‘ES’ Cementer @ 2,177’ MD 5&6 4-1/2” Shoe @ 15,241’ 10 11 12 3-1/2”CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5# / X25 / Weld N/A Surface 143’ N/A 9-5/8" Surface 47 / L-80 / TXP 8.525 Surface 2,077’ 0.0732 9-5/8” Surface 40 / L-80 / TXP 8.679 2,077’ 6,429’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 6,268’ 0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 6,257’ 15,244’ 0.0149 TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE-8rd 2.992 Surface 5,185’ 0.0087 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 – Lead – 612 sx / Tail – 400 sx Stg 2 – Lead – 587 sx / Tail – 264 sx 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 490’ Max Hole Angle = 93° TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23684-00-00 Completion Date: 8/11/2020 ESP Swap by ASR #1: 9/4/2021 4-1/2” Blank SCREEN LINER DETAIL Jts Top (MD) Btm (MD) 3 6,283’ 6,403’ 24 7,089’ 8,065’ 4 8,771’ 8,935’ 3 10,903’ 11,027’ 2 11,111’ 11,194’ 2 11,278’ 11,360’ 7 11,569’ 11,854’ 6 12,103’ 12,349’ 1 15,200’ 15,241’ JEWELRY DETAIL No. Top MD Item ID 1 110’ Sta 2: GLM, Patco, 3-1/2” x 1” BK-2 2.915” 2 4,438’ Sta 1: GLM, Patco, 3-1/2” x 1” BK-2 2.915” 3 4,497’ 3-1/2” XN Nipple, 2.75” no go 2.750” 4 5,113’ Discharge Head: 3-1/2 8RD, 513, MS1-015 5 5,114’ Pump 1: Series 538 090 Stage SJ4200 6 5,137’ Adapter Kit 400 REDA Intake .875 In 7 5,138’ Gas Separator: Tandem, 400 Series H2X Stainless 8 5,143’ Upper Tandem Seal: 513 Series, BPBSL, Premium, A/R 9 5,152’ Lower Tandem Seal: 513 Series, BPBSL, Premium, A/R 10 5,161’ Motor: 562 series KMS2, 300HP/3255V/57A, 10 Rotor 11 5,181’ High Temp Motor Gauge w/ Centralizer – Bottom @ 5,185’ 12 6,257’ BOT SLZXP LTP / Liner Hanger 7-5/8” x 9-5/8” 7.375” 13 6,278’ 7” H563 x 4.5” Hyd 625 XO 3.840” 14 15,241’ Solid Guide Shoe - 4-1/2” SCREEN LINER DETAIL Jts Top (MD) Btm (MD) 17 6,403’ 7,089’ 17 8,065’ 8,771’ 47 8,935’ 10,903’ 2 11,027’ 11,111’ 2 11,194’ 11,278’ 5 11,360’ 11,569’ 6 11,854’ 12,103’ 68 12,349’ 15,200’ FLOOR SAFTY VALVES: BOP STACK: STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Supry Z� BOPE Test Report for: MILNE PT UNIT I-38 Comm Contractor/Rig No.: Hilcorp ASR I PTD#: 2200570 , DATE: 9/3/2021 Inspector Lou Laubenstein - Insp Source Operator: Hilcorp Alaska, LLC P/F Operator Rep: Ed Hooter Rig Rep: Aaron Haberthor Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopLOL210905185939 NA No. Valves 15 - 321-408 Rams: Annular: Valves: — - - MASP: — -- NA Type Test: [NIT yP 1 Al" , 250/2000 - 250/2000 " 250/2000 715 � Related Insp No: P Ball Type __1 TEST DATA #1 Rams 1 - 2-7/8 x 5" MISC. INSPECTIONS: Hydraulic Chokes 1 MUD SYSTEM: ACCUMULATOR SYSTEM: __ ___I P P/F Visual Alarm Time/Pressure P/F Location Gen.: P_ Trip Tank NA - NA System Pressure 3100 P Housekeeping: P Pit Level Indicators P P ' Pressure After Closure 1650 P PTD On Location -P Flow Indicator P P - 200 PSI Attained 13 P " Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 61 P ' Well Sign P _' H2S Gas Detector P _ P Blind Switch Covers: yes _ P Dr]. Rig P _' MS Misc NA NA Nitgn. Bottles (avg): 4 *_2000 P Hazard Sec. P '_ (Valid for Coil Rigs Only) ACC Misc 0—NA— NA_Misc Mise NA Choke Ln. Valves 1 ' 2-1/16" P FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 0 _ NA- Stripper 0 NA No. Valves 15 - FP Lower Kelly__ 0 NA Annular Preventer 1 Al" P Manual Chokes 1 P Ball Type __1 P #1 Rams 1 - 2-7/8 x 5" VB- P Hydraulic Chokes 1 P " Inside BOP __ ___I P #2 Rams 1 Blinds P CH Misc 0 NA FSV Misc 0 NA #3 Rams 0 NA #4 Rams 0 NA - #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 ' 2-1/16" P Quantity P/F HCR Valves 1 2-1/16" P - Inside Reel Valves _ _ 0 _ NA Kill Line Valves ------- 2 2-1/16" ------- P - Check Valve 0 NA BOP Misc 0 NA Number of Failures: 3 ✓ Test Results Test Time 3.5 Remarks: Test was completed with a 3 1/2" test joint, Choke Valves C4, C7 and C11 failed and passed retest 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 15,500'N/A Casing Collapse Conductor N/A Surface 4,760psi Surface 3,090psi Tieback 4,790psi Liner 8,540psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025515, ADL025517, ADL025906 & ADL0315848 220-057 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 MILNE POINT / SCHRADER BLUFF OIL 50-029-23684-00-00 Hilcorp Alaska LLC Length Size 3,947' 15,241' 3,953' MD C.O. 477.05 PRESENT WELL CONDITION SUMMARY 715 N/A MILNE PT UNIT I-38 143'143' TVD Burst 5,191' 9,020psi N/A 6,890psi 6,870psi 5,750psi 1,839'2,077' 6,429' 4-1/2" 143'20" 9-5/8" 9-5/8" 2,077' 4,352' Authorized Signature: 9/1/2021 3-1/2" Perforation Depth MD (ft): See Schematic See Schematic Perforation Depth TVD (ft): 3,802' 3,790' 6,257 MD/ 3,789 TVD and N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 15,244' 7-5/8"6,268' 9.3# / L-80 / EUE 8rd BOT SLZXP and N/A 6,268' 8,987' 3,947' Tubing Grade: Tubing MD (ft): dgorm@hilcorp.com Tubing Size: ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:40 pm, Aug 19, 2021 321-408 Chad Helgeson (1517) 2021.08.19 14:01:28 - 08'00' DSR-8/19/21 715 BOPE test to 10-404 MGR19AUG2021 2000 psi. Annular to 2000 psi. SFD 8/20/2021 JLC 8/26/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.26 10:39:41 -08'00' RBDMS HEW 8/27/2021 ESP RWO Well: MP I-38 2021 ESP RWO Well Name:MPU I-38 API Number:50-029-23684-00 Current Status:SI Producer (Failed ESP)Pad:I-Pad Estimated Start Date:September 1st, 2021 Rig:ASR#1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:220-057 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:Job Type:ESP RWO Current Bottom Hole Pressure: 1,100 psi @ 3,850’ TVD Estimated BHP 8-19-2021 5.5 ppg EMW Maximum Expected BHP:1,100 psi @ 3,850’ TVD MPSP:715 psi (0.1 psi/ft gas gradient) Max Inclination:91° @ 6,826’ MD Horizontal @ 6,635’ MD Max Dogleg:5.58°/100’ @ 3,757’ TVD Brief Well Summary: MPU I-38 was drilled and completed as a Schrader Bluff producer with an ESP installed in August 2020. The ESP grounded out and failed in January 2021 and the ESP was changed out on 1/22/2021. The ESP grounded out on 8-18-2021. Notes Regarding the Well & Design x 9-5/8” Casing MIT @ 6,112’ to 1,000 psig passed on 8/11/2020 x 3/8” Cap String Installed x 2021 ESP shorted to ground requiring workover. x Offset Injector Support o I-37 Objective: x Pull Failed ESP Completion with 3/8” Cap String x Run new ESP Completion with 3/8” Cap String Pre-Workover Prep Procedure: 1. RD well house and flowlines. Clear and level area around well. 2. RU Little Red Services Pump. Setup reverse out skid, returns tank, and additional upright tanks as needed. 3. Pressure test lines to 3,000 psi. 4. Review kill plan with Engineer based on current well conditions. 5. Pump 220 bbls of 8.3 ppg source water down the IA with the TBG open to the pit. 6. Pump 40 bbls of 8.3 ppg source water down tubing with the IA open to the pit. 7. Confirm well is dead. 8. RD Little Red Services Pump and reverse out skid. 9. Clear and level pad area in front of well. Spot rig mats and containment. 10. RU crane. Set BPV. ND Tree. NU 11” BOPE. RD crane. a. Make scribe mark on tree for orientation for re-installation. -00 ESP RWO Well: MP I-38 2021 ESP RWO b. Function test all prior to arrival of AOGCC inspectors. 11. NU BOPE house. Spot mud boat Workover Procedure: 12. MIRU ASR #1 Workover rig, ancillary equipment and lines to returns tank. 13. Pull BPV after confirming zero surface wellhead pressure. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.3 ppg source-water prior to pulling BPV. Set TWC. 14. Test BOPE to 250psi Low/ 2,000 psi High, annular to 250psi Low/ 2,000 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR rams on 3-1/2” test joint. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 15. Bleed any pressure off casing to returns tank. Pull TWC. 16. RU spooler to pull ESP Cable. 17. MU landing joint or spear and PU on the tubing hanger. a. PU weight estimated 45 Klbs. b. If needed, circulate (long or reverse) source-water, and/or baraclean pill prior to laying down the tubing hanger. 18. Recover the tubing hanger. a. Evaluate pulled tubing hanger for possible thread damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. b. Check the ESP Cable after the hanger is removed. If cable is grounded continue POH, if Cable tests good Contact Engineer on test results, option to re-land hanger. 19. POOH and lay down the 3-1/2” tubing and ESP completion. (plan to re-run 3-1/2” TBG) a. Cable clamped every joint first 15 jts and every other joint after to surface. b. 3/8” Cap String installed c. Inspect and re-use 3-1/2” TBG and clamps. d. Re-use all gas-lift mandrels and XN nipple. e. Dispose of ESP cable, re-use cap string f. Prep ESP for DIFA (Dismantle Inspection and Failure Analysis). g. Note any sand, scale, or corrosion on the tubulars or ESP on the morning report. 20. PU new ESP and RIH on 3-1/2” 9.3# 8rd-EUE L-80 tubing w/ 3/8” Cap string. Set base of ESP assembly at ±5,190’ MD. a. Upper 3-1/2”x 1” Side-pocket GLM @ ±200’ MD with 0.25” OV b. 3-1/2” tubing c. Lower 3-1/2”x 1” Side-pocket GLM with Dummy GLV ESP RWO Well: MP I-38 2021 ESP RWO d. 1 joint of 3-1/2” tubing e. 3-1/2” XN (2.75” No-Go) Nipple f. 19 joints of 3-1/2” tubing g. Downhole gauge for discharge temperature and pressure. h. ESP (TBD) i. ESP (TBD) j. Tandem Gas Separator k. Motor l. Motor gauge m. Base of ESP centralizer @ ±5,190’ MD 21. Land tubing hanger. RILDS. Lay down landing joint. Note slack-off weight on tally. 22. Set BPV. Post-Rig Procedure: 23. RD mud boat. RD BOPE house. Move to next well location. 24. RU crane. ND BOPE. 25. NU existing tree. Test tubing hanger void to 500 psi low/5,000 psi high. 26. Pull BPV. 27. RD crane. Move returns tank and rig mats to next well location. 28. Replace gauge(s) if removed. 29. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Blank RWO MOC Form _____________________________________________________________________________________ Revised By: TDF 2/4/2021 SCHEMATIC Milne Point Unit Well: MPU I-38 Last Completed: 1/21/2021 PTD: 220-057 TD =15,500’ (MD) / TD =3,953’ (TVD) 4 & 5 20” Orig. KB Elev.: 60.4’ / GL Elev.: 33.8’ 7-5/8” 14 8 9 & 10 4 15 9-5/8” 1 2 3 See Screen/ Solid Liner Detail PBTD =15,241’(MD) / PBTD =3,947’(TVD) 9-5/8” ‘ES’ Cementer @ 2,177’ MD 6 & 7 4-1/2” Shoe @ 15,241’ 11 12 13 3-1/2”CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5# / X25 / Weld N/A Surface 143’ N/A 9-5/8" Surface 47 / L-80 / TXP 8.525 Surface 2,077’ 0.0732 9-5/8” Surface 40 / L-80 / TXP 8.679 2,077’ 6,429’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 6,268’ 0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 6,257’ 15,244’ 0.0149 TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE-8rd 2.992 Surface 5,191’ 0.0087 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 – Lead – 612 sx / Tail – 400 sx Stg 2 – Lead – 587 sx / Tail – 264 sx 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 490’ Max Hole Angle = 93° TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23684-00-00 Completion Date: 8/11/2020 4-1/2” SCREEN LINER DETAIL Jts Top (MD) Btm (MD) 3 6,283’ 6,403’ 24 7,089’ 8,065’ 4 8,771’ 8,935’ 3 10,903’ 11,027’ 2 11,111’ 11,194’ 2 11,278’ 11,360’ 7 11,569’ 11,854’ 6 12,103’ 12,349’ 1 15,200’ 15,241’ JEWELRY DETAIL No. Top MD Item ID 1 110’ Sta 2: Patco 3.5" X 1" BK-2 GLM EUE W/ 1" DPSOV 2.915” 2 4,438’ Sta 1: Patco 3.5" X 1" BK2 GLM EUE W 1" Dummy 2.920” 3 4,497’ 3-1/2” XN Nipple, 2.75” no go 2.750” 4 5,111.7’ Discharge Head: B/O PMP 513 3.5X8 EUE1040 5 5,112’ Zenith ported Sub Press Port 6 5,113’ Pump 2: 538PMSXD 093 FLEX47 H6 FER 7 5,135’ Pump 1: 538PMSXD 20 GINSPHH H6 FER 8 5,145’ Gas Separator: GAS-MASTER EXTREME 538GS 9 5,150’ Upper Tandem Seal: GSBDB H6 SB/AB PFSA 10 5,157’ Lower Tandem Seal: GSBDB H6 SB/AB PFSA 11 5,164’ Motor: 562XP 300/2090/88_250/1740 12R 12 5,186’ Motor Gauge w/ Centralizer – Bottom @ 5,191’ 13 6,257’ BOT SLZXP LTP / Liner Hanger 7-5/8” x 9-5/8” 7.375” 14 6,278’ 7” H563 x 4.5” Hyd 625 XO 3.840” 15 15,241’ Solid Guide Shoe - 4-1/2” SCREEN LINER DETAIL Jts Top (MD) Btm (MD) 17 6,403’ 7,089’ 17 8,065’ 8,771’ 47 8,935’ 10,903’ 2 11,027’ 11,111’ 2 11,194’ 11,278’ 5 11,360’ 11,569’ 6 11,854’ 12,103’ 68 12,349’ 15,200’ _____________________________________________________________________________________ Revised By: TDF 8/19/2021 PROPOSED Milne Point Unit Well: MPU I-38 Last Completed: 1/21/2021 PTD: 220-057 TD =15,500’ (MD) / TD =3,953’ (TVD) 4 & 5 20” Orig. KB Elev.: 60.4’ / GL Elev.: 33.8’ 7-5/8” 14 8 9 & 10 4 15 9-5/8” 1 2 3 See Screen/ Solid Liner Detail PBTD =15,241’(MD) / PBTD =3,947’(TVD) 9-5/8” ‘ES’ Cementer @ 2,177’ MD 6 & 7 4-1/2” Shoe @ 15,241’ 11 12 13 3-1/2”CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5# / X25 / Weld N/A Surface 143’ N/A 9-5/8" Surface 47 / L-80 / TXP 8.525 Surface 2,077’ 0.0732 9-5/8” Surface 40 / L-80 / TXP 8.679 2,077’ 6,429’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 6,268’ 0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 6,257’ 15,244’ 0.0149 TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE-8rd 2.992 Surface ±5,190’ 0.0087 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 – Lead – 612 sx / Tail – 400 sx Stg 2 – Lead – 587 sx / Tail – 264 sx 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 490’ Max Hole Angle = 93° TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23684-00-00 Completion Date: 8/11/2020 4-1/2” SCREEN LINER DETAIL Jts Top (MD) Btm (MD) 3 6,283’ 6,403’ 24 7,089’ 8,065’ 4 8,771’ 8,935’ 3 10,903’ 11,027’ 2 11,111’ 11,194’ 2 11,278’ 11,360’ 7 11,569’ 11,854’ 6 12,103’ 12,349’ 1 15,200’ 15,241’ JEWELRY DETAIL No. Top MD Item ID 1 ±200’ Sta 2: GLM 2.915” 2 ±4,438’ Sta 1: GLM 2.920” 3 ±4,497’ 3-1/2” XN Nipple, 2.75” no go 2.750” 4 ±5,110’ Discharge Head: 5 ±5,112’ Zenith ported Sub Press Port 6 ±5,113’ Pump 2: 7 ±5,135’ Pump 1: 8 ±5,145’ Gas Separator: 9 ±5,150’ Upper Tandem Seal: 10 ±5,157’ Lower Tandem Seal: 11 ±5,164’ Motor: 12 ±5,186’ Motor Gauge w/ Centralizer – Bottom @ ±5,190’ 13 6,257’ BOT SLZXP LTP / Liner Hanger 7-5/8” x 9-5/8” 7.375” 14 6,278’ 7” H563 x 4.5” Hyd 625 XO 3.840” 15 15,241’ Solid Guide Shoe - 4-1/2” SCREEN LINER DETAIL Jts Top (MD) Btm (MD) 17 6,403’ 7,089’ 17 8,065’ 8,771’ 47 8,935’ 10,903’ 2 11,027’ 11,111’ 2 11,194’ 11,278’ 5 11,360’ 11,569’ 6 11,854’ 12,103’ 68 12,349’ 15,200’ Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: August 19 th, 2021 Subject: Changes to Approved Sundry Procedure for Well MP I-38 Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date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y Jody Colombie at 3:00 pm, Feb 05, 2021 &KDG+HOJHVRQ SFD 2/9/2021RBDMS HEW 2/5/2021 DSR-2/5/21MGR30JUL2021 BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϮͬϰͬϮϬϮϭ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh/Ͳϯϴ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭͬϮϭͬϮϬϮϭ Wd͗ϮϮϬͲϬϱϳ dсϭϱ͕ϱϬϬ͛ ;DͿͬ dсϯ͕ϵϱϯ͛ ;dsͿ ϮϬ͟ KƌŝŐ͘<ůĞǀ͗͘ϲϬ͘ϰ͛ͬ'>ůĞǀ͗͘ϯϯ͘ϴ͛ ϳͲϱͬϴ͟ ϵͲϱͬϴ͟ 6HH 6FUHHQ 6ROLG /LQHU 'HWDLO Wdсϭϱ͕Ϯϰϭ͛;DͿͬWdсϯ͕ϵϰϳ͛;dsͿ ´ µ(6¶ &HPHQWHU# ¶0' ϰͲϭͬϮ͟ ^ŚŽĞΛ ϭϱ͕Ϯϰϭ͛ ϯͲϭͬϮ͟^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϭϮϵ͘ϱηͬyϮϱͬtĞůĚ Eͬ ^ƵƌĨĂĐĞ ϭϰϯ͛ Eͬ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϳͬ>ͲϴϬͬdyW ϴ͘ϱϮϱ ^ƵƌĨĂĐĞ Ϯ͕Ϭϳϳ͛ Ϭ͘ϬϳϯϮ ϵͲϱͬϴ͟ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬdyW ϴ͘ϲϳϵ Ϯ͕Ϭϳϳ͛ ϲ͕ϰϮϵ͛ Ϭ͘Ϭϳϱϴ ϳͲϱͬϴ͟ dŝĞďĂĐŬ Ϯϵ͘ϳͬ>ͲϴϬͬ,ǇĚϱϮϭ ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϲ͕Ϯϲϴ͛ Ϭ͘Ϭϰϱϵ ϰͲϭͬϮ͟ >ŝŶĞƌϮϱϬђ^ĐƌĞĞŶƐ ϭϯ͘ϱͬ>ͲϴϬͬ,ǇĚϲϮϱ ϯ͘ϵϮϬ ϲ͕Ϯϱϳ͛ ϭϱ͕Ϯϰϰ͛ Ϭ͘Ϭϭϰϵ dh/E'd/> ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬhͲϴƌĚ Ϯ͘ϵϵϮ ^ƵƌĨĂĐĞ ϱ͕ϭϵϭ͛ Ϭ͘ϬϬϴϳ KWE,K>ͬDEdd/> ŽŶĚƵĐƚŽƌ цϮϳϬĨƚϯ ϭϮͲϭͬϰΗ ^ƚŐϭʹ>ĞĂĚʹϲϭϮƐǆͬdĂŝůʹϰϬϬƐǆ ^ƚŐϮʹ>ĞĂĚʹϱϴϳƐǆͬdĂŝůʹϮϲϰƐǆ ϴͲϭͬϮ͟ ĞŵĞŶƚůĞƐƐ^ĐƌĞĞŶƐ>ŝŶĞƌŝŶϴͲϭͬϮ͟ŚŽůĞ t>>/E>/Ed/KE d/> <KWΛϰϵϬ͛ DĂǆ,ŽůĞŶŐůĞсϵϯΣ dZΘt>>, dƌĞĞ ĂŵĞƌŽŶϯϭͬϴΗϱDǁͬϰͲϭͬϭϲ͟ϱDĂŵĞƌŽŶtŝŶŐ tĞůůŚĞĂĚ ĂŵĞƌŽŶϭϭ͟ϱ<ǆƐůŝƉůŽĐŬďŽƚƚŽŵǁͬ;ϮͿϮͲϭͬϭϲ͟ϱ<ŽƵƚƐ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϲϴϰͲϬϬͲϬϬ ŽŵƉůĞƚŝŽŶĂƚĞ͗ϴͬϭϭͬϮϬϮϬ ϰͲϭͬϮ͟^ZE>/EZd/> :ƚƐ dŽƉ;DͿ ƚŵ;DͿ ϯ ϲ͕Ϯϴϯ͛ ϲ͕ϰϬϯ͛ Ϯϰ ϳ͕Ϭϴϵ͛ ϴ͕Ϭϲϱ͛ ϰ ϴ͕ϳϳϭ͛ ϴ͕ϵϯϱ͛ ϯ ϭϬ͕ϵϬϯ͛ ϭϭ͕ϬϮϳ͛ Ϯ ϭϭ͕ϭϭϭ͛ ϭϭ͕ϭϵϰ͛ Ϯ ϭϭ͕Ϯϳϴ͛ ϭϭ͕ϯϲϬ͛ ϳ ϭϭ͕ϱϲϵ͛ ϭϭ͕ϴϱϰ͛ ϲ ϭϮ͕ϭϬϯ͛ ϭϮ͕ϯϰϵ͛ ϭ ϭϱ͕ϮϬϬ͛ ϭϱ͕Ϯϰϭ͛ :t>Zzd/> EŽ͘ dŽƉD /ƚĞŵ / ϭ ϭϭϬ͛ ^ƚĂϮ͗WĂƚĐŽϯ͘ϱΗyϭΗ<ͲϮ'>DhtͬϭΗW^Ks Ϯ͘ϵϭϱ͟ Ϯ ϰ͕ϰϯϴ͛ ^ƚĂϭ͗WĂƚĐŽϯ͘ϱΗyϭΗ<Ϯ'>DhtϭΗƵŵŵǇ Ϯ͘ϵϮϬ͟ ϯ ϰ͕ϰϵϳ͛ ϯͲϭͬϮ͟yEEŝƉƉůĞ͕Ϯ͘ϳϱ͟ŶŽŐŽ Ϯ͘ϳϱϬ͟ ϰ ϱ͕ϭϭϭ͘ϳ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ͬKWDWϱϭϯϯ͘ϱyϴhϭϬϰϬ ϱ ϱ͕ϭϭϮ͛ ĞŶŝƚŚƉŽƌƚĞĚ^ƵďWƌĞƐƐWŽƌƚ ϲ ϱ͕ϭϭϯ͛ WƵŵƉϮ͗ϱϯϴWD^yϬϵϯ&>yϰϳ,ϲ&Z ϳ ϱ͕ϭϯϱ͛ WƵŵƉϭ͗ϱϯϴWD^yϮϬ'/E^W,,,ϲ&Z ϴ ϱ͕ϭϰϱ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗'^ͲD^dZydZDϱϯϴ'^ ϵ ϱ͕ϭϱϬ͛ hƉƉĞƌdĂŶĚĞŵ^ĞĂů͗'^,ϲ^ͬW&^ ϭϬ ϱ͕ϭϱϳ͛ >ŽǁĞƌdĂŶĚĞŵ^ĞĂů͗'^,ϲ^ͬW&^ ϭϭ ϱ͕ϭϲϰ͛ DŽƚŽƌ͗ϱϲϮyWϯϬϬͬϮϬϵϬͬϴϴͺϮϱϬͬϭϳϰϬϭϮZ ϭϮ ϱ͕ϭϴϲ͛ DŽƚŽƌ'ĂƵŐĞǁͬĞŶƚƌĂůŝǌĞƌʹŽƚƚŽŵΛϱ͕ϭϵϭ͛ ϭϯ ϲ͕Ϯϱϳ͛ Kd^>yW>dWͬ>ŝŶĞƌ,ĂŶŐĞƌϳͲϱͬϴ͟ǆϵͲϱͬϴ͟ ϳ͘ϯϳϱ͟ ϭϰ ϲ͕Ϯϳϴ͛ ϳ͟,ϱϲϯǆϰ͘ϱ͟,ǇĚϲϮϱyK ϯ͘ϴϰϬ͟ ϭϱ ϭϱ͕Ϯϰϭ͛ ^ŽůŝĚ'ƵŝĚĞ^ŚŽĞ Ͳ ϰͲϭͬϮ͟^ZE>/EZd/> :ƚƐ dŽƉ;DͿ ƚŵ;DͿ ϭϳ ϲ͕ϰϬϯ͛ ϳ͕Ϭϴϵ͛ ϭϳ ϴ͕Ϭϲϱ͛ ϴ͕ϳϳϭ͛ ϰϳ ϴ͕ϵϯϱ͛ ϭϬ͕ϵϬϯ͛ Ϯ ϭϭ͕ϬϮϳ͛ ϭϭ͕ϭϭϭ͛ Ϯ ϭϭ͕ϭϵϰ͛ ϭϭ͕Ϯϳϴ͛ ϱ ϭϭ͕ϯϲϬ͛ ϭϭ͕ϱϲϵ͛ ϲ ϭϭ͕ϴϱϰ͛ ϭϮ͕ϭϬϯ͛ ϲϴ ϭϮ͕ϯϰϵ͛ ϭϱ͕ϮϬϬ͛ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW/Ͳϯϴ ^Z ϱϬͲϬϮϵͲϮϯϲϴϰͲϬϬͲϬϬ ϮϮϬͲϬϱϳ ϭͬϮϬͬϮϬϮϭ ϭͬϮϭͬϮϬϮϭ ϭͬϮϮͬϮϬϮϭͲ&ƌŝĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭͬϮϬͬϮϬϮϬͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ WĞƌĨŽƌŵĞĚKWdĞƐƚĂƐĨŽůůŽǁŝŶŐ͗ŶŶƵůĂƌϮϱϬͲϮ͕ϱϬϬƉƐŝ͕sĂůǀĞƐǀZĂŵƐϮϱϬͲϮ͕ϱϬϬƉƐŝ͘'ĂƐĚĞƚĞĐƚŝŽŶĂŶĚWĞƌĨŽƌŵĞĚƚŚĞ <ŽŽŵĞǇƌĂǁŽǁŶƚĞƐƚ͘EŽĨĂŝůƵƌĞƐƌĞĐŽƌĚĞĚ͘K'ǁŝƚŶĞƐƐǁĂŝǀĞĚďǇ>ŽƵ>ĂƵďĞŶƐƚĞŝŶ͘>ͬKWdĞƐƚŝŶŐĞƋƵŝƉŵĞŶƚ͘/ ƐƚĂƚŝĐ͘WhƌǇZŽĚĂŶĚƉƵůůĞĚƚĞƐƚƉůƵŐ͘&ŽƵŶĚƉƌĞƐƐƵƌĞƵŶĚĞƌŶĞĂƚŚƚŚĞWs͘ůŽƐĞĚďůŝŶĚƐĂŶĚƉƵŵƉĞĚϭϬďďůƐŽĨ^tƚŚƌƵ WsǁŝƚŚƚŚĞĐŚĂƌŐĞƉƵŵƉ͘^ƉƵŵƉĂŶĚƚďŐǁĂƐŽŶĂǀĂĐ͘WƵůůĞĚWs͘DŽŶŝƚŽƌĞĚǁĞůůĨŽƌϭϱŵŝƐdďŐͬ/ƐƚĂƚŝĐ͘DhϯͲϭͬϮΗ >ĂŶĚŝŶŐ:ƚ͕K>^ĂŶĚƉƵůůĞĚŚĂŶŐĞƌƚŽƌŝŐĨůŽŽƌWhtϱϮŬ͘ZĞŵŽǀĞĚƉĞŶĞƚƌĂƚŽƌĂŶĚĚŝĚŶƚƐĞĞĂŶĚĚĂŵĂŐĞƚŽŝƚ͕ƵƚĐĂďůĞ ĂŶĚƚĞƐƚĞĚĨŽƵŶĚĚŽǁŶŚŽůĞƐŚŽƌƚ͘ĞͲĐŽŵƉůĞƚĞĚĂŶĚ>,ĂŶŐĞƌĂŶĚůĂŶĚŝŶŐũŽŝŶƚ͘WĞƌƉĂƌĞĚƚŽƉƵůůŽŵƉůĞƚŝŽŶ͘Zh ůĞƉŚĞŶƚdƌƵĐŬƉƵůůĞĚĐĂďůĞĂŶĚĐĂƉůŝŶĞƚŚƌƵƐŚĞĂǀĞ͘WKK,ǁŝƚŚϯͲϭͬϮhdďŐ^WŽŵƉůĞƚŝŽŶƌĞŵŽǀŝŶŐĐůĂŵƉƐĂŶĚ ƐƉŽŽůŝŶŐĐĂďůĞĂŶĚĐĂƉƐƚƌŝŶŐ͘KŶũŽŝŶƚϮϮĐĂƉƐƚƌŝŶŐǁĂƐƚǁŝƐƚĞĚĂŶĚŬŝŶŬĞĚ͘ƵƚĂŶĚƐƉůŝĐĞĚĐĂƉƐƚƌŝŶŐƐŽǁĞĐŽƵůĚĐŽŶƚŝŶƵĞ ƉƵůůŝŶŐŝƚƚŚƌƵƚŚĞƐŚĞĂǀĞ͘ŽŶƚŝƵĞĚWKK,ǁŝƚŚ^WĨͬϰ͕ϰϬϬΖŵĚƚͬϮ͕ϮϱϯΖŵĚWhtϮϳŬƌĞŵŽǀŝŶŐĐůĂŵƉƐĂŶĚƐƉŽŽůŝŶŐĐĂďůĞ ĂŶĚĐĂƉƐƚƌŝŶŐ͘EŽŝƐƐƵĞƐǁŝƚŚĐĂƉƐƚƌŝŶŐƐŝŶĐĞ͘ƌĞǁĐŚĂŶŐĞ͕ƐĞƌǀŝĐĞĂŶĚŝŶƐƉĞĐƚƌŝŐĂŶĚĞƋƵŝƉŵĞŶƚ͘ƵƌŝŶŐƚŚŝƐƚŝŵĞƚŚĞŐĞŶ ĨŽƌƚŚĞ^ƉŽŽůĞƌǁĂƐĨŽƵŶĚƚŽŶŽƚďĞƉƵƚƚŝŶŐŽƵƚĞŶŽƵŐŚƉŽǁĞƌƚŽƌƵŶƚŚĞƐƉŽŽůĞƌ͘ĐĂůůĞĚůĞĐƚƌŝĐŝĂŶƚŽĐŽŵĞǁŝƌĞŝŶƚŽƚŚĞ ϯϬϬ<ŐĞŶ͘ŽŶƚŝŶƵĞĚWKK,ǁŝƚŚ^WĨͬϮ͕ϮϱϯΖŵĚƚͬƐƵƌĨĂĐĞƌĞŵŽǀŝŶŐĐůĂŵƉƐĂŶĚƐƉŽŽůŝŶŐĐĂďůĞĂŶĚĐĂƉůŝŶĞ͘>ĂǇŽǁŶ^W ƉƵŵƉĂŶĚŵŽƚŽƌ͘ϭƐƚƉƵŵƉǁŽƵůĚŶŽƚƚƵƌŶϮŶĚƉƵŵƉƐƉƵŶĨƌĞĞůǇ͘DŽƚŽƌĂŶĚƐĞĂůƐǁŚĞƌĞďůƵŝŶŐĨƌŽŵŚĞĂƚ͘KŝůŝŶƐĞĂůƐ ůŽŽŬĞĚŶŽƌŵĂů͘ZĞŵŽǀĞĂŶĚůŽĂĚŽůĚĞƋƵŝƉŵĞŶƚ͕ůŽĂĚƚĂůůǇĂŶĚƉƌĞƉƚŽWhͬDhŶĞǁ^WĐŽŵƉůĞƚŝŽŶ͘WhͬDhĂŶĚƐĞƌǀŝĐĞ ŶĞǁ^WĐŽŵƉůĞƚŝŽŶĞƋƵŝƉŵĞŶƚ͘ƚĞƐƚĐĂďůĞǁĂƐŐŽŽĚ͘ ϭͬϮϭͬϮϬϮϬͲdŚƵƌƐĚĂǇ W:^D͕ŚĞĐŬĞĚĨŝƵůĚƐĂŶĚƐĞƌǀŝĐĞƌŝŐĂƐŶĞĞĚĞĚ͘Z/,ǁͬŶĞǁ^WŽŶϯ͘ϱΗϵ͘ϯη>ͲϴϬhϴƌĚ&ͬϳϴΖƚͬϮ͕ϵϰϭΖDdĞƐƚ^WĐĂďůĞ ĞǀĞƌǇϭ͕ϬϬϬΖ͘dŽƌƋƵĞDhhϯ<͘/ŶƐƚĂůůŝŶŐĐĂŶŶŽŶĐůĂŵƉƐŽŶƚŚĞĨŝƌƐƚϭϱũƚƐƚŚĞŶĞǀĞƌŽƚŚĞƌũƚĂĨƚĞƌ͘^KtϮϯŬ͘ŽŶƚZ/,ǁͬ ŶĞǁ^WŽŶϯ͘ϱΗϵ͘ϯη>ͲϴϬhϴƌĚ&ͬϮ͕ϵϰϭΖƚͬϱ͕ϭϳϰΖDdĞƐƚ^WĐĂďůĞĞǀĞƌǇϭ͕ϬϬϬΖ͘dŽƌƋƵĞDhhϯ<͘/ŶƐƚĂůůŝŶŐĐĂŶŶŽŶ ĐůĂŵƉƐŽŶĞǀĞƌǇŽƚŚĞƌũŽŝŶƚ͘WhtϱϯŬͬ^KtϮϳŬ͘WhͬDh>ĂŶĚŝŶŐ:ƚĂŶĚdďŐ,ĂŶŐĞƌǁͬWs/ŶƐƚĂůůĞĚ͘ĂďůĞdĞƐƚ'ŽŽĚ͘Ƶƚ ĂďůĞĂŶĚŵĂŬĞƉĞŶĞƚƌĂƚŽƌƐƉůŝĐĞ͘>ĂŶĚĞĚĐŽŵƉůĞƚŝŽŶǁŝƚŚϮϳŬĚŽǁŶŽŶ,ĂŶŐĞƌ͘Z/>^͘&ŝŶĂůĐĂďůĞƚĞƐƚŐŽŽĚ͘KdΛ ϱ͕ϭϵϬΖŵĚ͘EhǁĞůů,ĞĂĚĂŶĚdĞƐƚϱϬϬͬůŽǁϱ͕ϬϬϬͬŚŝŐŚƚĞƐƚŐŽŽĚĚŽĨŝŶĂůĐŚĞĐŬƐŽŶƚŚĞĂďůĞ͘dĞƐƚǁĂƐŐŽŽĚ͘ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭͬϮϯͬϮϬϮϭͲ^ĂƚƵƌĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭͬϮϲͬϮϬϮϭͲdƵĞƐĚĂǇ ϭͬϮϰͬϮϬϮϭͲ^ƵŶĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭͬϮϱͬϮϬϮϭͲDŽŶĚĂǇ 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 15,500'N/A Casing Collapse Conductor N/A Surface 4,760psi Surface 3,090psi Tieback 4,790psi Liner 8,540psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 6,257 MD/ 3,789 TVD and N/A Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 15,244' 6,268' 8,987' 3,947' 4,352' Authorized Signature: 1/20/2021 3-1/2" Perforation Depth MD (ft): See Schematic See Schematic Perforation Depth TVD (ft): Tubing Size: 2,077' 6,429' 4-1/2" 143'20" 9-5/8" 9-5/8" 2,077' 7-5/8"6,268' N/A 6,890psi 6,870psi 5,750psi 1,839' 3,802' 3,790' 715 N/A MILNE PT UNIT I-38 143'143' 9.3# / L-80 / EUE 8rd TVD Burst 5,192' 9,020psi Hilcorp Alaska LLC Length Size 3,947'15,241'3,953' MD C.O. 477.05 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025515, ADL025517, ADL025906 & ADL0315848 220-057 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 MILNE POINT / SCHRADER BLUFF OIL 50-029-23684-00-00 Tubing Grade: Tubing MD (ft): dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: BOT SLZXP and N/A ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:19 pm, Jan 12, 2021 321-019 Chad Helgeson (1517) 2021.01.12 14:54:05 - 09'00' DSR-1/12/21 10-404 BOPE Test to 2000 psi. SFD 1/13/2021MGR15JAN21Comm. 1/19/21 dts 1/15/2020 JLC 1/18/2021 RBDMS HEW 1/26/2021 ESP RWO Well: MP I-38 2021 ESP RWO Well Name:MPU I-38 API Number:50-029-23684-00 Current Status:SI Producer (Failed ESP)Pad:I-Pad Estimated Start Date:January 20th , 2021 Rig:ASR#1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:220-057 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:Ian Toomey (907) 777-8520 (O) (907) 903-3987 (M) AFE Number:Job Type:ESP RWO Current Bottom Hole Pressure: 1,100 psi @ 3,850’ TVD Estimated BHP 1-11-2021 5.5 ppg EMW Maximum Expected BHP:1,100 psi @ 3,850’ TVD MPSP:715 psi (0.1 psi/ft gas gradient) Max Inclination:91° @ 6,826’ MD Horizontal @ 6,635’ MD Max Dogleg:5.58°/100’ @ 3,757’ TVD Brief Well Summary: MPU I-38 was drilled, and completed as a Schrader Bluff producer with an ESP installed in August 2020. Notes Regarding the Well & Design x 9-5/8” Casing MIT @ 6,112’ to 1,000 psig passed on 8/11/2020 x 3/8” Cap String Installed x 2021 ESP shorted to ground requiring workover. x Offset Injector Support o I-37 Objective: x Pull Failed ESP Completion with 3/8” Cap String x Run new ESP Completion with 3/8” Cap String Pre-Workover Prep Procedure: 1. RD well house and flowlines. Clear and level area around well. 2. RU Little Red Services Pump. Setup reverse out skid, returns tank, and additional upright tanks as needed. 3. Pressure test lines to 3,000 psi. 4. Review kill plan with Engineer based on current well conditions. 5. Pump 220 bbls of 8.3 ppg source water down the IA with the TBG open to the pit. 6. Pump 40 bbls of 8.3 ppg source water down tubing with the IA open to the pit. 7. Confirm well is dead. 8. RD Little Red Services Pump and reverse out skid. 9. Clear and level pad area in front of well. Spot rig mats and containment. 10. RU crane. Set BPV. ND Tree. NU 11” BOPE. RD crane. a. Make scribe mark on tree for orientation for re-installation. b. Function test all prior to arrival of AOGCC inspectors. ESP RWO Well: MP I-38 2021 ESP RWO 11. NU BOPE house. Spot mud boat Workover Procedure: 12. MIRU ASR #1 Workover rig, ancillary equipment and lines to returns tank. 13. Pull BPV after confirming zero surface wellhead pressure. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.3 ppg source-water prior to pulling BPV. Set TWC. 14. Test BOPE to 250psi Low/ 2,000 psi High, annular to 250psi Low/ 2,000 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR rams on 3-1/2” test joint. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 15. Bleed any pressure off casing to returns tank. Pull TWC. 16. RU spooler to pull ESP Cable. 17. MU landing joint or spear and PU on the tubing hanger. a. PU weight estimated 45 Klbs. b. If needed, circulate (long or reverse) source-water, and/or baraclean pill prior to laying down the tubing hanger. 18. Recover the tubing hanger. a. Evaluate pulled tubing hanger for possible thread damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. b. Check the ESP Cable after the hanger is removed. If cable is grounded continue POH, if Cable tests good Contact Engineer on test results, option to re-land hanger. 19. POOH and lay down the 3-1/2” tubing and ESP completion. (plan to re-run 3-1/2” TBG) a. Cable clamped every joint first 15 jts and every other joint after to surface. b. 3/8” Cap String installed c. Inspect and re-use 3-1/2” TBG and clamps. d. Re-use all gas-lift mandrels and XN nipple. e. Dispose of ESP cable, re-use cap string f. Prep ESP for DIFA (Dismantle Inspection and Failure Analysis). g. Note any sand, scale, or corrosion on the tubulars or ESP on the morning report. 20. PU new ESP and RIH on 3-1/2” 9.3# 8rd-EUE L-80 tubing w/ 3/8” Cap string. Set base of ESP assembly at ±5,190’ MD. a. Upper 3-1/2”x 1” Side-pocket GLM @ ±200’ MD with 0.25” OV b. 3-1/2” tubing c. Lower 3-1/2”x 1” Side-pocket GLM with Dummy GLV d. 1 joint of 3-1/2” tubing ESP RWO Well: MP I-38 2021 ESP RWO e. 3-1/2” XN (2.75” No-Go) Nipple f. 19 joints of 3-1/2” tubing g. Downhole gauge for discharge temperature and pressure. h. Baker Hughes ESP (TBD) i. Baker Hughes ESP(TBD) j. Tandem Gas Separator k. Motor l. Motor gauge m. Base of ESP centralizer @ ±5,190’ MD 21. Land tubing hanger. RILDS. Lay down landing joint. Note slack-off weight on tally. 22. Set BPV. Post-Rig Procedure: 23. RD mud boat. RD BOPE house. Move to next well location. 24. RU crane. ND BOPE. 25. NU existing tree. Test tubing hanger void to 500 psi low/5,000 psi high. 26. Pull BPV. 27. RD crane. Move returns tank and rig mats to next well location. 28. Replace gauge(s) if removed. 29. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Blank RWO MOC Form WINJ Conversion Well: MPU F-22 Date: 12-18-2020 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Blank RWO MOC Form _____________________________________________________________________________________ Revised By: TDF 1/11/2021 SCHEMATIC Milne Point Unit Well: MPU I-38 Last Completed: 8/11/2020 PTD: 220-057 4-1/2” SOLID LINER DETAIL 4-1/2” SCREEN LINER DETAIL TD =15,500’ (MD) /TD = 3,953’ (TVD) 4&5 20” Orig. KB Elev.: 60.4’ / GL Elev.: 33.8’ 7-5/8” 16 8&9 10 & 11 4 17 9-5/8” 1 2 3 See Screen/ Solid Liner Detail PBTD = 15,241’(MD) /PBTD = 3,947’(TVD) 9-5/8” ‘ES’ Cementer @ 2,177’ MD 6& 7 4-1/2” Shoe @ 15,241’ 13 12 14 15 3-1/2”CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5# / X25 / Weld N/A Surface 143’ N/A 9-5/8" Surface 47 / L-80 / TXP 8.525 Surface 2,077’ 0.0732 9-5/8” Surface 40 / L-80 / TXP 8.679 2,077’ 6,429’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 6,268’ 0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 6,257’ 15,244’ 0.0149 TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE-8rd 2.992 Surface 5,192’ 0.0087 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 – Lead – 612 sx / Tail – 400 sx Stg 2 – Lead – 587 sx / Tail – 264 sx 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 490’ Max Hole Angle = 93° TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23684-00-00 Completion Date: 8/11/2020 Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 3 6283’ 6403’ 24 7089’ 8065’ 4 8771’ 8935’ 3 10903’ 11027’ 2 11111’ 11194’ 2 11278’ 11360’ 7 11569’ 11854’ 6 12103’ 12349’ 1 15200’ 15241’ JEWELRY DETAIL No. Top MD Item ID 1 116’ GLM: 3-1/2” x 1” BK-2 GLM w/DPSOV 2.915” 2 4,442’ GLM w/Dummy: 3-1/2” x 1” BK-2 GLM 2.920” 3 4,500’ 2.813” XN Nipple, 2.75” no go 2.750” 4 5,116’ Discharge Head: PMP 513 5 5,116’ Zenith ported Sub Pres Port 513/538P 6 5,117’ Pump 2: 538PM SXD 086 Flex47 7 5,139’ Pump 1: 538PM SXD 20 8 5,149’ Gas Separator: 538 9 5,154’ Gas Avoider 513HS 10 5,157’ Upper Tandem Seal: GSB3DB 11 5,164’ Lower Tandem Seal: GSB3DB 12 5,171’ Motor: CL5 XP – 250hp Protectolizer 13 5,187’ Sensor, Zenith 14 5,190’ Centralizer:Bottom @ 5,192’ 15 6,257’ BOT SLZXP LTP / Liner Hanger 7-5/8” x 9-5/8” 7.375” 16 6,278’ 7” H563 x 4.5” Hyd 625 XO 3.840” 17 15,241’ Solid Guide Shoe - Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 17 6403’ 7089’ 17 8065’ 8771’ 47 8935’ 10903’ 2 11027’ 11111’ 2 11194’ 11278’ 5 11360’ 11569’ 6 11854’ 12103’ 68 12349’ 15200’ _____________________________________________________________________________________ Revised By: TDF 1/11/2021 PROPOSED Milne Point Unit Well: MPU I-38 Last Completed: 8/11/2020 PTD: 220-057 4-1/2” SOLID LINER DETAIL 4-1/2” SCREEN LINER DETAIL TD =15,500’ (MD) /TD = 3,953’ (TVD) 4&5 20” Orig. KB Elev.: 60.4’ / GL Elev.: 33.8’ 7-5/8” 16 8&9 10 & 11 4 17 9-5/8” 1 2 3 See Screen/ Solid Liner Detail PBTD = 15,241’(MD) /PBTD = 3,947’(TVD) 9-5/8” ‘ES’ Cementer @ 2,177’ MD 6& 7 4-1/2” Shoe @ 15,241’ 13 12 14 15 3-1/2”CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5# / X25 / Weld N/A Surface 143’ N/A 9-5/8" Surface 47 / L-80 / TXP 8.525 Surface 2,077’ 0.0732 9-5/8” Surface 40 / L-80 / TXP 8.679 2,077’ 6,429’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 6,268’ 0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 6,257’ 15,244’ 0.0149 TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE-8rd 2.992 Surface ±5,192’ 0.0087 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 – Lead – 612 sx / Tail – 400 sx Stg 2 – Lead – 587 sx / Tail – 264 sx 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 490’ Max Hole Angle = 93° TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23684-00-00 Completion Date: 8/11/2020 Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 3 6283’ 6403’ 24 7089’ 8065’ 4 8771’ 8935’ 3 10903’ 11027’ 2 11111’ 11194’ 2 11278’ 11360’ 7 11569’ 11854’ 6 12103’ 12349’ 1 15200’ 15241’ JEWELRY DETAIL No. Top MD Item ID 1 ±116’ GLM 2:2.915” 2 ±4,442’ GLM 1:2.920” 3 ±4,500’ 3-1/2” XN Nipple, 2.75” no go 2.750” 4 ±5,116’ Discharge Head: 5 ±5,116’ Zenith ported Sub Pres Port 6 ±5,117’ Pump 2: 7 ±5,139’ Pump 1: 8 ±5,149’ Gas Separator: 9 ±5,154’ Gas Avoider 10 ±5,157’ Upper Tandem Seal: 11 ±5,164’ Lower Tandem Seal: 12 ±5,171’ Motor: 13 ±5,187’ Sensor, Zenith 14 ±5,190’ Centralizer: Bottom @ ±5,192’ 15 6,257’ BOT SLZXP LTP / Liner Hanger 7-5/8” x 9-5/8” 7.375” 16 6,278’ 7” H563 x 4.5” Hyd 625 XO 3.840” 17 15,241’ Solid Guide Shoe - Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 17 6403’ 7089’ 17 8065’ 8771’ 47 8935’ 10903’ 2 11027’ 11111’ 2 11194’ 11278’ 5 11360’ 11569’ 6 11854’ 12103’ 68 12349’ 15200’ Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: January 11th, 2021Subject: Changes to Approved Sundry Procedure for Well MP I-38Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23684-00-00Well Name/No. MILNE PT UNIT I-38Completion Status1-OILCompletion Date8/11/2020Permit to Drill2200570Operator Hilcorp Alaska, LLCMD15500TVD3953Current Status1-OIL10/14/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP, AGR, ABG, DGR, EWR, ADR MD & TVD...PB1/PB2: ROP ,AGR, ABG, DGR, EWR, ADR MD & TVDNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF10/5/2020128 15500 Electronic Data Set, Filename: MPU I-38 LWD Final.las34032EDDigital DataDF10/5/20206420 15462 Electronic Data Set, Filename: MPU I-38 ADR Quadrants All Curves.las34032EDDigital DataDF10/5/2020 Electronic File: MPU I-38 LWD Final MD.cgm34032EDDigital DataDF10/5/2020 Electronic File: MPU I-38 LWD Final TVD.cgm34032EDDigital DataDF10/5/2020 Electronic File: MPU I-38_Definitive Survey Report.pdf34032EDDigital DataDF10/5/2020 Electronic File: MPU I-38_DSR.txt34032EDDigital DataDF10/5/2020 Electronic File: MPU I-38_GIS.txt34032EDDigital DataDF10/5/2020 Electronic File: MPU I-38 LWD Final MD.emf34032EDDigital DataDF10/5/2020 Electronic File: MPU I-38 LWD Final TVD.emf34032EDDigital DataDF10/5/2020 Electronic File: MPU_I-38_Geosteering.dlis34032EDDigital DataDF10/5/2020 Electronic File: MPU_I-38_Geosteering.ver34032EDDigital DataDF10/5/2020 Electronic File: MPU I-38 LWD Final MD.pdf34032EDDigital DataDF10/5/2020 Electronic File: MPU I-38 LWD Final TVD.pdf34032EDDigital DataDF10/5/2020 Electronic File: MPU I-38 LWD Final MD.tif34032EDDigital DataDF10/5/2020 Electronic File: MPU I-38 LWD Final TVD.tif34032EDDigital Data0 0 2200570 MILNE PT UNIT I-38 LOG HEADERS34032LogLog Header Scans0 0 2200570 MILNE PT UNIT I-38 PB1 LOG HEADERS34033LogLog Header ScansDF10/5/2020128 9459 Electronic Data Set, Filename: MPU I-38PB1 LWD Final.las34033EDDigital DataWednesday, October 14, 2020AOGCCPage 1 of 3PB1PB2MPU I-38 LWDFinal.lasMPU I-38PB1 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23684-00-00Well Name/No. MILNE PT UNIT I-38Completion Status1-OILCompletion Date8/11/2020Permit to Drill2200570Operator Hilcorp Alaska, LLCMD15500TVD3953Current Status1-OIL10/14/2020UICNoDF10/5/20206420 9422 Electronic Data Set, Filename: MPU I-38PB1 ADR Quadrants All Curves.las34033EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB1 LWD Final MD.cgm34033EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB1 LWD Final TVD.cgm34033EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB1_Definitive Survey Report.pdf34033EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB1_DSR.txt34033EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB1_GIS.txt34033EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB1 LWD Final MD.emf34033EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB1 LWD Final TVD.emf34033EDDigital DataDF10/5/2020 Electronic File: MPU_I-38PB1_Geosteering.dlis34033EDDigital DataDF10/5/2020 Electronic File: MPU_I-38PB1_Geosteering.ver34033EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB1 LWD Final MD.pdf34033EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB1 LWD Final TVD.pdf34033EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB1 LWD Final MD.tif34033EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB1 LWD Final TVD.tif34033EDDigital DataDF10/5/2020128 11575 Electronic Data Set, Filename: MPU I-38PB2 LWD Final.las34034EDDigital DataDF10/5/20206420 11538 Electronic Data Set, Filename: MPU I-38PB2 ADR Quadrants All Curves.las34034EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB2 LWD Final MD.cgm34034EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB2 LWD Final TVD.cgm34034EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB2_Definitive Survey Report.pdf34034EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB2_DSR.txt34034EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB2_GIS.txt34034EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB2 LWD Final MD.emf34034EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB2 LWD Final TVD.emf34034EDDigital DataDF10/5/2020 Electronic File: MPU_I-38PB2_Geosteering.dlis34034EDDigital DataDF10/5/2020 Electronic File: MPU_I-38PB2_Geosteering.ver34034EDDigital DataWednesday, October 14, 2020AOGCCPage 2 of 3MPU I-38PB2LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23684-00-00Well Name/No. MILNE PT UNIT I-38Completion Status1-OILCompletion Date8/11/2020Permit to Drill2200570Operator Hilcorp Alaska, LLCMD15500TVD3953Current Status1-OIL10/14/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:8/11/2020Release Date:7/13/2020DF10/5/2020 Electronic File: MPU I-38PB2 LWD Final MD.pdf34034EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB2 LWD Final TVD.pdf34034EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB2 LWD Final MD.tif34034EDDigital DataDF10/5/2020 Electronic File: MPU I-38PB2 LWD Final TVD.tif34034EDDigital Data0 0 2200570 MILNE PT UNIT I-38 PB2 LOG HEADERS34034LogLog Header ScansWednesday, October 14, 2020AOGCCPage 3 of 3M. Guhl10/14/2020 David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 777-8510. Received By: Date: DATE 10/02/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-38 + MPU I-38PB1 + MPU I-38PB2 (PTD 220-057) FINAL LWD LOGS (06AUG2020): EWR-M5, AGR, ABG, DGR, ADR, HORIZONTAL PRESENTATION (MD/TVD) AND DEFINITIVE DIRECTIONAL SURVEY Main Folders: Sub-Folders: Received by the AOGCC 10/05/2020 PTD: 2200570 E-Set: 34032 Abby Bell 10/05/2020 David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 777-8510. Received By: Date: DATE 10/02/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-38 + MPU I-38PB1 + MPU I-38PB2 (PTD 220-057) FINAL LWD LOGS (06AUG2020): EWR-M5, AGR, ABG, DGR, ADR, HORIZONTAL PRESENTATION (MD/TVD) AND DEFINITIVE DIRECTIONAL SURVEY Main Folders: Sub-Folders: Received by the AOGCC 10/05/2020 PTD: 2200570 E-Set: 34033 Abby Bell 10/05/2020 David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 777-8510. Received By: Date: DATE 10/02/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-38 + MPU I-38PB1 + MPU I-38PB2 (PTD 220-057) FINAL LWD LOGS (06AUG2020): EWR-M5, AGR, ABG, DGR, ADR, HORIZONTAL PRESENTATION (MD/TVD) AND DEFINITIVE DIRECTIONAL SURVEY Main Folders: Sub-Folders: Received by the AOGCC 10/05/2020 PTD: 2200570 E-Set: 34034 Abby Bell 10/05/2020 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name:6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address:7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section):8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:9. Ref Elevations: KB: 17. Field / Pool(s): GL: 33.80' BF: Total Depth:10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27):11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone-4 TPI:x- y- Zone-4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth:x- y- Zone-4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" X-25 143' L-80 1839' L-80 3802' 7-5/8"L-80 3790' 4-1/2"L-80 3947' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production:Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ADL025906, 025517 & 025515 88-004 1974' / 1761' N/AN/A None 15500' / 3953' Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl:Water-Bbl: Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar l ocator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A 4-1/2" Screen Liner 8/8/20 **Please see attached Schematic for detail** Water-Bbl: PRODUCTION TEST Not on Production Date of Test: Flow Tubing 130# 47# 143' 2077'6429' Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 40# 6268' 1839' Surface DEPTH SET (MD) 6257' / 3789' PACKER SET (MD/TVD) CASING WT. PER FT.GRADE 29.7# 548217 549870 TOP SETTING DEPTH MD Surface Surface SETTING DEPTH TVD 6019915 BOTTOM TOP Surface Surface ROP, AGR, ABG, DGR, EWR, ADR MD & TVD PB1: ROP, AGR, ABG, DGR, EWR, ADR MD & TVD PB2: ROP, AGR, ABG, DGR, EWR, ADR MD & TVD HOLE SIZE AMOUNT PULLED 33.80' 50-029-23684-00-00 MPU I-38 551510 6009452 1383' FSL, 1859' FEL, Sec. 32, T13N, R10E, UM, AK CEMENTING RECORD 6010989 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 8/11/2020 2337' FSL, 3861' FEL, Sec. 33, T13N, R10E, UM, AK 2253' FSL, 121' FEL, Sec. 20, T13N, R10E, UM, AK 220-057 Milne Point Field, Schrader Bluff Oil Pool 60.40' 15241' / 3947' 8/5/2020 7/21/2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas Driven 13.5# Surface 2077'Stg 1 L - 612 sx / T - 400sx 8-1/2"6257'15244' Stg 2 L - 587 sx / T 264 sx 3789' Liner Top Packer 5192'3-1/2" 9.3# L-80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 9-5/8"12-1/4" ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, Uncemented TiebackTieback TUBING RECORD Uncemented Screen Liner G s d 1 0 p d P l L (att Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 11:31 am, Aug 31, 2020 +(: Completion Date 8/11/2020 HEW RBDMS HEW 9/1/2020 FNL HEW SFD 9/2/2020 DLB 09/01/2020 DSR-9/1/2020MGR10SEP2020 G Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 36' 36' 2010' 1797' Top of Productive Interval 6365' 3799' 1388' 1345' 2351' 2010' 4535' 3236' 6149' 3777' 6365' 3799' SB NB 6365' 3799' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Joe Lastufka Contact Email:joseph.lastufka@hilcorp.com Authorized Contact Phone: 777-8400 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31:Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: Ugnu LA3 Plugback Summary, LOT / FIT Data Sheet, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report, Wellbore Schematic Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated . Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Schrader Bluff NA SV5 SV1 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inc lination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Schrader Bluff NB Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered):FORMATION TESTS Permafrost - Top N Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 8.31.2020Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.08.31 11:05:00 -08'00' Monty M Myers _____________________________________________________________________________________ Edited By: JNL 8-21-2020 Proposed Schematic Milne Point Unit Well: MPU I-38 Last Completed: 8/11/2020 PTD: 220-057 4-1/2” SOLID LINER DETAIL 4-1/2” SCREEN LINER DETAIL CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5# / X25 / Weld N/A Surface 143’ N/A 9-5/8" Surface 47 / L-80 / TXP 8.525 Surface 2,077’ 0.0732 9-5/8” Surface 40 / L-80 / TXP 8.679 2,077’ 6,429’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 6,268’ 0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920 6,257’ 15,244’ 0.0149 TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE-8rd 2.992 Surface 5,192’ 0.0087 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4" Stg 1 – Lead – 612 sx / Tail – 400 sx Stg 2 – Lead – 587 sx / Tail – 264 sx 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 490’ Max Hole Angle = 93° TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23684-00-00 Completion Date: 8/11/2020 Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 3 6283’ 3791’ 6403’ 3801’ 24 7089’ 3796’ 8065’ 3834’ 4 8771’ 3831’ 8935’ 3823’ 3 10903’ 3872’ 11027’3873’ 2 11111’ 3871’ 11194’3869’ 2 11278’ 3868' 11360’3871’ 7 11569’ 3883’ 11854’3900’ 6 12103’ 3904’ 12349’3896’ 1 15200’ 3946’ 15241’3947’ JEWELRY DETAIL No. Top MD Item ID 1 116’ GLM: 3-1/2” x 1” BK-2 GLM w/DPSOV 2.915” 2 4442’ GLM w/Dummy: 3-1/2” x 1” BK-2 GLM 2.920” 3 4500’ 2.813” XN Nipple, 2.75” no go 2.750” 4 5116’ Discharge Head: PMP 513 5 5116’ Zenith ported Sub Pres Port 513/538P 6 5117’ Upper Tandem Pump: 538PM SXD 086 Flex47 7 5139’ Lower Tandem Pump: 538PM SXD 20 8 5149’ Gas Separator: 538 9 5154’ Gas Avoider 513HS 10 5157’ Upper Tandem Seal: GSB3DB 11 5164’ Lower Tandem Seal: GSB3DB 12 5171’ Motor: CL5 XP – 250hp Protectolizer 13 5187’ Sensor, Zenith 14 5190’ Centralizer: Bottom @ TBD 15 6257’ BOT SLZXP LTP / Liner Hanger 7-5/8” x 9-5/8” (TVD TBD) 7.375” 16 6278’ 7” H563 x 4.5” Hyd 625 XO 3.840” 17 15241’ Solid Guide Shoe - Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 17 6403’ 3801’ 7089’ 3796’ 17 8065’ 3834’ 8771’ 3831’ 47 8935’ 3823’ 10903’ 3872’ 2 11027’ 3873’ 11111’ 3871’ 2 11194’ 3869’ 11278’ 3868’ 5 11360’ 3871’ 11569’ 3883’ 6 11854’ 3900’ 12103’ 3904’ 68 12349’ 3896’ 15200’ 3946’ CASING AND LEAK-OFF FRACTURE TESTS Well Name:MPU I-38 Date:7/29/2020 Csg Size/Wt/Grade: Supervisor:Lott / Montague Csg Setting Depth:6,429 3,802 TVD Mud Weight:8.9 ppg LOT / FIT Press =618 psi LOT / FIT =12.00 ppg Hole Depth =6439 md Fluid Pumped=1.1 Bbls Volume Back =1.0 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here ->023 ->00 ->269 ->10 135 ->4132 ->20 442 ->6203 ->30 733 ->8278 ->40 1061 ->10 355 ->45 1245 ->12 430 ->50 1424 ->14 493 ->55 1606 ->16 550 ->60 1804 ->18 605 ->65 1992 ->19 628 ->70 2182 -> ->75 2372 -> ->80 2564 -> ->82 2650 Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0621 ->02650 ->1587 ->12636 ->2570 ->22633 ->3558 ->32630 ->4547 ->42629 ->5536 ->52626 ->6530 ->10 2619 ->7525 ->15 2613 ->8518 ->20 2607 ->9514 ->25 2603 ->10 510 ->30 2602 -> -> -> -> -> -> 9.625 40#/47# L-80 0 2 4 6 8 10 12 14 16 1819 0 10 20 30 40 45 50 55 60 65 70 75 80 82 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 0 102030405060708090Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 621587570558547536530525518514510 265026362633263026292626 2619 2613 2607 2603 2602 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 0 5 10 15 20 25 30Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA Activity Date Ops Summary 7/19/2020 PJSM Crab walk Sub over I-38. Spot and level Sub over I-38. Spot Catwalk to Sub.;Daily fluid hauled to G&I 0 bbls total = 0 bbls Daily water hauled from A Pad Lake 0 bbls total = 0 bbls Daily fluid lost 0 Total= 0 bbls Daily metal recovered 0 lbs, total = 0 lbs 7/20/2020 Spot and shim pipeshed, Mud module, and generator module. Release Peak rig movers @ 09:30 hrs. Swap to C-32 Rig power @ 10:00 hrs. Set cuttings box, MPD and Break shack. R/U interconnect lines. Roll steam, water and air throughout rig. Swap to Hi-Line power @ 11:15 hrs. W ork rig acceptance checklist. PJSM, Scope derrick up and secure same. Bridal down. R/U DS stairs and install barriers for adjacent wells of sub mod. Load shed (200 jts dp / MWD tools). Prep mud pumps and pits for drilling operations. 2 trucks w/ spud mud staged on location and ready. N/U 13-5/8" BOP stack, configured for diverter operations drilling surface. N/U 16" diverter knife valve, 16" diverter line to tundra and wait till crane is available.. Continue work rig acceptance checklist. PJSM Finish acceptance checklist other than testing the mud line. Move fluid thru pits, pump w/ mud pumps thru bleeders, run centrifuges, service skate and fh-80, Pressure up Koomey, obtain RKB 26.5' measurement. Rig Accepted at 21:00. PJSM P/U M/U 5” S-135 NC-50 DP M/U stands in mouse hole and rack back, drift w/ 3.125” rabbit F/ Skate P/U – 15 stands Canrig quit working. PJSM Crane on location. Set rig mats on tundra, set twin tower pedestal, set diverter sections and bolt up, PJSM Cont. P/U M/U 5” S-135 NC- 50 DP M/U stands in mouse hole and rack back, drift w/ 3.125” rabbit F/ Skate P/U – 18 stands. PJSM Cont. P/U M/U 5” S-135 NC-50 DP M/U stands in mouse hole and rack back, drift w/ 3.125” rabbit F/ Skate P/U – 67 stands. P/U M/U 5" HWDP S-135 NC50 2.75" rabbit F/ Skate- 15 stands. SIMOPS Function Annular and Knife Valve. Take on 580 bbls Spud Mud to Pits. Cont trying to get Canrig going. PJSM Pull false rotary, hook up knife valve, and pressure annular back up to 1500 psi. PJSM P/U and stage short BHA on rig floor. Daily fluid hauled to G&I 0 bbls total = 0 bbls Daily water hauled from A Pad Lake 390 bbls total = 390 bbls Daily fluid lost 0 Total= 0 bbls Daily metal recovered 0 lbs, total = 0 lbs 7/21/2020 Clean and clear rig floor. Mob BHA tools to rig floor. Continue troubleshooting CanRig "RigWatch" system. Perform Diverter Test. Witnessed by AOGCC rep Adam Earl. Knife valve 6 secs, Annular 9 secs. Drawdown Test - 3050 initial, 1950 drawdown, 13 secs for 200 psi inc, 56 secs for full charge. 2300 psi 6 bottle avg N2O. Test gas alarms 10/20 ppm H2S, 20/40% LEL. Service Rig - Grease drawworks, traveling equipment, handling equipment. R/U Gyro (Ak E-line) w/ Scientific Gyro tool. Continue troubleshoot CanRig. Computer Driver failed. Bring replacement computer drive system from Deadhorse and replace same. Reconfigure and install. Test system (test good). Setup CanRig stations for drilling operations. PJSM, M/U 12-1/4" 633 Kymera (.8191" TFA), 8" Terra Force mtr w/ 1.5° bend (5.3 stg - 4/5 Lobe). RIH and tag @ 37' MD. Flood surface lines and conductor with H2O. P/T surface lines to 3k (test good). Drill ahead F/ 37' - T/ 218' MD. 350 gpm, 250 psi, 40 rpm, 1.1k tq. Mostly pea gravel w/ coarse sand. (Btm of conductor 143' + 26.5' = 169.5'). MW 8.8, 250 vis. BROOH from 218' to 155' 350 gpm, 250 psi, 40 rpms, 1.1Kft-lbs. POOH on elevators to 120', pull 20K over x2. Establish rotary and circulation, BROOH to 92'. POOH, check bit - good. Cont. M/U 12-1/4 drilling BHA: DM colloar, EWR-M5 collar, TM Collar, UBHO. Measure RFO 5.99/7.90= 272.96. Orientate UBHO to motor. Plu in and upload MWD. Cont. RIH with flex collars, tag up at 117', attempt to work through, unable to. L/D collar, M/U stand of HWDP with XO on bottom. Wash and ream down to 181' with 400 gpm, 470 psi, 20 rpms, 750 ft-lbs. Rack back stand of HWDP. RIH with (2) drill collars, followed by HWDP. Set down at 192', wash through with same parameters to 218'. Drill 12-1/4" surface F/ 218' - T/ 394' (176' total, 117 fph AROP). WOB 2K, 416 gpm, 560 psi, 40 rpm, 1.4K tq on, 9.87 ppg ECD with 8.8 ppg MW. P/U 57K, S/O 57K, ROT 57K. Negligible gas. Observe ~300 psi loss of pump pressure (erratic), pump through bleeder with each pump mud pump 2 pressure 100 psi lower. Rack back stand and troubleshoot MP#2. Pull valves and inspect, replace pod 4 discharge valve (washed out). Observe small pea gravel in valves. Clean out mud pump. Pump through bleeders, 20 psi differential between pumps. RIH to 394'. Drill 12-1/4" surface F/ 394' - T/ 714' (320' total, 71 fph AROP). WOB 2-4K, 410 gpm, 847 psi, 40 rpm, 1.5K tq on, 9.8 ppg ECD with 8.8 ppg MW. P/U 78K, S/O 74K, ROT 76K. Max gas 9U. KOP at 460', start collecting gyro surveys every stand, pump through bleeder while gyro. Distance to WP 09: 3.87', 3.24' high, 2.12' Right Daily fluid hauled to G&I 181 bbls total = 181 bbls Daily water hauled from A Pad Lake 390 bbls total = 780 bbls Daily fluid lost 0 Total= 0 bbls Daily metal recovered 0 lbs, total = 0 lbs 7/22/2020 Continue Drlg 12-1/4" surface F/ 714' - T/ 1191' MD (477' total - 80 fph AROP). 450 gpm, 1100 psi on, 900 psi off, 58% flow, 60-80 rpm, 3.1k tq on, 2.1k tq off. Negligible gas with no hydrates or Hydrocarbons observed. 9.8 ECD's w/ 8.9 MW, 250 vis mud. Sliding as needed for 4°/100 build and turn. 79k up, 79k dn, 79k rot. Clean MWD svy's @ 929' MD. R/D & Release gyro (Ak-Eline, Scientific). Continue Drlg 12-1/4" surface F/ 1191' - T/ 1920' MD (729' total - 122 fph AROP). 450 gpm, 1360 psi on, 1150 psi off, 63% flow, 80 rpm, 5.3k tq on, 2.7k tq off. Max gas 190u. 10.3 ECD's w/ 8.9 MW, 250 vis mud. 89k up, 82k dn, 86k rot. BR 1/2 stds. Sliding as needed for 4°/100 build and turn. Continue Drlg 12-1/4" surface F/ 1920' - T/ 2718' MD (798' total - 133 fph AROP). 450 gpm, 1380 psi on, 1180 psi off, 57% flow, 80 rpm, 5.5K tq on, 4.8K tq off. Max gas 3060u. 10.19 ECD's w/ 9.1 MW. 104k up, 83k dn, 92k rot. Backream full stands. Sliding as needed for 4°/100 build and turn to start of tangent section at 1850'MD. Observe oil on shakers at 2700'MD (gas 3060U). Base of Permafrost logged at 2010'MD. Continue Drlg 12-1/4" surface F/2718 ' - T/ 3195' MD (477' total - 80 fph AROP). 500 gpm, 1625 psi, 58% flow, 90 rpm, 7.5K tq on, 7K tq off. Max gas 2751U. ECD's 10.22 w/ 9.3 MW. 110K up, 85K dn, 94K rot. Backream full stands. Start for 4°/100 build and turn at 2800'MD. Distance to WP09 13.59', 11.96' high, 6.45' right Daily fluid hauled to G&I 1083 bbls total = 1264 bbls Daily water hauled from A Pad Lake 390 bbls total = 1170 bbls Daily water hauled from B pad creek 650 bbls total = 650 bbls Daily fluid lost 0 Total= 0 bbls Daily metal recovered 0 lbs, total = 0 lbs 50-029-23684-00-00API #: Well Name: Field: County/State: MP I-38 Milne Point Hilcorp Energy Company Composite Report , Alaska 7/21/2020Spud Date: 7/23/2020 Drill 12-1/4" surface F/ 3195' - T/ 3831' (636' total, 106fph AROP). WOB 12K, 525 gpm, 1814 psi, 100 rpm, 9.5K tq on, 8.6K tq off, 65% flow, 10.3 ppg ECD, 9.25 ppg MW. P/U 125K, S/O 84K, ROT 101K. Max gas 191U. Backream full stands. Maintenance slides as necessary for tangent from ~3300' - 4060' Drill 12-1/4" surface F/ 3831' - T/ 4420' (589' total, 98 fph AROP). WOB 8K, 525 gpm, 1930 psi, 100 rpm, 10.5K tq on. 9-12K tq off, 66% flow, 10.11 ppg ECD with 9.2 ppg MW. P/U 136K, S/O 86K, ROT 107K. Max gas 190U. Backream full stands. Sliding for 4°/100 build and turn from 4060' - 5096' Drill 12-1/4" surface F/ 4420' - T/ 4880' (460' total, 77 fph AROP). WOB 10K, 525 gpm, 1930 psi, 100 rpm, 12.5K tq on. 9-12K tq off, 59% flow, 9.8 ppg ECD with 9.2 ppg MW. P/U 144K, S/O 87K, ROT 110K. Max gas 13U. Backream full stands. Sliding for 4°/100 build and turn from 4060' - 5096' Drill 12-1/4" surface F/ 4880' - T/ 5357' (477' total, 80 fph AROP). WOB 8K, 550 gpm, 1980 psi, 120 rpm, 14K tq on. 15K tq off, 65% flow, 10.1ppg ECD with 9.25 ppg MW. P/U 155K, S/O 84K, ROT 111K. Max gas 200U. Backream full stands. Start pump tangent at 5100'. Distance to WP09: 11.74', 11.54' high, 2.15' left Daily fluid hauled to G&I 1083 bbls total = 2347 bbls Daily water hauled from A Pad Lake 0 bbls total = 1170 bbls Daily water hauled from B pad creek 1170 bbls total = 1820 bbls Daily fluid lost 0 Total= 0 bbls Daily metal recovered 0 lbs, total = 0 lbs 7/24/2020 Drill 12-1/4" surface F/ 5357' - T/ 5736' (379' total, 63 fph AROP). WOB 2-15K, 550 gpm, 2130 psi, 90 rpm, 12.5K tq on. 14K tq off, 66% flow, 10.2 ppg ECD with 9.25 ppg MW. P/U 166K, S/O 80K, ROT 113K. Max gas 465u. Backream full stands. Screen down @ 5430' (2x ea 100's) losses @ shakers. Drill 12-1/4" surface F/ 5736' - T/ 6300' (564' total, 94 fph AROP). WOB 9K, 550 gpm, 2160 psi, 95 rpm, 17.8K tq on. 12-15K tq off, 66% flow, 10.09 ppg ECD with 9.3 ppg MW. P/U 165K, S/O 75K, ROT 108K. Max gas 404u. Backream full stands. Fault crossed at 5800' with 62' DTN throw. Drill 12-1/4" surface F/ 6300' - T casing point at 6439', 3802'TVD (139' total, 70 fph AROP). WOB 12-16K, 550 gpm, 2200 psi, 100 rpm, 17.8K tq on. 11K tq off, 67% flow, 10.54 ppg ECD with 9.2 ppg MW. P/U 166K, S/O 75K, ROT 108K. Max gas 790u. Backream full stands. Obtain final on btm survey. SB NB sands logged at 6365'. BROOH to 6300' (above NB sands). Pump 45 bbls high viscosity sweep (1000 strokes early, 10%) and circulate hole clean (2x bottoms up), 550 gpm, 2145 psi, 100 rpms, 12-18Kft-lbs, reciprocating pipe. RIH from 6300' to 6439' on elevators with no issues. BROOH from 6439' to 6240', 20 fpm, 500 gpm, 1975 psi, 80 rpms, 13-18Kft-lbs, ECD 10.0 ppg, PUW 165K, SOW 77K, ROT 110K. Monitor well, static. Cont. to BROOH from 6240' to 3167' at 550 gpm, 1685 psi, 80 rpms, 9-13Kft-lbs. ECD 10.16 with 9.3 ppg mud, Max gas 254U. PUW 123K, SOW 76K, ROTW 97K. Pulling 18-35 fpm as hole dictates. Distance to WP09: 7.65', 3.22' low, 6.59' Left Daily fluid hauled to G&I 1197 bbls total = 3544 bbls Daily water hauled from A Pad Lake 0 bbls total = 1170 bbls Daily water hauled from B pad creek 1430 bbls total = 3250 bbls Daily fluid lost 0 Total= 0 bbls Daily metal recovered 0 lbs, total = 0 lbs 7/25/2020 Cont. to BROOH F/ 3167' - T/ 715' MD (BHA). 550 gpm, 1685 psi, 80 rpms, 9-13Kft-lbs. At 2200' - Reduce to 500 gpm, 1510 psi, 60 rpm, 5.5k tq. Pull 2x stds slowly allowing time to circulate 2x btms up just below base of permafrost. At 1100' - Reduce to 450 gpm, 1070 psi. Saw slight packing off w/ 15k when pulling bit through base of permafrost @ 2010' MD. Work thru clean and continued BROOH without any other issue. Monitor well @ HWDP (static). Attempt to pull on elevators @ 715' MD. Pulled clean to 650' then saw overpull slowly climb to 15k over. S/O and attempt to pull thru (no go). Continue BROOH F/ 650' - T/ 370' MD @ 450 gpm, 1050 psi, 20 rpm, 2-3k tq. Pull on elevators F/ 370' to surface. Pulled clean into conductor shoe. Racked back HWDP w/ jars. L/D 8" NM DC.s Download MWD. Drain mtr, B/O and L/D bit. Bit grade 1,1,WT,A,E,I,NO,TD. Slight damage to mtr sleeve/stab on high side of blades indicating it was from backreaming. Rig up to run casing. Remove 5" hydraulic elevators. Install Volant tool, install bail extensions, install casing elevators, rig up casing tongs. Make up shoe track and Bakerlok, install top hat on float collar as per HES. Check floats - good. RIH with 9-5/8", 40#, L-80, TXP casing as per detail to 2586', torque connections to 21Kft-lbs. Fill every 5 joints, break circulation every 10. Circulate hole clean, stage pumps up to 6 bpm, 140 psi, 7 rpms, 7Kft-lbs, reciprocating pipe. No losses. Max gas 146U. PUW 125K, SOW 98K. RIH with 9-5/8", 40# & 47#, L-80, TXP casing as per detail from 2586' to 4515', torque 40# connections to 21Kft-lbs, and 47# connections to 23.8Kft-lbs. Fill every 5 joints, break circulation every 10. Pick up ES cementer, BakerLok and inspect as per tally, swap to 47# casing as per tally. Circulate bottoms up, staging pumps up to 6 bpm, FCP 230 psi, 2-4 rpms with torque limiter set at 15Kft-lbs, reciprocating pipe. Max Gas 77U, PUW 197K, SOW 97K RIH with 9-5/8", 47#, L-80, TXP casing as per detail from 4515' to 5550', torque connections to 23.8Kft-lbs. Fill every 5 joints, break circulation every 10. PUW 258K, SOW 90K. Calculated displacement observed. Daily fluid hauled to G&I 399 bbls total = 3943 bbls Daily water hauled from A Pad Lake 0 bbls total = 1170 bbls Daily water hauled from B pad creek 390 bbls total = 3640 bbls Daily fluid lost 0 Total= 0 bbls Daily metal recovered 0 lbs, total = 0 lbs 7/26/2020 Continue running 9-5/8" TXP BTC , L-80, 40/47# casing as per detail F/ 5550' - T/ 6429' MD (set depth). No obstructions during casing run. Tq 47# 24k ft/lbs. Track disp every 5 jts. Ran a total of 77 bow spring centralizers. 270k up, 97k dn @ 6429' MD. Calculated displacement for casing run. Circulate and condition mud (Rot/Recip) @ 6429' MD. Stage up to 8 bpm, 325 psi, 53%, 1-5 rpm, 18k tq. Could only rotate while reciprocating pipe. Condition mud to 9.35 ppg, 15 YP. Circulate 2x Btms up. PJSM, R/U cmt line to Volant CRT. Break circulation 8 bpm, 630 psi, 53% flow, 105k dn, 267k up. Perform 1st stage cmt job - Wet lines w/ 5 bbls H2O. P/T lines 1178 psi low / 4112 psi high (test good). Pump 60 bbls 10# spacer (5# poly flake, 4# red dye in first 10bbls), 4 bpm 290 psi. Drop btm bypass plug. 256 bbls 12# type I/II Lead cmt (2.349 yld) 612sxs, 4.9 bpm, 378 psi. 82 bbls 15.8# Class G Tail cmt (1.151 yld) 400 sxs, 3 bpm, 200 psi. Drop top shutoff plug. HES pump 20 bbls H2O, 5.5 bpm, 330 psi. Rig disp MP#2 - 283.4 bbls 9.4 spud mud, 8 bpm, 410 psi HES- 80 bbls 9.4 ppg tuned spacer, 4.5 bpm, 222 psi (10 bbl below / 70 bbl above) Rig disp 90.5 bbls 9.4 spud mud, 7.5 bpm, 540 psi. Slowed last 10 bbls to 3 bpm, FCP 770 psi. Bumped @ 6030 stks (472.8 bbls calc / 476.9 bbls act). Psi up to 1270 psi w/ 5 min hold. Bled back 3 bbls, floats held. CIP @ 14:55 hrs. Full returns thru out job. Rot/Recip until last 10 bbl disp Poly back at shaker 300 bbls into displacement. Contaminated mud w/ Spacer back @ surface Psi up @ 3 bpm. Observed indication of stg tool shifting @ 3330 psi. Stg up to 6. bpm, 640 psi. Overboard 60 bbls spacer, 46 bbls green cmt, Flush surface equipment, Cont circ. Prep for 2nd stg. Circ @ 6 bpm 380 psi. Surge @ 10 bpm holding 2-5 min then continue @ 6 BPM to help cleanup Cont. to circulate hole at 6 bpm, 540 psi with no losses, prepping pits for 2nd stage cement job and WOC. Perform 2nd stage cement job: HES Wet lines w/ 5 bbls H2O 3.5 bpm, 240 psi. Pump 50 bbls 10# spacer (5# poly flake, 4# red dye in first 10bbls), 3.7 bpm 215 psi. 308 bbls 10.7# ArcticCem Lead cmt (2.944 yld) 587sxs, 4 bpm, 400 psi. Observe good 10.65 ppg cement at surface 285 bbls into lead. 55 bbls 15.8 ppg Class G tail cement (1.169 yld), 264 sxs at 3.6 bpm, 470 psi. Drop closing plug. Displaced with 20 bbls H2O at 5.5 bpm, 340 psi. Rig displaced with 140 bbls (139.8 calc) of 9.4 ppg mud at 6 bpm, 955 psi. Slow to 3 bpm with 10 bbls to go. FCP 600 psi. Bump plug and pressure up to 2100 psi, observing tool shift close at 1933 psi. Hold pressure for 5 minutes, bleed back 1.5 bbls and confirm tool closed. CIP at 01:00. 238 bbls of green cement returned. No losses. Rig down and flush cement line with black water. Flush flow line. Break out and L/D Volant tool. Disconnect knife valve and flush stack 3 x, working annular. Sim Ops N/D diverter vent line. Install casing elevators. Blow down lines to stack, clean out cellar box. Break bolts and lift stack. Set 'E-slips (115K on slips). Suck out cut joint. Cut excess casing (29.17') and lay down. Remove casing elevators and install 5". Sim Ops Flush lines and pumps in pits. Begin offloading mud. Set stack down and 4-bolt. Pick up working single and stack washing tool. Wash stack with black water. Drain stack, clean out cellar box and flow box. Sim Ops: Cont. offloading mud. Daily fluid hauled to G&I 1095 bbls total = 5038 bbls. Daily water hauled from A Pad Lake 0 bbls total = 1170 bbls. Daily water hauled from B pad creek 780 bbls total = 4420 bbls. Daily fluid lost 0 Total= 0 bbls. Daily metal recovered 0 lbs, total = 0 lbs. 256 bbls 12# type I/II Lead cmt (2.349 yld) 612sxs, 4.9 bpm, 378 psi. 82 bbls 15.8# Class G Tail cmt (1.151 yld) 400 sxs, 3 bpm, 200 psi. . 308 bbls 10.7# ArcticCem Lead cmt (2.944 yld) 587sxs,4 bpm, 400 psi. 10.65 ppg cement at surface 285 bbls into lead. 55 bbls 15.8 ppg Class G tail cement (1.169 yld), 264 sxs at 3.6 bpm, 470 psi. 7/27/2020 N/D diverter: remove riser, knife valve. Pick up stack to pull speed head off diverter. Remove diveter 'T', DSA and speed head from cellar. Set stack on pedestal. Sim Ops: Clear all unnecessary tools and equipment off floor. Bring split bushings, trip nipples and test plug to floor. Clean up cellar box. Make final cut on 9-5/8" casing - 22" from E-Slips. Install FMC sliplock wellhead. Test metal to metal seals 500/5 min, 3800/10 min (80% casing burst. N/U BOPE: Remove 4" valves from conductor and install caps. Install DSA. raise MPD head to flow box. Set stack on DSA. Install MPD studs. Set MPD head on stack. Observed sliplock nuts were loose with the additional weight of the stack. Begin tightening. SimOps: Clean pits, test gas alarms. While tightening flange from slip lock to lower multibowl observe nuts start stripping. Notified wellhead hand, nuts overtorqued. Test metal to metal seals - good. Change out saver sub, pipe handler dies, level pipe handler to saver sub. Sim Ops: Cut 3 stripped bolts off sliplock flange. Cont. cutting off bolts from sliplock flange. Pick up stack with multibowl off casing stub. Metal seals still on sliplock. Inspect casing - good. Replace stripped bolts, lower stack back onto slip lock, Torque to spec 450 ft-lbs. Retest void 500/5 min 3800/15 minutes - good. Chain off stack and remove bridge cranes. TQ DSA and MPD head. Install drip pan. Hook up choke and kill lines, drain hoses. Install hard iron from MPD choke to rotating head. Install hard iron off MPD head to drain hose and hole fill. SimOps: Change out wash pipe. Install mousehole. SimOps: Change out wash pipe. Install mousehole. Obtain RKB's. M/U 5" test joint with pump in sub, TIW and dart. Daily fluid hauled to G&I 1513 bbls total = 6551 bbls Daily water hauled from A Pad Lake 0 bbls total = 1170 bbls Daily water hauled from B pad creek 650 bbls total = 5070 bbls Daily fluid lost 0 Total= 0 bbls Daily metal recovered 0 lbs, total = 0 lbs 7/28/2020 Flood and purge stack and MPD choke. PT MPD lines 500/1200 psi for 5 minutes - good. Pull RCD plug and install trip nipple. Center stack and air up riser boot. Install 5" test joint. flood stack and lines. Attempt to body test stack. Observe DSA to BOPE flange leaking. Attempt to tighten and re-test, still leaking. Remove drip pan, hook up bridge cranes and remove binders. Break studs and lift stack. C/O API ring and N/U stack. Install 5" test joint and perform body test - good. Test BOPE 250/3000 psi on 5" and 3.5" TJs. AOGCC right to witness waived by Jeff Jones. Check pit high level alarms, PVT sensors, pit & trip G/L alarms, return flow alarm. F/P on superchoke. Accumulator draw down: initial pressure 3000 psi, final 1500 psi, 200 psi recharge 27 sec, full 98 sec. (6)N2 at 2300 psi avg. Rig down testing equpment. Break out test sub from TD. Break down test joint. Pull test joint. Install wear ring. Blow down choke manifold, choke and kill lines. Grease IBOP. M/U 8-1/2" Drill out BHA: 8-1/2" Smith tricone (rerun), Mud motor, float sub, RIH out of derrick with (6) HWDP, Jars, (11) HWDP Pick up, drift (3.125") and single in the hole with 5" drill pipe from 600' to 2123'. PUW 96K, SOW 94K. Break in wash pipe as per procedure: 50 rpms for 1 minute, circulate pipe volume. Check to ensure washpipe tight. Wash and ream from 2123' at 35 gpm, 400 psi, 40 rpm, 4.5Kft-lbs. Tag cement stringer at 2154'. Drill cement, plug and ES cementer (on depth) from 2154' to 2182' with 5-8K WOB, wash down to 2186'. Ream through x 2 and work through with no pumps/rotary (clean). Attempt to RIH on elevators tagging up at 2189' with 15K down. Establish circulation: 375 gpm, 400 psi, 40rpms, 4.5Kft-lbs. Drill cement stringers with 5-15K WOB at 200 fph to 2250' Continue drilling cement stringers with 0-5K WOB 300 fph to 2405' RIH from 2405' to 6288', picking up and drifting (3.125") drill pipe to 3780' (100 total joints). Fill pipe at 4400'. Calculated displacement observed. PUW 184K, SOW 70K. Wash last stand down. Fill pipe and circulate bottoms up at 330 gpm, 680 psi, 40 rpms, 14Kft-lbs. Reciprocating pipe. Flush through choke and kill lines. Shut UPR's. PT casing to 2500 psi for 30 minutes - good. MW 9.0 ppg. Pumped 4.8 bbls, bled back 4.6 bbls. Daily fluid hauled to G&I 1228 bbls total = 6779 bbls Daily water hauled from A Pad Lake 0 bbls total = 1170 bbls Daily water hauled from B pad creek 390 bbls total = 5460 bbls Daily fluid lost 0 Total= 0 bbls Daily metal recovered 0 lbs, total = 0 lbs 7/29/2020 Wash down from 6288' to 6305' (tag BA). Drill out shoe track, cement and 20' of new hole to 6459' (tag baffle adapter, float, and shoe on depth) at 350 gpm, 875 psi, 40 rpms, 15Kft-lbs, WOB 3-10K. PUW 174K, SOW 76K, ROTW 104K. Work through shoe track after drilling each component with no issues. Displace to 8.9 ppg Baradril-N. Pump high vis spacer followed by new mud. 450 gpm, 930 psi, 40 rpms, 14Kft-lbs, reciprocating pipe. Obtain SPR's. Monitor well, static. Rig up and Perform FIT to 12.0 ppg EMW, 613 psi with 8.9 ppg mud. Pumped 1.1 bbls, bled back 1.0 bbls. rig down, blow down choke and kill lines. POOH to 6110', 5 stands, no indication of swabbing. Pump dry job. Cont. to POOH with drill out assembly to 602'. Cont to POOH laying down BHA and excess HWDP. Rack back jar stand. Bit grade same as when picked up 1-1-WT-A-E-1-NO-BHA Clean and clear rig floor. Bring BHA components to rig floor. M/U BHA #3, 8.5" RSS Drilling assembly: NOV PDC bit, NOV, Teo-Pilot, ADR/HCIM, ILS, DGR, PWD, DM,TM, IBS, Float sub. Plug in and attempt to upload to tools, unable to read Geo-Pilot. Pick up to Geo-Pilot/ADR connection, rack back remaining BHA. Plug into Geo-Pilot and obtain good Comms. Plug into ADR, unable to read Geo-Pilot. Mobilize spare ADR from D14. L/D ADR. M/U new ADR and plug in with good Comms. M/U remaining BHA. Plug in and upload MWD tools. M/U flex collars, HW/Jar stand to 283'. Break in Geo-Pilot, shallow pulse test tools - good. Pick up, drift (3.125") and single in the hole with 5" drill pipe from 238' to 6320', fill pipe at 3150'. Calc displacement observed. PUW 150K, SOW 73K. Circulate bottoms up at 415 gpm, 1050 psi, 40 rpms, 14Kft-lbs. Cut and slip 76' drilling line. Check brake air gaps - within specs. Service rig: grease top drive, drawworks, iron roughneck and spinners. Perform crown wobble EAM - within spec. Install MPD bearing: drain stack, remove trip nipple. P/U stand and slip on RCD bearing. Install bearing in stack and tighten clamp. Daily fluid hauled to G&I 1029 bbls total = 7808 bbls Daily water hauled from A Pad Lake 0 bbls total = 1170 bbls Daily water hauled from B pad creek 390 bbls total = 5850 bbls Daily fluid lost 0 Total= 0 bbls Daily metal recovered 0 lbs, total = 0 lbs PT casing to 2500 psi for 30 minutes - good. M 7/30/2020 Flood Beyond Lines and check comms between Canrig and WITS. Establish paramerters at the shoe. Wash down through shoe with no rotary, no issues. Soft Tag btm on depth @ 6459'. Drill 8 1/2" Laterl F/ 6459'' - T/ 7022' (563' total, 102 fph AROP). WOB 10-12K, 550 gpm, 1710 psi, 120 rpm, 15 tq on. 14K tq off, 65% flow, 10.3ppg ECD with 8.9 ppg MW. P/U 172K, S/O 70K, ROT 98K. Max gas 1392U. Drilled in the NB Sands. Crossed Fault #2 at 6780’with 9’throw DTN Drill 8 1/2" Laterl F/7022' - T/ 7922' (900' total, 150 fph AROP). WOB 8K, 550 gpm, 1763 psi, 120 rpm, 16 tq on. 14.5K tq off, 65% flow, 10.5ppg ECD with 8.9 ppg MW. P/U 195K, ROT 98K, lost SOW at 7088'. Max gas 2108U. Backream full stands. MPD choke open. Crossed Fault #3 at 7681' with 73' DTN throw , faulting from NB sands to Ugnu MF. Drill 8 1/2" Laterl F/7922' - T/ 8550' (628' total, 105 fph AROP). WOB 10-15K, 550 gpm, 1840 psi, 120 rpm, 18 tq on. 10.6ppg ECD with 9.0 ppg MW. P/U 207K, ROT 101K. Max gas 1881U. Backream full stands. Seepage loses while drilling with slight ballooning on connections. MPD chokes open. Re-acquire NB-sands at 8363', exiting top of NB-sands at 8,449'. Crossed fault #4 at 8,500' with estimated throw 22' DTS throw from NA-clay to NB-clay. Re- acquiring NB-sands at 8515'. Drill 8 1/2" Laterl F/8550' - T/ 9185' (635' total, 106 fph AROP). WOB 5-15K, 550 gpm, 1950 psi, 120 rpm, 15Kft-lbs tq. 10.99 ppg ECD with 9.0 ppg MW. P/U 150K, SOW 57K ROT 98K. Max gas 1726U. Backream full stands. Observe slight ballooning on connections. MPD chokes open. Increase lube concentrations from 1.5% to 3% to mitigate pipe wobble/surface vibrations. TQ went down from 20Kft-lbs to 15Kft-lbs and regained SOW. Adjust RPMS from 80 to 140 due to pipe wobble/surface vibrations.Adjust flow from 400 gpm to 550 gpm to maintain fluid on shakers (due to gas). Fault #5 crossed at 8756' with estimated 31' DTS throw from the NB-sands to NC-Sand. 4 faults have been crossed so far this lateral (6782', 7681', 8500', 8756'). 7 concretions have been drilled so far, for a total footage of 26’ (1.0% of the lateral). 1,579' Drilled in the NB-sands, 1,082' drilled out of zone. Distance to WP#11: 28.65', 27.97' low, 6.22' right. Daily fluid hauled to G&I 513 bbls total = 8321 bbls Daily water hauled from A Pad Lake 0 bbls total = 1170 bbls Daily water hauled from B pad creek 650 bbls total = 6500 bbls Daily fluid lost 14 Total= 14 bbls Daily metal recovered 0 lbs, total = 0 lbs 7/31/2020 Drill 8 1/2" Lateral F/9185' - T/ 9459' (274' total, 92 fph AROP). WOB 5-15K, 550 gpm, 1930 psi, 140 rpm, 10Kft-lbs tq. 10.9 ppg ECD with 9.0 ppg MW. Max gas 999U. P/U 130K, SOW 70K ROT 94K. Backream full stands. Begin holding 270 psi backpressure on connections to mitigate connection gas. Fault #3 at 7,681’ md (74’ DTN) exhibited more throw than anticipated and resulted in entering the NB-Sand at 8,363’ md. Due to crossing Fault #4 at 8,500’ md, there is likely not enough footage in the previous block to achieve offtake. The operations team made decision to OHST @ 7406’ Pump out of hole from 9459' to 7406' at 445 gpm, 1250 psi, mas gas 894U, ECD 10.5 ppg. Puling speed 60 fpm. PUW 130K, SOW 73K. Holding 230 psi back pressure on connections. Open Hole sidetrack: Begin troughing from 7406' to 7466' 460 gpm, 1220 psi, 80 rpm, 7Kft-lbs, WOB 1-3K with a toolface of 160R. At the end of one pass 2.2° ABI separation was achieved. Work through sidetrack with no rotary and no rotary/pumps with no issues getting into new hole. Drill 8 1/2" Lateral F/7,466' - T/ 7,724' (258' total, 103 fph AROP). WOB 8-10K, 550 gpm, 1775 psi, 120 rpm, 10Kft-lbs tq,10.58 ppg ECD with 9.0 ppg MW. Max gas 1281U. P/U 131K, SOW 81K ROT 105K. Backream full stands. MPD holding 240 psi backpressure on connections to mitigate connection gas. Fault crossed at 7681' with 74'DTN thorw from NC-clay to Ugnu MF. Re-acquired NB sands at 8048'. Drill 8 1/2" Lateral F/7,724' - T/ 8,359' (635' total, 106 fph AROP). WOB 5K, 550 gpm, 1780 psi, 140 rpm, 11Kft-lbs tq,10.74 ppg ECD with 9.0 ppg MW. Max gas 953U. P/U 134K, SOW 77K ROT 101K. Backream full stands. MPD holding 220 psi backpressure on connections to mitigate connection gas. Drill 8 1/2" Lateral F/8,359' - T/ 8,928' (569' total, 95 fph AROP). WOB 5-10K, 550 gpm, 1985 psi, 140 rpm, 12.8Kft-lbs tq,11.0 ppg ECD with 9.0 ppg MW. Max gas 865U. P/U 131K, SOW 73K ROT 98K. Backream full stands. MPD holding 220 psi backpressure on connections to mitigate connection gas. Control drill at 150 fph from 8550' to 8700' due to close approach of I-38 PB1, 4' at 8605'MD. Crossed fault 4 at 8500', estimated 22' DTS from NB- sands to NB-clay, Reacquired NB sands at 8546'. Crossed #5 at 8750' estimated throw 34' DTS from NB-sands to NC-sand. 4 faults have been crossed so far this lateral (6780', 7681', 8500', 8750'). One plugback has been drilled so far (7406' - 9458'). 7 concretions have been drilled so far, for a total footage of 26’ (1.1% of the lateral). 1772' Drilled in NB sands, 664' drilled out of zone. Distance to WP#11 33.48', 27.88' high, 18.55' left. Daily fluid hauled to G&I 855 bbls total = 9176 bbls Daily water from A Pad Lake 0 bbls total =1170 bbls Daily water hauled from B pad creek 390 bbls total =6890 bbls Daily water hauled from L pad lake 390 bbls total=390 bbls Daily fluid lost 0 Total= 14 bbls Daily metal recovered 0 lbs, total=0 lbs 8/1/2020 Drill 8 1/2" Lateral F/8,928' - T/ 9,694' (766' total, 128 fph AROP). WOB 9K, 550 gpm, 2000 psi, 140 rpm, 11Kft-lbs tq,11.17 ppg ECD with 9.1 ppg MW. Max gas 1236U. P/U 135K, SOW 65K ROT 99K. Backream full stands. MPD holding 240 psi backpressure on connections to mitigate connection gas. Crossed fault #6 at 9,070' with 3' DTS throw, did not fault out of zone. Drill 8 1/2" Lateral F/9,694' - T/ 10,394' (700' total, 117 fph AROP). WOB 9-12K, 550 gpm, 2010 psi, 140 rpm, 13Kft-lbs tq,11.0 ppg ECD with 9.0 ppg MW. Max gas 1291U. P/U 148K, SOW 60K ROT 100K. Backream full stands. MPD holding 220 psi backpressure on connections to mitigate connection gas. Drill 8 1/2" Lateral F/10,394' - T/ 10,712' (318' total, 127 fph AROP). WOB 10K, 550 gpm, 2060 psi, 140 rpm, 13.5Kft-lbs tq,11.11 ppg ECD with 9.0 ppg MW. Max gas 1282U. P/U 154K, SOW 55K ROT 99K. Backream full stands. MPD holding 220 psi backpressure on connections to mitigate connection gas. Rack one stand back. Change out swab and line on mud pump 1 pod 1. Circulate at 310 gpm, 1950 psi, 40 rpms, 11.5Kft-lbs, reciprocating pipe. Wash down to 10,712'. Drill 8 1/2" Lateral F/10,712' - T/ 11,030' (318' total, 106 fph AROP). WOB 10-K, 550 gpm, 2073 psi, 140 rpm, 13.5Kft- lbs tq,11.07 ppg ECD with 9.0 ppg MW. Max gas 1086U. P/U 155K, SOW 55K ROT 10K. Backream full stands. MPD holding 220 psi backpressure on connections to mitigate connection gas. Drill 8 1/2" Lateral F/11,030' - T/ 11,575' (545' total, 91 fph AROP). WOB 10-25K, 550 gpm, 2100 psi, 125 rpm, 16Kft-lbs tq,11.7 ppg ECD with 9.1 ppg MW. Max gas 1391U. P/U 135K, SOW 45K ROT 97K. Backream full stands. MPD holding 220 psi backpressure on connections to mitigate connection gas. Drilled out of NB-sands at 11,270''. Obtain final survey prior to POOH for OHST at ~11,210'. 5 faults have been crossed so far this lateral (6780', 7681', 8500', 8750', 9070'). One plugback has been drilled so far (7406' - 9458'). 19 concretions have been drilled so far, for a total footage of 58’ (1.1% of the lateral). 4,122' Drilled in NB sands, 949' drilled out of zone. Distance to WP#11 4.71', 4.25' Low, 2.03' Left Daily fluid hauled to G&I 855 bbls total = 10,031 bbls Daily water from A Pad Lake 0 bbls total =1170 bbls Daily water from B pad creek 0 bbls total =6890 bbls Daily water from L pad lake 0 bbls total=390 bbls Daily water from G pad lagoon 910 bbls total = 910 bbls Daily fluid lost 0 Total= 14 bbls 8/2/2020 Pump out of hole from 11,575' to 11,210' at 30-60 fpm, 460 gpm, 1860 psi, max gas 576U, holding 240 psi back pressure on connections. Sidetrack wellbore from 11,210' to 11,240'. Trough at 25 fph, 490 gpm, 1780 psi, 80 rpms, 13.5Kft-lbs, WOB 2-4K, with 100% deflection at 150R. Observe ABI drop from 91.63° to 91.14° by 11,229', confirming seperation. Work through without pumps/rotary with no issues. Drill 8 1/2" Lateral F/11,240' - T/ 11,408' (168' total, 84 fph AROP). WOB 10- 25K, 550 gpm, 2250 psi, 100 rpm, 14Kft-lbs tq,11.3 ppg ECD with 9.1 ppg MW. Max gas 614U. P/U 143K, SOW 65K ROT 96K. Within the NB sands. Backream full stands. MPD holding 240 psi backpressure on connections. Drill 8 1/2" Lateral F/11,408' - T/ 12,110' (702' total, 117 fph AROP). WOB 5-7K, 550 gpm, 2290 psi, 100 rpm, 15-16Kft-lbs tq,11.69 ppg ECD with 9.1 ppg MW. Max gas 138U. P/U 155K, SOW N/A ROT 97K. Lost SOW at 12,047. Backream full stands. MPD holding 240 psi backpressure on connections. Drilled out the base of NB-sands at 11,577' sands appeared thin with no additional lobe below. Cont. to drill below NB due to close approach of J-25. Drill 8 1/2" Lateral F/12,110' - T/ 12,714' (604' total, 101 fph AROP). WOB 10-12K, 450 gpm, 1775 psi, 140 rpm, 17-18Kft-lbs tq,11.53 ppg ECD with 9.1 ppg MW. Max gas 1125U. P/U 154K, SOW N/A ROT 97K. Backream full stands. MPD holding 240 psi backpressure on connections. Re-acquire NB sands at 12,336'. Closest approach to J-25 at 12,229' with 4.99' separation. Drill 8 1/2" Lateral F/12,714' - T/ 13,255' (541' total, 90 fph AROP). WOB 5-25K, 550 gpm, 2475 psi, 140 rpm, 18.5Kft-lbs tq,11.89 ppg ECD with 9.2 ppg MW. Max gas 1002U. P/U 155K, SOW N/A ROT 95K. Backream full stands. MPD holding 240 psi backpressure on connections. Drilled out top of NB sands at 12,717', re-acquired NB sands 12,807'. 5 faults have been crossed so far this lateral (6780', 7681', 8500', 8750', 9070'). Two plugback has been drilled so far 7406' - 9458' 11,210' - 11,575'. 28 concretions have been drilled so far, for a total footage of 98’ (1.5% of the lateral). 5,153' Drilled in NB sands, 1,568' drilled out of zone. Distance to WP#11 33.01', 11.0' Low, 33', left Daily fluid to G&I 855 bbls total = 10,886 bbls Daily water from A Pad Lake 0 bbls total =1170 bbls Daily water from B pad creek 0 bbls total =6890 bbls Daily water from L pad lake 0 bbls total=390 bbls Daily water from G pad lagoon 1040 bbls total = 1950 bbls Daily fluid lost 0 Total= 14 bbls 8/3/2020 Drill 8 1/2" Lateral F/13,255' - T/ 13,315' (60' total, 120 fph AROP). WOB 5-25K, 550 gpm, 2475 psi, 140 rpm, 18.5Kft-lbs tq,11.89 ppg ECD with 9.15 ppg MW. P/U 155K, SOW N/A ROT 95K. Backream full stands. MPD holding 240 psi backpressure on connections. No communication with Geo-Pilot. Attempt to troubleshoot and downlink to Geo-pilot with no success. BROOH from 13,315' to 10,903' at 25-35 fpm, 500 gpm, 1790 psi, 120 rpms, 13.5Kft-lbs, ECD 11.3 ppg with 9.15 ppg mud. Max gas 969U. PUW 140K, SOW 66K, ROT 103K, hold 240 psi backpressure with MPD on connections. BROOH from 10,903' to 8,486' at 20- 40 fpm as hole dictates, 500 gpm, 1720 psi, 120 rpms, 10Kft-lbs, ECD 10.6 ppg with 9.15 ppg mud. Max gas 485U. PUW 138K, SOW 78K, ROT 105K, hold 240 psi backpressure with MPD on connections. Slight packoffs observed at 8,871 - 8,771' Cont BROOH from 8,486' to 7,130' at 15-25 fpm, 500 gpm, 1462 psi, 120 rpms, 8.5Kft-lbs, ECD 10.35 ppg with 9.15 ppg mud. Max gas 585U. PUW 132K, SOW 83K, ROT 105K, hold 240 psi backpressure with MPD on connections. At 7,544 observe slight pack off, stalling TD at 12.5Kft-lbs (limiter). slack off to nuetral wt with full rotary and circulation (no pack-off). Attempt to work down, setting 50K down no increase in torque. Work pipe with varying parameters down and up working up with no torque increase until pulling ~40K over, jars fired. Attempt to work pipe down, fired jars. Work pipe down to 7589'. Slowly pull up with 10-20K overpull at 7,448' and 7,438'. Work through tight spot, Wash and ream down to 7589' and BROOH without any issues. Cont BROOH from 7,130' to 6,579' at 15-25 fpm, 500 gpm, 1435 psi, 120 rpms, 8.5Kft-lbs, ECD 10.25 ppg with 9.15 ppg mud. Max gas 38U. PUW 132K, SOW 83K, ROT 103K, hold 240 psi backpressure with MPD on connections. Pump tandem low vis/wt and high vis/wt (on time 10% increase) and circulate hole clean 2 x BU reciprocating pipe. 500 gpm, 1435 psi, 120 rpms, 8.5Kft-lbs. ECD 10.36 ppg. No gas. BROOH from 6579' to 6380', slowing rotary to 60 rpms, 8Kft-lbs, 500 gpm, 1435 psi. 1-3K bobble as jars and bit come through shoe. Service rig: grease crown, blocks, top drive, drawworks, iron roughneck, elevators and spinners. Check oil in top drive and welds on cradle. SimOps: start monitoring well. Monitor well through MPD. Open chokes and allow to flow for 5 minutes, shut in for 3 mins repeat multiple times with flow and pressure build diminishing each time. Static in 45 minutes. Open valve on MPD stack and confirm well is static. Pull MPD RCD, install trip nipple. POOH from 6,380' to 6070'. No indication of swabbing. PUW 138K, SOW 98K. Pump dry job. 5 faults have been crossed so far this lateral (6780', 7681', 8500', 8750', 9070') Two plugback has been drilled so far 7406' - 9458' 11,210' - 11,575'. 28 concretions have been drilled so far, for a total footage of 98’ (1.5% of the lateral). 5,153' Drilled in NB sands, 1,568' drilled out of zone. Distance to WP#11 22.89', 13.33' low, 18.61' left Daily fluid to G&I 966 bbls total = 11,852 bbls Daily water from A Pad Lake 0 bbls total =1170 bbls Daily water from B pad creek 0 bbls total =6890 bbls Daily water from L pad lake 0 bbls total=390 bbls Daily water from G pad lagoon 1040 bbls total = 2990 bbls Daily fluid lost 0 Total= 14 bbls 8/4/2020 Continue to POOH on elevators from 6070’ to Surface, racking back all DP (245stands) P/U 49K, SO 48K. Hole fill as calculated. Check Floats and L/D flex collars and Stab. Down Load MWD Data. L/D BHA as per sperry. Found J-Box cover on Geo Pilot Drive was gone with damaged electrical connections. Bit Graded 1-2-CT- A-X-I-DL-DTF PJSM, P/U BHA with new Geo Pilot, DM and TM Collar all other components good. Down Load MWD. Static loss rate @ 3BPH TIH with 8.5" RTSS BHA on 5" DP from 283' to 3715' filling pipe and break in Geo-Pilot @ 3146' no loss Cont RIH W/ 8.5" RSS BHA W/ 5" D.P. F/ 3,715' to 6,325' MD. P/U 115K SLK 86K Calc Disp. PJSM CBU 1.5X ROT REC F/ 6,325' to 6,261' MD. 500 GPM, 1,300 PSI, 40 RPM, TRQ 9.8K, RF 56%. P/U 130K SLK 90K ROT 108K. Max Gas 10U Monitor well for 30 min till static. Int flow 3.5 bph slowing to zero. PJSM Drain Stack and remove RCD clamp. Pull bushing and remove trip nipple. Install RCD Bearing as per Beyond. M/U RCD clamp. Flood MPD choke lines and Circ at 400 GPM/ MPD 393 GPM 916 PSI. ECD 9.85. PJSM Cont RIH 5" D.P on elevators F/ 6,261' to 7,770' MD. Observed 10K bobble at Shoe (6,429' MD) At 7,700 performed check survey to ensure we did not enter plug back at 7,406' MD. 500 GPM / MPD 465 GPM, 1,450 PSI, ECD 9.74. P/U 135K SLK 85K. PJSM Cont RIH 5" D.P on elevators F/ 7,770' to 12,115' MD. Lost down weight. P/U 152K SLK 35K Pass through plug back W/O issue. Fill pipe at 12,700' MD. PJSM Started washing down stands F/ 12,115' to 13,315' MD. Initial pump rate 430 GPM reduced to 350 GPM due Gas and shakers running over. At 12,488' started holding 190 PSI W/ MPD to control Gas. Max Gas 1,931U. F/ 13,062' to 13,315' MD started staging up pump rate to 550 GPM. 550 GPM/ MPD 560, 2,190 PSI, 80 RPM TRQ 14.5K, P/U 145K SLK 35K ROT 95K. Calc Disp 109 bbls, actual 103 bbls lost 6 bbls. Cont Drill 8.5" Production Hole F/ 13,315' to 13,380' MD ( 3,914' TVD) Total 65’ (AROP 160’) 550 GPM/ MPD 531, 2,180 PSI, 100 RPM, TRQ on 14.8K, TRQ off 14.5K, WOB 5K. ECD 11.06 .P/U 145K, SLK 35K, ROT 95K. Max Gas 224U. MPD full open, static 230 PSI 10.3 ppg EMW W/ 9.2.ppg MW. 5 faults have been crossed so far this lateral (6780', 7681', 8500', 8750', 9070'). Two plugback has been drilled so far 7406' - 9458' 11,210' - 11,575'. 28 concretions have been drilled so far, for a total footage of 98’ (1.5% of the lateral). 5,153' Drilled in NB sands, 1,568' drilled out of zone. Daily fluid to G&I 57 bbls total = 11,909 bbls Daily water from A Pad Lake 0 bbls total =1170 bbls Daily water from B pad creek 0 bbls total =6890 bbls Daily water from L pad lake 0 bbls total=390 bbls Daily water from G pad lagoon 130 bbls total = 3120 bbls Daily fluid lost formation = 12 bbls Total lost for Production = 12 bbls. Total lost on surface= 14 bbls 8/5/2020 PJSM Drill 8.5" Production Hole F/ 13,380' to 13,986' MD ( 3,924' TVD) Total 606’ (AROP 101’) 550 GPM/ MPD 533, 2,105 PSI, 140 RPM, TRQ on 20.5K, TRQ off 19.5K, WOB 5K. ECD 11.12 .P/U 151K, SLK 35K, ROT 99K. Max Gas 1,293U. MPD full open, static 240 PSI 10.3 ppg EMW W/ 9.2.ppg MW. Back ream 60'. SPR @ 13,825' (3,919' TVD) W/ 9.2 MW. MP #1 32-481, 48-547. MP #2 32-477, 48-546. MPD 140 PSI PJSM Drill 8.5" Production Hole F/ 13,986' to 14,590' MD ( 3,941' TVD) Total 604’ (AROP 100.6’) 550 GPM/ MPD 523, 2,190 PSI, 120 RPM, TRQ on 21K, TRQ off 20K, WOB 12-16K. ECD 11.18 .P/U 178K, SLK 35K, ROT 101K. Max Gas 1,131U. MPD full open, static 240 PSI 10.3 ppg EMW W/ 9.2.ppg MW. Back ream 60'. SPR @ 14,524' (3,940' TVD) W/ 9.15 MW. MP #1 32-440, 48-510. MP #2 32-440, 48-510. MPD 130 PSI PJSM Drill 8.5" Production Hole F/ 14,590' to 15,099' MD ( 3,944' TVD) Total 509’ (AROP 84.8’) 490 GPM/ MPD 485, 1,740 PSI, 120 RPM, TRQ on 23.5K, TRQ off 22K, WOB 3K. ECD 10.9 .P/U 182K, SLK 35K, ROT 101K. Max Gas 1,138U. MPD full open, static 220 PSI 10.2 ppg EMW W/ 9.2.ppg MW. Back ream 60'. Did clean up cycle at 14,847’ to 14,969’ MD. Hole unloading heavy sand at shakers W/ max gas 1,138U. ECD reduced F/ 11.18 to 11.06.After clean up cycles at 14,975’ MD encountered dynamic losses ~24 BPH W/ 550 GPM/ F/O 508 GPM 2,110 PSI. Reduced rate to 530 GPM F/O 485 GPM 2,017 PSI. At 15,025’ MD reduced to 490 GPM F/O 455 GPM 1,760 PSI. Dynamic loss rate 14 BPH. Max Gas 702U. Heavy oil at Shakers blinding screens off at 15,095’ reduced flow F/ 500 GPM/ F/O 467 GPM 1,813 PSI to 350 GPM/ F/O 336 GPM 1,207 PSI used MPD dynamic shut in 80 PSI 10.95 ECD. Max Gas 683U. Screened down F/ 230 -200's to 170's and cont Circ hole clean staging up pump rate Rot & Rec 15,099' to 15,039' MD F/ 350 GPM to 500 GPM F/O 468 GPM. 1,828 PSI 120 RPM TRQ 21-23K, ECD 11.04. Max Gas 721U running water at 40 bph to build volume. Lost about 100 bbls over Shakers and 24 bbls down hole. PJSM Drill 8.5" Production Hole F/ 15,099' to TD 15,500' MD ( 3,953' TVD) Total 401’ (AROP 100.2’) 430/500 GPM/ MPD 406/480, 1,420/1,950 PSI, 140 RPM, TRQ on 24.5K, TRQ off 21-23K, WOB 5-10K. ECD 11.36 .P/U 183K, SLK 35K, ROT 98K. Max Gas 902U. MPD full open, static 220 PSI 10.2 ppg EMW W/ 9.2.ppg MW. Adjusted pump parameters F/ 430 to 550 GPM as needed to keep shaker from over loading. Back ream 60'. Obtain final survey at TD 15,500' MD 88.15° Inc 23.90° Azi SPR @ 15,500' (3,953' TVD) W/ 9.2 MW. MP #1 32-518, 48-588. MP #2 32-523, 48-595. MPD 140 PSI PJSM Pump Tandem Sweeps 40 bbls 8.6 ppg 31 Vis, 40 bbl 10.0 ppg 190 Vis ROT REC F/ 15,500' to 15,440' MD 500 GPM/ MPD 475 GPM, 1,925 PSI 130-140 RPM, 25-26K TRQ, ECD 11.24, Max Gas 748U. Distance to WP# 11: 2.16', 1.51' Low, 1.55' Left 5 faults have been crossed so far this lateral (6780', 7681', 8500', 8750', 9070'). Two plugback has been drilled so far 7406' - 9458' 11,210' - 11,575'. 39 concretions have been drilled so far, for a total footage of 134’ (1.5% of the lateral). 7,503' Drilled in NB sands, 1,568' drilled out of zone. Daily fluid to G&I 1,259 bbls total = 13,168 bbls Daily water from A Pad Lake 0 bbls total =1170 bbls Daily water from B pad creek 0 bbls total =6890 bbls Daily water from L pad lake 0 bbls total=390 bbls Daily water from G pad lagoon 1200 bbls total = 4320 bbls Daily fluid lost formation = 24 bbls Total lost for Production = 44 bbls. Total lost on surface= 14 bbls 8/6/2020 PJSM Cont Rot Rec F/ 15,500 to 15,440' MD 500 GPM, MPD 475 GPM, 1,925 PSI, 130-140 RPM, 25-26K TRQ. ECD 11.24, Max Gas 229U. Dynamic loss 14 BPH. Sweep back as Calc W/ 10% increase. SIMOPS Off load mud F/ Pits, Clean Pits and bring on new 9.3 ppg Quickdril. Stage trucks for displacement. PJSM Pump 40 bbl SAPP and 20 bbl 9.3 Qucikdril sweeps 3X. Displace W/ 9.3 ppg Quickdril taking returns to cutting box. 370 GPM/ MPD 356 GPM, 1,000 PSI, 130 RPM, 25K TRQ, ECD 10.7. Max Gas 76U. P/U 183K SLK 35K ROT 98K. Monitor well shut in MPD 150 PSI decreased to 120 PSI 10 Min. SPR at 15,500' (3,953' TVD) MW 9.3. MP #1 32-370, 48-440. MP #2 32-370, 48-440. MPD hold 100 PSI. PJSM BROOH F/ 15,500 to 14,399' MD Drop 2.38" OD Drift. 475 GPM/ MPD 465 GPM, 1,560 PSI, 120 RPM, 20K TRQ, ECD 10.76, Max Gas 714U. P/U 186K SLK 35K ROT 108K. Pull speed 15-25 ft/min as hole dictates. MPD holding static 180-190 PSI during connections. PJSM BROOH F/ 14,399 to 12,492' MD 500 GPM/ MPD 480 GPM, 1,565 PSI, 120 RPM, 16.5K TRQ, ECD 10.54, Max Gas 198U. P/U 172K SLK 35K ROT 102K. Pull speed 15-25 ft/min as hole dictates. MPD holding static 190-200 PSI during connections. Dynamic loss 3-10 BPH Lost 84 bbls for tour. PJSM BROOH F/ 12,492 to 9,900' MD 500 GPM/ MPD 480 GPM, 1,490 PSI, 120 RPM, 12.5K TRQ, ECD 10.54, Max Gas 404U. P/U 146K SLK 63K ROT 98K. Pull speed 15-35 ft/min as hole dictates. MPD holding static 185-200 PSI during connections. Dynamic loss 3-5 BPH Lost 19.8 bbls for tour. Work slight pack off at 12,030' MD 2X W/O issue. Got down weight back at 12,200' MD. Daily fluid to G&I 2,160 bbls total = 15,328 bbls Daily water from A Pad Lake 0 bbls total =1170 bbls Daily water from B pad creek 0 bbls total =6890 bbls Daily water from L pad lake 0 bbls total=390 bbls Daily water from G pad lagoon 780 bbls total = 5,100 bbls Daily fluid lost formation = 84 bbls Total lost for Production = 128 bbls. Total lost on surface= 14 bbls 8/7/2020 PJSM BROOH F/ 9,900 to 6,612' MD 500 GPM/ MPD 487 GPM, 1,320 PSI, 120 RPM, 8.5K TRQ, ECD 10.5, Max Gas 165U. P/U 135K SLK 81K ROT 101K. Pull speed 30-40 ft/min as hole dictates. MPD holding static 185-200 PSI during connections. Dynamic loss 3-5 BPH Lost 24 bbls for tour. PJSM BROOH F/ 6,612 to 6,345' MD 500 GPM/ MPD 487 GPM, 1,350 PSI, 120 RPM, 9.2K TRQ, ECD 10.5, Max Gas 165U. P/U 138K SLK 81K ROT 101K. Pull speed 10-15 ft/min as hole dictates. MPD holding static 185-200 PSI during connections. Pull thru Shoe 6,429' W/O ROT no issue. PJSM Pump 40 bbl 9.3 ppg 212 Vis sweep. Rot Rec F/ 6,356' to 6,293' MD 500 GPM/ MPD 493, 1,275 PSI, 50 RPM 9k TRQ, ECD 10.16. P/U 142 SLK 85K ROT 105K. Monitor well 20 min. Shut in MPD 150 PSI, Open choke 20 GPM tapering to 0.5 GPM. Shut in choke 20 PSI over 3 min. open choke, static. Sweep back as Calc no increase. PJSM Bull bushings and remove grey loc clamp. Pull RCD Bearing. Set bushings and break stand. M/U Bearing puller and strip off RCD Bearinf F/ Stand. Set riser on stump, M/U Stand pull bushings and install riser. Install bushings. PJSM Hang Blocks, cut 16 warps (100' 20' excess) 1,025 ACUMTM. Slip on drilling line. No line left on spool. Check Drawwork brakes. Check Deadman bolts TRQ 80 ft/lb. Inspect Top Drive coffin for leak, could not find any in front of panel. Very slight. PJSM Service rig. Grease Crown, Blocks and Top Drive. Service Iron Roughneck. Monitor well static. PJSM POOH L/D 5" D.P. F/ 6,356' to 6,070' MD to Pipe Shed. No swabbing. Pump 25 bbl 10.3 ppg corrosion inhibited Dry Job. B/D Top Drive and Geo Span. Cont POOH L/D 5" D.P. to Pipe Shed F/ 6,070' to 283' MD. P/U 86K SLK 72K Cull pipe as per tally for CAT5 inspection. Lost 36 bbls. PJSM L/D 5" HWDP, Jars, NM FC, remove corrosion ring, retrieve drift F/ top float sub. TRQ lift Sub and start uploading MWD. L/D TM, DM, ADR, Geo Pilot and 8.5" Bit as per Sperry. Bit Grade 2- 3-BT-S-X-I-ER-TD Significant wear on wear sleeve of ADR-DGR-PWD and compensator of Geo Pilot. PJSM Clean and clear rig floor of BHA components . PJSM C/O 5" Elevators to 4.5" 125T. Bring up 4.5" handling Equip. R/U Weatherford Tongs and Equip. Bring 52 ea 4.5" X 7" Centralizers and Stop Rings. Open Blind Rams hole took 8 bbls to fill, static loss rate ~4 BPH. PJSM P/U M/U Innovex Solid Guide Shoe W 2 ea 7" Centralizers and 4 stop rings RIH W/ 4.5" Production Screens W625 W/ 7" Centralizers as per tally to 1,891' MD. P/U 62K SLK 60K. TRQ W625 9.6K. Drift 3.8" OD. Calc 6 bbls, actual 12.1 bbls, lost 12.1 BBls. Daily fluid to G&I 171 bbls total = 15,499 bbls Daily water from A Pad Lake 0 bbls total =1170 bbls Daily water from B pad creek 0 bbls total =6890 bbls Daily water from L pad lake 0 bbls total=390 bbls Daily water from G pad lagoon 390 bbls total = 5,490 bbls Daily fluid lost formation = 60 bbls Total lost for Production = 188 bbls. Total lost on surface= 14 bbls 8/8/2020 PJSM Cont RIH 4.5" Production Screens F/ 1,891' to 8,317' MD as per tally. P/U 117K SLK 66K. TRQ W625 9.6K. Drift 3.80" OD. Calc 38 bbls, actual -23 bbls, lost 61 bbls. PJSM Cont RIH 4.5" Production Screens F/ 8,317' to 8,997' MD as per tally. P/U 117K SLK 66K. TRQ W625 9.6K. Drift 3.80" OD. Calc 6 bbls, actual 1.1 bbls, lost 4.9 bbls. P/U M/U SLZXP Liner Hanger as per Baker Rep. Installed 2 3/8" Ball Seat Assy on SLZXP. M/U to 4.5" string. Found 4 broken drill bits in screens while drifting. R/D Weatherford tools and Equip. Ran total 53 4.5" X 7" Centralizers and 55 Stop Rings. 51 ea 4.5" Blanks. 143 ea Pro Mesh. 22 ea Petro Gaurd PJSM Fix Hydraulic leak on Top Drive. Service/ inspect Iron Roughneck. L/D Weatherford 4.5" handling Equip and tongs. PJSM Convey 4.5" Production Liner W/ 5" D.P. F/ Derrick F/ 8,997' to 10,905' MD. Single in W/ 5" HWDP F/ Skate F/ 10,905' to 13,995' MD. Drift 2.75" OD. 9,061' MD pump through SLZXP 84 GPM, 80 PSI, 168 GPM 265 PSI. P/U 195k SLK 95K. Calc 83 bbls, actual 58 bbls lost 25 bbls Cont Convey 4.5" Production Liner W/ 5" D.P. F/ Derrick F/ 13,995' to 15,243' MD. P/U 245K SLK 88K. Work tight spot at 14,850' MD. PJSM Circ drill string volume 5 bpm 625 PSI. At 15,243' MD Drop 29/32" Phenolic Ball. Pump down at Int 4 bpm 450 PSI, slow to 2 bpm 220 PSI at 900 stcks, ball seated 200 strcks earlly. Cont Press up SLZXP set at 3,011 psi rig floor confirmation. Held for 2 min. SLK off 33K F/ 88K to 55K. Change to test pump and cont Press up to 4,246 PSI released released F/ HRDE Press bled to 0. SLK to 55K. P/U to 200K released dog sub F/ SLZXP. TOL at 6,246' MD. PJSM Flood lines and work out air. Close Annular Bag. Test SLZXP seals to 1,500 PSI for 10 min on chart, good. Pump 2.2 bbls, bled back 1.9 bbls. Bleed down and open Annular Bag. R/D test Equip. PJSM Rack back 1 stand F/ 6,288' to 6,236' MD. CBU 1.5X 450 GPM, 1,015 PSI, Max Gas 304U. P/U 200K SLK 105K. Dynamic loss 1 bph. Monitor well for 30 min int flow 4 bph to static. PJSM POOH L/D 5" D.P. F/ 6,236' to 5,916' MD. P/U 200K SLK 120K Cull CAT5 in Pipe Shed. PJSM Pump 20 bbl 10.4 ppg Dry Job. Install Hydraulic Elevators, stripping rubber and air slips. POOH L/D 5" D.P & 5" HWDP F/ 5,916' to 1,100' MD. Cull CAT5 in Pipe Shed. P/U 64K SLK 64K. Calc Disp 70 bbls , actual 87 bbls, lost 17 bbls. Daily fluid to G&I 187 bbls total = 15,686 bbls Daily water from A Pad Lake 0 bbls total =1170 bbls Daily water from B pad creek 0 bbls total =6890 bbls Daily water from L pad lake 0 bbls total=390 bbls Daily water from G pad lagoon 0 bbls total = 5,490 bbls Daily fluid lost formation = 109 bbls Total lost for Production = 297 bbls. Total lost on surface= 14 bbls SLZXP seals to 1,500 PSI for 10 min on chart, good. Production Screens F/ / 13,995' to 15,243' MD. Activity Date Ops Summary 8/9/2020 Continue to POOH L/D 5" DP f/1100' to HRD Running tool. Inspect and L/D Tool,Service Rig, Greaser and Inspect Crown, Blocks, and Top Drive.,M/U 3.5" Stinger w/8.4" OD Go-Go. RIH on elevators to 6231'. M/U Top Drive and RIH and tag TOL @ 6260'. Bring on pumps and wash out of liner top @ 525 gpm.,Work Pipe from 6255-6199' and CBU @ 525 gpm, 485psi. P/U 137K, S/O 89K,POOH L/D All the 5" DP F/6199' and No/Go. Pumped corrosion inhibited Dry Job. Cull D.P. in Pipe Shed for CAT5 inspection. SIMOPS Transfer new drilling line to spooler. Lost 30 bbls.,PJSM M/U running tool to 5" D.P. Jnt. Pull Wear Ring and set test plug. L/D 5" D.P.,PJSM Shut Blind Rams and de energize Koomey. Open doors, clean and inspect ram cavity. Remove upper 2.875" X 5.5" variable rams. Install 7.625" solid body rams. Tighten doors. SIMOPS R/U test Equip, M/U 5" Dart, 5" TIW, side entry to test joint.M/U test sub to Top Drive.,PJSM Perform BOPE test W/ 3.5" & 7.625" to 250 PSI low and 3,000 PSI high for 5 Min. Tested Choke Manifold 1-15, 5" Dart, 5" TIW, Upper and lower IBOP, Mez Kill, HCR and manual Choke and Kill, manual and Super Choke to 1,600 PSI, Upper 7.625” Solid Body and lower VRB Rams (2,875" X 5.5") Blind Rams, Annular W/ 3.5" & 7.625” test Jnt. Koomey draw drown Initial System 3,025 PSI, Manifold 1,350 PSI, Annular 1,125 PSI, after,System 1,610 PSI, Man 1,500 PSI, Annular 1,200 PSI. 200 PSI increase 20 Sec, full charge 78 sec. Nitrogen 6 bottle average 2,268 PSI. Test H2S 10-20 ppm, LEL 20-40%, PVT high/ low level alarms. Witnessed waived by AOGCC Rep Bob Noble. SIMOPS: R/D test jnt & Equip. 13 bbls to fill hole.,Daily fluid to G&I 187 bbls total = 15,686 bbls Daily water from A Pad Lake 0 bbls total =1170 bbls Daily water from B pad creek 0 bbls total =6890 bbls Daily water from L pad lake 0 bbls total=390 bbls Daily water from G pad lagoon 0 bbls total = 5,490 bbls,Daily fluid lost formation = 60 bbls Total lost for Production = 357 bbls. Total lost on surface= 14 bbls 8/10/2020 Cont rigging down test Equip. Pull test plug, blow down Choke and lines.,PJSM Remove 5" Hyd Elevators and install 200T 7.625" elevators. Bring up 7.625" handling Equip. R/U Weatherford tongs. Dummy run 7.625" fluted hanger as per NOS. 24.5' RKB.,PJSM P/U M/U Seal Assy as per Baker Rep W/ 7.625" 29.7# L- 80 W521 Tie Back to 3,299' MD. P/U 109K SLK 90K. TRQ W521 10.3K. Calc 31.0 bbls, actual 13.8 bbls, lost 16.3 bbls.,PJSM Cont RIH 7.625" Tie Back F/ 3,299' to 6,720' MD. Set down 20K on No/Go. P/U test seals to 500 PSI. P/U L/D 3 Jnts (155,156,157) and M/U 14.79' Pup and 1 jnt (155) P/U M/U 7.625" Hanger and landing Jnt. Install X/O and 5' 5" Pup and kelly up. P/U 169K SLK 103K. TRQ W521 10.3K. Calc 38.7 bbls, actual 26.2 bbls, lost 12.5 bbls.,PJSM Land Hanger and close Annular Bag. Press up to 500 PSI and P/U to expose 1" ports, Press dumped. Reverse Circ at 3 bpm 305 PSI 400 bbls 9.3 ppg Corrosion Inhibited Brine FCP 165 PSI taking returns to cutting box. Pump 50 bbls Diesel 3 bpm 440 PSI. Clear lines W/ 10 bbl Brine. Unload remaining brine to pits.,PJSM Land 7.625" Hanger Shoe at 6,267.98' MD 1.63' off No/Go 7.98' seals swallowed. Weight on Hanger 68K. Bleed off Press. Open Annular and R/D Circ. Equip. Back out and L/D Landing Jnt. Drain Stack. C/O Elevators and P/U 5" D.P. install X/U and Pack Off. Land Pack Off and RILDS. Test 500 low 5 min, 5,000 high 10 min. Witnessed by Co Rep. Pull Mouse Hole and L/D 5" D.P. & X/O.,PJSM R/U HP hose to annular 9 5/8" X 7 5/8". Flood lines and test 9 5/8" X 7 5/8" annular to 1,000 PSI for 30 min on chart. Pump 2.2 bbls bled back 1.9 bbls.,PJSM R/D blow down test Equip. Clean and clear rig floor 7.625" handling Equip. Blow down Top Drive. 10 bbls to fill hole.,PJSM C/O 5"elevators to 75T 3.5". Bring up Weatherford tools and Equip. R/U Weatherford tongs and Equip. Bring up 100 ea Cannon Clamps. Bring up and hand ESP Sheave. Run ESP and CAP through Sheave in Derrick. Static loss rate 2 bph.,PJSM P/U M/U ESP as per Centrilift. Centralizer, Zenith Sensor, 250 hp 562EP Motor, Upper and Lower Tandem Seals, Gas Avoider, Gas Separator, 538PM SXD 20 Pump. Oil and work air out of pump Assy. 2 bph static loss rate.,Daily fluid to G&I 632 bbls total = 16,318 bbls Daily water from A Pad Lake 0 bbls total =1170 bbls Daily water from B pad creek 0 bbls total =6890 bbls Daily water from L pad lake 0 bbls total=390 bbls Daily water from G pad lagoon 0 bbls total = 5,490 bbls,Daily fluid lost formation = 61 bbls Total lost for Production = 418 bbls. Total lost on surface= 14 bbls 8/11/2020 PJSM M/U ESP and test. Cont P/U M/U ESP Aassy as per Centrilift. 538PM SXD 086 Flex47 Pump, Zenith ported sub 513/538P, Discharge Head PMP 513 3.5: X EUE and pup. Splice discharge Press line. 2 bph static loss. Installed 1 ea Protectorlizer, 2 ea Motor Clamp, 4 ea Seal Clamp, 6 ea Pump Clamps.,PJSM RIH ESP on 3.5" 9.3# L-80 EUE 8rd F/ 86' to 1,787' MD Test CAP every 2,000' and ESP every 1,000'. TRQ EUE 3.2K. Place Cannon Clamps as per tally. P/U 55K SLK 52K. Calc 7.2 bbls, Actual 6.2 bbls, lost 13.4 bbls.,PJSM Cont RIH ESP on 3.5" 9.3# L-80 EUE 8rd F/ 1,787' to 5,165' MD Test CAP every 2,000' and ESP every 1,000'. TRQ EUE 3.2K. Place Cannon Clamps as per tally. P/U 85K SLK 60K. Calc 21.16 bbls, Actual 6.6 bbls, lost 15 bbls.,PJSM P/U M/U Hanger & landing Jnt. Test ESP and CAP. Splice ESP to Penetrator and terminate CAP to Hanger. Land Hanger on depth 5,192' MD W/ 25K. RILDS as per NOS. L/D landing jnt. Set Modified BPV. R/D 3.5" tools and Equip. Total 95 ea CC ran. 40 jnts left over, good. PH-PH 2.8, PH-GND 1.86g, PI 1,699, PD 1,697, TI 72.1, TM 71.9, VX .068, VY .007, VT 120.9, CT 10.0,PJSM Johnny Whack Stack. Flush BOPE and lines. Flush Gas Buster. Blow down all surface lines. Clean drip pan in cellar. Prep for N/D BOP.,PJSM 4 bolt BOP. Bleed down Koomey. Remove upper drip pan, Beyond hard lines and R/U bridge cranes. Raise stack to drain and set back down. Prep for C/O Upper Rams. SINOPS load 5" D.P. in Pipe Shed, flush MP's and clean pits.,PJSM Open upper ram doors and C/I F/ 7.625" solid bods to 2.875" X 5.5" VRBS rams.,PJSM Install Beyond test cap. Remove Koomey hoses, choke & kill lines. Hook up slings top drive slings to RCD. Unbolt RCD and remove from BOP. Set BOP back on pedestal and secure. Prep for installing Dry Hole Tree. SIMOPS Perform PM's on MP's. Cont cleaning pits. Prep I-39. Clear rig floor.,SIMOPS LRS Freeze Protect I-38 22 bbls Diesel 2 bpm 500 PSI, IA 70 bbls Diesel 2 bpm 520 PSI.,Daily fluid to G&I 260 bbls total = 16,587 bbls Daily water from A Pad Lake 0 bbls total =1170 bbls Daily water from B pad creek 0 bbls total =6890 bbls Daily water from L pad lake 0 bbls total=390 bbls Daily water from G pad lagoon 0 bbls total = 5,490 bbls,Daily fluid lost formation = 48 bbls Total lost for Production = 466 bbls. Total lost on surface= 14 bbls 50-029-23684-00-00API #: Well Name: Field: County/State: MP I-38 Milne Point Hilcorp Energy Company Composite Report , Alaska 7/21/2020Spud Date: Tie Back Land Hanger and close Annular Bag. Land 7.625" Hanger Shoe at 6,267.98' MD Flood lines and test 9 5/8" X 7 5/8" annular to 1,000 PSI for 30 min on chart. P TD Shoe Depth: PBTD: No. Jts. Returned RKB RKB to BHF RKB to THF Jts. 2 1 103 51 X Yes No X Yes No 80 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated?X Yes No Reciprocated?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: 1.17 7/27/2020 27 Spud Mud Type I/II 612 2.35 Class G 400 1.15 4.9 2,157.83 Casing 9 5/8 47.0 L-80 TXP Tenaris 2,122.56 2,157.83 35.27 2,179.63 2,176.81 Pup Joint 9 5/8 40.0 L-80 TXP Tenaris 18.98 2,176.81 17.92 2,197.55 2,179.63 ES Cementer 10 3/4 40.0 L-80 TXP HES 2.82 Pup Joint 9 5/8 40.0 L-80 TXP Tenaris 6,305.50 Casing 9 5/8 40.0 L-80 TXP Tenaris 4,107.95 6,305.50 2,197.55 6,346.62 6,306.89 Baffle Adapter 10 3/4 40.0 L-80 TXP HES 1.39 6,306.89 1.29 6,347.91 6,346.62 Casing 9 5/8 40.0 L-80 TXP Tenaris 39.73 Float Collar 10 3/4 40.0 L-80 BTC Innovex 2 on joint 1, 1 every joint to 5431', 1 every third joint to 2400', 1 every joint to 1952' (5 before and after ES cementer), 1 every third joint to 240'. Casing 9 5/8 40.0 L-80 TXP Tenaris 79.49 6,427.40 6,347.91 www.wellez.net WellEz Information Management LLC ver_04818br 5.5 8.3420Water 3 Ftg. Returned 313.92 Ftg. Cut Jt.29.17 Ftg. Balance No. Jts. Delivered 167 No. Jts. Run 159 8 Length Measurements W/O Threads Ftg. Delivered 6,705.07 Ftg. Run 6,401.80 26.60 RKB to CHF Type of Shoe:Bullnose Casing Crew:Weatherford 12 256 Water #N/A Closure OK 5.5208.34 55 ArcticCem Type Class G 264 Tuned spacer 587 2.94 Stage Collar @ 50 Bump press 100 238 6,429.006,439.00 CEMENTING REPORT Csg Wt. On Slips:115,000 Spud Mud 14:55 7/26/2020 2,177 2176.81 15.8 82 Bump press Returns Bump Plug? Y 3.6 9.4 3 140.1/139.8 476.9/472.8 1270 46 RigFIRST STAGE10Tuned Spacer 60 15.8 600 9.4 3 2100 10 10.7 308 4 100 700 Bump Plug? Csg Wt. On Hook:270,000 Type Float Collar:Conventional No. Hrs to Run:14 9 5/8 47.0 L-80 TXP Tenaris BTC Innovex 1.60 6,429.00 6,427.40 10.65 35.27 24.62 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.MP I-38 Date Run 25-Jul-20 OK Remarks: CASING RECORD County State Alaska Supv.S Barber/ C Montague 6,346.00 Floats Held 404.87 701 284 417 Spud Mud / Spacer Rotate Csg Recip Csg Ft. Min. PPG9.4 Shoe @ 6429 FC @ Top of Liner #N/A SECOND STAGERig 1:00 Returns 349 WELLHEAD Make Type Serial No.FMC MIN 361.6 3.6 Size W.P. Test head to PSIG Casing (Or Liner) Detail Shoe Cut Joint 10 3/4 40.0 L-80 07 August, 2020 Milne Point M Pt I Pad MPU I-38 500292368400 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: MPU I-38 usft usft 0.00 0.00 6,009,451.89 551,509.84 33.80Wellhead Elevation:33.80 usft0.50 70° 26' 11.661 N 149° 34' 48.112 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-38 Model NameMagnetics IFR 7/23/2020 15.89 80.86 57,377.70000000 Phase:Version: Audit Notes: Design MPU I-38 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:11,149.33 16.750.000.0026.60 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 8/6/2020 Survey Date 3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing100.00 867.00 MPU I-38PB1 E-Line Gyro (MPU I-38PB1 07/15/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa929.14 6,401.54 MPU I-38PB1 MWD+IFR2+MS+Sag (1) (07/22/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa6,443.67 7,398.12 MPU I-38PB1 MWD+IFR2+MS+Sag (2) (07/30/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa7,406.00 11,149.33 MPU I-38PB2 MWD+IFR2+MS+Sag (3) (07/31/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa11,210.00 15,431.78 MPU I-38 MWD+IFR2+MS+Sag (4) (MPU 08/03/2020 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 26.60 0.00 0.00 26.60 0.00 0.00-33.80 6,009,451.89 551,509.84 0.00 0.00 UNDEFINED 100.00 0.46 324.50 100.00 0.24 -0.1739.60 6,009,452.13 551,509.67 0.63 0.18 3_Gyro-GC_Csg (1) 200.00 0.61 271.25 200.00 0.58 -0.94139.60 6,009,452.46 551,508.90 0.50 0.28 3_Gyro-GC_Csg (1) 300.00 0.60 311.84 299.99 0.94 -1.86239.59 6,009,452.82 551,507.98 0.42 0.36 3_Gyro-GC_Csg (1) 363.00 0.51 255.31 362.99 1.09 -2.38302.59 6,009,452.96 551,507.46 0.84 0.36 3_Gyro-GC_Csg (1) 423.00 0.58 255.12 422.99 0.94 -2.93362.59 6,009,452.81 551,506.91 0.12 0.06 3_Gyro-GC_Csg (1) 490.00 1.23 243.65 489.98 0.54 -3.90429.58 6,009,452.40 551,505.94 1.00 -0.61 3_Gyro-GC_Csg (1) 553.00 2.48 219.93 552.94 -0.81 -5.38492.54 6,009,451.04 551,504.47 2.29 -2.33 3_Gyro-GC_Csg (1) 612.00 4.40 213.55 611.83 -3.67 -7.45551.43 6,009,448.16 551,502.42 3.31 -5.67 3_Gyro-GC_Csg (1) 678.00 5.54 208.10 677.59 -8.60 -10.35617.19 6,009,443.22 551,499.55 1.87 -11.21 3_Gyro-GC_Csg (1) 8/7/2020 5:36:02PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 739.00 6.30 214.03 738.26 -13.97 -13.61677.86 6,009,437.83 551,496.33 1.60 -17.30 3_Gyro-GC_Csg (1) 803.00 7.26 219.14 801.81 -20.01 -18.13741.41 6,009,431.75 551,491.85 1.77 -24.39 3_Gyro-GC_Csg (1) 867.00 9.90 228.94 865.09 -26.76 -24.83804.69 6,009,424.96 551,485.20 4.70 -32.79 3_Gyro-GC_Csg (1) 929.14 13.42 232.67 925.94 -34.65 -34.60865.54 6,009,417.01 551,475.49 5.79 -43.15 3_MWD+IFR2+MS+Sag (2) 991.71 16.55 237.76 986.38 -43.81 -47.91925.98 6,009,407.76 551,462.24 5.42 -55.76 3_MWD+IFR2+MS+Sag (2) 1,056.19 18.80 240.43 1,047.81 -53.84 -64.72987.41 6,009,397.61 551,445.50 3.71 -70.20 3_MWD+IFR2+MS+Sag (2) 1,118.13 21.25 242.57 1,106.00 -63.93 -83.361,045.60 6,009,387.39 551,426.93 4.13 -85.25 3_MWD+IFR2+MS+Sag (2) 1,183.52 23.28 245.70 1,166.52 -74.71 -105.661,106.12 6,009,376.46 551,404.71 3.59 -101.99 3_MWD+IFR2+MS+Sag (2) 1,246.43 26.83 247.13 1,223.50 -85.35 -130.081,163.10 6,009,365.65 551,380.36 5.72 -119.22 3_MWD+IFR2+MS+Sag (2) 1,310.16 30.28 247.73 1,279.47 -97.03 -158.211,219.07 6,009,353.78 551,352.32 5.43 -138.51 3_MWD+IFR2+MS+Sag (2) 1,374.12 33.97 248.78 1,333.63 -109.61 -189.801,273.23 6,009,340.98 551,320.82 5.83 -159.66 3_MWD+IFR2+MS+Sag (2) 1,437.83 34.30 250.03 1,386.36 -122.19 -223.271,325.96 6,009,328.17 551,287.44 1.22 -181.35 3_MWD+IFR2+MS+Sag (2) 1,501.43 36.45 252.43 1,438.22 -134.01 -258.131,377.82 6,009,316.11 551,252.67 4.02 -202.72 3_MWD+IFR2+MS+Sag (2) 1,564.84 37.86 255.24 1,488.76 -144.66 -294.901,428.36 6,009,305.21 551,215.97 3.48 -223.51 3_MWD+IFR2+MS+Sag (2) 1,628.40 40.81 256.80 1,537.92 -154.37 -334.001,477.52 6,009,295.23 551,176.95 4.89 -244.08 3_MWD+IFR2+MS+Sag (2) 1,692.28 44.14 259.53 1,585.03 -163.18 -376.211,524.63 6,009,286.13 551,134.80 5.96 -264.68 3_MWD+IFR2+MS+Sag (2) 1,755.56 45.88 260.10 1,629.77 -171.09 -420.251,569.37 6,009,277.91 551,090.82 2.82 -284.95 3_MWD+IFR2+MS+Sag (2) 1,819.28 48.75 260.45 1,672.96 -179.00 -466.421,612.56 6,009,269.69 551,044.72 4.52 -305.83 3_MWD+IFR2+MS+Sag (2) 1,883.18 49.91 260.60 1,714.61 -186.98 -514.221,654.21 6,009,261.38 550,996.97 1.82 -327.24 3_MWD+IFR2+MS+Sag (2) 1,947.05 49.32 260.28 1,755.99 -195.06 -562.201,695.59 6,009,252.97 550,949.06 1.00 -348.81 3_MWD+IFR2+MS+Sag (2) 2,010.60 50.52 259.92 1,796.90 -203.42 -610.101,736.50 6,009,244.28 550,901.22 1.94 -370.62 3_MWD+IFR2+MS+Sag (2) 2,073.80 50.55 260.42 1,837.08 -211.75 -658.171,776.68 6,009,235.62 550,853.21 0.61 -392.45 3_MWD+IFR2+MS+Sag (2) 2,137.07 52.13 260.46 1,876.60 -219.96 -706.891,816.20 6,009,227.08 550,804.56 2.50 -414.35 3_MWD+IFR2+MS+Sag (2) 2,200.76 51.50 260.58 1,915.97 -228.20 -756.271,855.57 6,009,218.49 550,755.24 1.00 -436.47 3_MWD+IFR2+MS+Sag (2) 2,264.43 51.15 261.61 1,955.76 -235.90 -805.371,895.36 6,009,210.46 550,706.19 1.38 -457.99 3_MWD+IFR2+MS+Sag (2) 2,327.73 51.66 260.84 1,995.25 -243.44 -854.271,934.85 6,009,202.57 550,657.36 1.25 -479.31 3_MWD+IFR2+MS+Sag (2) 2,390.99 51.00 261.26 2,034.77 -251.13 -903.061,974.37 6,009,194.55 550,608.63 1.16 -500.73 3_MWD+IFR2+MS+Sag (2) 2,455.08 51.02 260.90 2,075.10 -258.85 -952.272,014.70 6,009,186.49 550,559.48 0.44 -522.31 3_MWD+IFR2+MS+Sag (2) 2,518.47 51.01 261.19 2,114.98 -266.52 -1,000.942,054.58 6,009,178.49 550,510.86 0.36 -543.68 3_MWD+IFR2+MS+Sag (2) 2,581.89 51.74 259.59 2,154.57 -274.80 -1,049.792,094.17 6,009,169.88 550,462.08 2.28 -565.68 3_MWD+IFR2+MS+Sag (2) 2,645.30 51.19 259.67 2,194.07 -283.73 -1,098.582,133.67 6,009,160.61 550,413.35 0.87 -588.29 3_MWD+IFR2+MS+Sag (2) 2,709.39 51.36 259.97 2,234.17 -292.56 -1,147.792,173.77 6,009,151.44 550,364.21 0.45 -610.94 3_MWD+IFR2+MS+Sag (2) 2,773.28 51.81 261.65 2,273.87 -300.56 -1,197.212,213.47 6,009,143.10 550,314.85 2.18 -632.83 3_MWD+IFR2+MS+Sag (2) 2,837.15 52.06 264.22 2,313.25 -306.74 -1,247.102,252.85 6,009,136.58 550,265.01 3.19 -653.13 3_MWD+IFR2+MS+Sag (2) 2,900.04 52.09 266.52 2,351.91 -310.74 -1,296.542,291.51 6,009,132.23 550,215.60 2.89 -671.22 3_MWD+IFR2+MS+Sag (2) 2,963.55 53.13 268.59 2,390.47 -312.89 -1,346.952,330.07 6,009,129.74 550,165.21 3.06 -687.80 3_MWD+IFR2+MS+Sag (2) 3,025.52 53.42 272.60 2,427.54 -312.37 -1,396.602,367.14 6,009,129.91 550,115.56 5.21 -701.61 3_MWD+IFR2+MS+Sag (2) 3,090.97 54.85 276.41 2,465.89 -308.19 -1,449.462,405.49 6,009,133.73 550,062.68 5.20 -712.84 3_MWD+IFR2+MS+Sag (2) 3,153.91 56.12 279.65 2,501.56 -300.93 -1,500.802,441.16 6,009,140.63 550,011.30 4.70 -720.69 3_MWD+IFR2+MS+Sag (2) 3,217.54 57.89 283.47 2,536.22 -290.23 -1,553.062,475.82 6,009,150.97 549,958.97 5.75 -725.50 3_MWD+IFR2+MS+Sag (2) 8/7/2020 5:36:02PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,281.59 56.60 286.24 2,570.88 -276.43 -1,605.122,510.48 6,009,164.41 549,906.82 4.16 -727.29 3_MWD+IFR2+MS+Sag (2) 3,345.17 57.60 285.92 2,605.41 -261.64 -1,656.412,545.01 6,009,178.84 549,855.43 1.63 -727.91 3_MWD+IFR2+MS+Sag (2) 3,408.61 57.41 286.62 2,639.50 -246.65 -1,707.782,579.10 6,009,193.47 549,803.97 0.98 -728.36 3_MWD+IFR2+MS+Sag (2) 3,470.73 57.85 284.84 2,672.76 -232.43 -1,758.282,612.36 6,009,207.34 549,753.38 2.52 -729.30 3_MWD+IFR2+MS+Sag (2) 3,536.32 58.34 283.12 2,707.42 -218.98 -1,812.312,647.02 6,009,220.42 549,699.26 2.35 -731.99 3_MWD+IFR2+MS+Sag (2) 3,599.19 58.58 282.82 2,740.31 -206.96 -1,864.522,679.91 6,009,232.08 549,646.97 0.56 -735.52 3_MWD+IFR2+MS+Sag (2) 3,663.46 58.61 283.58 2,773.80 -194.43 -1,917.932,713.40 6,009,244.24 549,593.49 1.01 -738.92 3_MWD+IFR2+MS+Sag (2) 3,726.84 58.27 283.84 2,806.97 -181.63 -1,970.392,746.57 6,009,256.67 549,540.94 0.64 -741.78 3_MWD+IFR2+MS+Sag (2) 3,790.23 58.61 284.50 2,840.15 -168.41 -2,022.762,779.75 6,009,269.53 549,488.48 1.04 -744.22 3_MWD+IFR2+MS+Sag (2) 3,853.96 57.55 283.32 2,873.85 -155.40 -2,075.272,813.45 6,009,282.18 549,435.90 2.29 -746.89 3_MWD+IFR2+MS+Sag (2) 3,917.15 55.49 283.30 2,908.70 -143.27 -2,126.562,848.30 6,009,293.95 549,384.53 3.26 -750.05 3_MWD+IFR2+MS+Sag (2) 3,981.09 55.95 283.73 2,944.72 -130.92 -2,177.932,884.32 6,009,305.94 549,333.08 0.91 -753.04 3_MWD+IFR2+MS+Sag (2) 4,043.45 57.60 284.35 2,978.88 -118.26 -2,228.532,918.48 6,009,318.25 549,282.40 2.77 -755.50 3_MWD+IFR2+MS+Sag (2) 4,108.49 57.93 286.74 3,013.58 -103.52 -2,281.532,953.18 6,009,332.63 549,229.30 3.15 -756.65 3_MWD+IFR2+MS+Sag (2) 4,171.99 57.19 289.13 3,047.65 -87.02 -2,332.512,987.25 6,009,348.77 549,178.21 3.38 -755.55 3_MWD+IFR2+MS+Sag (2) 4,235.18 56.89 293.24 3,082.04 -67.87 -2,381.933,021.64 6,009,367.58 549,128.67 5.48 -751.45 3_MWD+IFR2+MS+Sag (2) 4,298.95 57.57 296.26 3,116.56 -45.42 -2,430.613,056.16 6,009,389.69 549,079.83 4.12 -743.99 3_MWD+IFR2+MS+Sag (2) 4,362.78 58.68 299.69 3,150.27 -19.99 -2,478.473,089.87 6,009,414.78 549,031.81 4.88 -733.43 3_MWD+IFR2+MS+Sag (2) 4,426.42 60.16 302.55 3,182.65 8.33 -2,525.363,122.25 6,009,442.78 548,984.73 4.51 -719.82 3_MWD+IFR2+MS+Sag (2) 4,489.88 61.01 305.71 3,213.82 39.34 -2,571.103,153.42 6,009,473.47 548,938.78 4.54 -703.31 3_MWD+IFR2+MS+Sag (2) 4,553.54 61.28 308.58 3,244.55 73.01 -2,615.543,184.15 6,009,506.82 548,894.11 3.97 -683.88 3_MWD+IFR2+MS+Sag (2) 4,617.44 61.78 311.01 3,275.02 108.96 -2,658.693,214.62 6,009,542.47 548,850.72 3.43 -661.89 3_MWD+IFR2+MS+Sag (2) 4,680.61 62.58 314.17 3,304.50 146.76 -2,699.813,244.10 6,009,579.99 548,809.34 4.60 -637.54 3_MWD+IFR2+MS+Sag (2) 4,744.09 64.27 315.22 3,332.90 186.69 -2,740.163,272.50 6,009,619.64 548,768.72 3.05 -610.93 3_MWD+IFR2+MS+Sag (2) 4,807.74 65.30 317.43 3,360.02 228.34 -2,779.923,299.62 6,009,661.01 548,728.68 3.53 -582.51 3_MWD+IFR2+MS+Sag (2) 4,871.34 65.84 320.78 3,386.33 272.11 -2,817.823,325.93 6,009,704.50 548,690.48 4.87 -551.52 3_MWD+IFR2+MS+Sag (2) 4,934.72 67.74 324.07 3,411.31 318.27 -2,853.333,350.91 6,009,750.42 548,654.66 5.63 -517.55 3_MWD+IFR2+MS+Sag (2) 4,998.78 67.82 326.25 3,435.54 366.94 -2,887.203,375.14 6,009,798.85 548,620.45 3.15 -480.71 3_MWD+IFR2+MS+Sag (2) 5,062.44 68.99 328.46 3,458.97 416.78 -2,919.133,398.57 6,009,848.46 548,588.19 3.71 -442.19 3_MWD+IFR2+MS+Sag (2) 5,126.00 68.64 329.71 3,481.94 467.62 -2,949.573,421.54 6,009,899.09 548,557.39 1.91 -402.27 3_MWD+IFR2+MS+Sag (2) 5,188.76 68.28 329.99 3,504.98 518.10 -2,978.893,444.58 6,009,949.36 548,527.73 0.71 -362.39 3_MWD+IFR2+MS+Sag (2) 5,253.17 66.96 330.94 3,529.51 569.92 -3,008.253,469.11 6,010,000.96 548,498.01 2.46 -321.23 3_MWD+IFR2+MS+Sag (2) 5,317.20 65.63 332.62 3,555.25 621.57 -3,035.983,494.85 6,010,052.42 548,469.93 3.18 -279.76 3_MWD+IFR2+MS+Sag (2) 5,379.75 68.84 333.87 3,579.45 673.07 -3,061.933,519.05 6,010,103.73 548,443.63 5.45 -237.93 3_MWD+IFR2+MS+Sag (2) 5,443.44 69.82 334.93 3,601.93 726.81 -3,087.683,541.53 6,010,157.29 548,417.51 2.19 -193.89 3_MWD+IFR2+MS+Sag (2) 5,506.96 70.34 334.82 3,623.58 780.88 -3,113.043,563.18 6,010,211.17 548,391.79 0.83 -149.42 3_MWD+IFR2+MS+Sag (2) 5,570.47 72.13 335.65 3,644.01 835.48 -3,138.223,583.61 6,010,265.60 548,366.23 3.08 -104.39 3_MWD+IFR2+MS+Sag (2) 5,634.24 71.80 337.50 3,663.75 891.11 -3,162.333,603.35 6,010,321.06 548,341.74 2.81 -58.07 3_MWD+IFR2+MS+Sag (2) 5,697.75 73.40 338.63 3,682.74 947.33 -3,184.963,622.34 6,010,377.11 548,318.72 3.04 -10.76 3_MWD+IFR2+MS+Sag (2) 5,761.34 75.99 340.99 3,699.53 1,004.89 -3,206.123,639.13 6,010,434.52 548,297.17 5.42 38.26 3_MWD+IFR2+MS+Sag (2) 8/7/2020 5:36:02PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 5,825.34 76.81 342.95 3,714.58 1,064.04 -3,225.373,654.18 6,010,493.52 548,277.51 3.24 89.35 3_MWD+IFR2+MS+Sag (2) 5,888.66 75.92 346.07 3,729.51 1,123.33 -3,241.813,669.11 6,010,552.69 548,260.67 4.99 141.39 3_MWD+IFR2+MS+Sag (2) 5,952.32 76.80 348.57 3,744.52 1,183.68 -3,255.383,684.12 6,010,612.94 548,246.68 4.06 195.27 3_MWD+IFR2+MS+Sag (2) 6,015.59 79.33 351.09 3,757.61 1,244.60 -3,266.303,697.21 6,010,673.78 548,235.33 5.58 250.45 3_MWD+IFR2+MS+Sag (2) 6,079.29 81.92 353.17 3,767.98 1,306.85 -3,274.903,707.58 6,010,735.96 548,226.31 5.19 307.58 3_MWD+IFR2+MS+Sag (2) 6,142.80 83.70 355.71 3,775.93 1,369.55 -3,281.013,715.53 6,010,798.62 548,219.77 4.86 365.87 3_MWD+IFR2+MS+Sag (2) 6,206.64 83.64 358.33 3,782.97 1,432.91 -3,284.303,722.57 6,010,861.95 548,216.04 4.08 425.59 3_MWD+IFR2+MS+Sag (2) 6,270.00 83.62 1.69 3,790.01 1,495.87 -3,284.293,729.61 6,010,924.90 548,215.61 5.27 485.88 3_MWD+IFR2+MS+Sag (2) 6,333.99 84.25 1.96 3,796.77 1,559.47 -3,282.273,736.37 6,010,988.51 548,217.20 1.07 547.37 3_MWD+IFR2+MS+Sag (2) 6,401.54 88.22 2.00 3,801.20 1,626.82 -3,279.943,740.80 6,011,055.86 548,219.06 5.88 612.53 3_MWD+IFR2+MS+Sag (2) 6,443.67 89.44 2.28 3,802.06 1,668.91 -3,278.373,741.66 6,011,097.96 548,220.34 2.97 653.29 3_MWD+IFR2+MS+Sag (3) 6,507.64 88.95 0.89 3,802.96 1,732.85 -3,276.603,742.56 6,011,161.90 548,221.67 2.30 715.03 3_MWD+IFR2+MS+Sag (3) 6,571.50 89.87 0.29 3,803.62 1,796.70 -3,275.943,743.22 6,011,225.75 548,221.89 1.72 776.36 3_MWD+IFR2+MS+Sag (3) 6,635.02 90.00 0.23 3,803.69 1,860.22 -3,275.653,743.29 6,011,289.27 548,221.74 0.23 837.27 3_MWD+IFR2+MS+Sag (3) 6,699.01 90.43 0.22 3,803.45 1,924.21 -3,275.403,743.05 6,011,353.25 548,221.55 0.67 898.61 3_MWD+IFR2+MS+Sag (3) 6,762.25 90.12 0.20 3,803.15 1,987.45 -3,275.173,742.75 6,011,416.48 548,221.34 0.49 959.23 3_MWD+IFR2+MS+Sag (3) 6,826.08 91.48 0.45 3,802.26 2,051.27 -3,274.813,741.86 6,011,480.30 548,221.26 2.17 1,020.45 3_MWD+IFR2+MS+Sag (3) 6,887.94 91.48 0.58 3,800.66 2,113.11 -3,274.253,740.26 6,011,542.13 548,221.39 0.21 1,079.82 3_MWD+IFR2+MS+Sag (3) 6,951.61 91.42 0.25 3,799.05 2,176.76 -3,273.793,738.65 6,011,605.77 548,221.41 0.53 1,140.91 3_MWD+IFR2+MS+Sag (3) 7,014.70 91.36 0.57 3,797.52 2,239.83 -3,273.343,737.12 6,011,668.84 548,221.43 0.52 1,201.43 3_MWD+IFR2+MS+Sag (3) 7,080.13 90.62 359.86 3,796.39 2,305.24 -3,273.093,735.99 6,011,734.25 548,221.22 1.57 1,264.14 3_MWD+IFR2+MS+Sag (3) 7,143.77 90.99 359.67 3,795.49 2,368.88 -3,273.353,735.09 6,011,797.88 548,220.52 0.65 1,325.00 3_MWD+IFR2+MS+Sag (3) 7,207.39 90.92 359.86 3,794.43 2,432.49 -3,273.613,734.03 6,011,861.48 548,219.82 0.32 1,385.84 3_MWD+IFR2+MS+Sag (3) 7,270.93 91.54 359.53 3,793.07 2,496.01 -3,273.953,732.67 6,011,924.99 548,219.05 1.11 1,446.57 3_MWD+IFR2+MS+Sag (3) 7,334.84 91.85 359.36 3,791.18 2,559.89 -3,274.573,730.78 6,011,988.86 548,217.99 0.55 1,507.56 3_MWD+IFR2+MS+Sag (3) 7,398.12 91.85 0.05 3,789.13 2,623.14 -3,274.903,728.73 6,012,052.09 548,217.22 1.09 1,568.03 3_MWD+IFR2+MS+Sag (3) 7,406.00 91.87 0.07 3,788.88 2,631.01 -3,274.893,728.48 6,012,059.97 548,217.18 0.36 1,575.57 3_MWD+IFR2+MS+Sag (4) 7,461.19 89.44 0.89 3,788.25 2,686.19 -3,274.433,727.85 6,012,115.14 548,217.26 4.65 1,628.54 3_MWD+IFR2+MS+Sag (4) 7,524.78 86.97 1.47 3,790.24 2,749.73 -3,273.123,729.84 6,012,178.69 548,218.13 3.99 1,689.76 3_MWD+IFR2+MS+Sag (4) 7,588.73 85.18 2.34 3,794.62 2,813.49 -3,271.003,734.22 6,012,242.45 548,219.81 3.11 1,751.43 3_MWD+IFR2+MS+Sag (4) 7,651.96 85.12 2.30 3,799.96 2,876.45 -3,268.453,739.56 6,012,305.42 548,221.92 0.11 1,812.45 3_MWD+IFR2+MS+Sag (4) 7,715.23 84.62 2.19 3,805.62 2,939.41 -3,265.983,745.22 6,012,368.39 548,223.96 0.81 1,873.46 3_MWD+IFR2+MS+Sag (4) 7,779.29 83.88 2.15 3,812.04 3,003.11 -3,263.563,751.64 6,012,432.09 548,225.93 1.16 1,935.14 3_MWD+IFR2+MS+Sag (4) 7,842.97 84.31 2.32 3,818.59 3,066.40 -3,261.093,758.19 6,012,495.40 548,227.96 0.73 1,996.46 3_MWD+IFR2+MS+Sag (4) 7,906.41 84.80 2.88 3,824.61 3,129.49 -3,258.233,764.21 6,012,558.50 548,230.39 1.17 2,057.70 3_MWD+IFR2+MS+Sag (4) 7,969.52 86.48 2.75 3,829.41 3,192.34 -3,255.143,769.01 6,012,621.36 548,233.05 2.67 2,118.77 3_MWD+IFR2+MS+Sag (4) 8,033.18 86.97 2.42 3,833.04 3,255.83 -3,252.273,772.64 6,012,684.86 548,235.47 0.93 2,180.39 3_MWD+IFR2+MS+Sag (4) 8,096.84 89.19 2.88 3,835.18 3,319.38 -3,249.333,774.78 6,012,748.43 548,237.98 3.56 2,242.10 3_MWD+IFR2+MS+Sag (4) 8,160.67 90.43 2.64 3,835.39 3,383.13 -3,246.263,774.99 6,012,812.20 548,240.61 1.98 2,304.03 3_MWD+IFR2+MS+Sag (4) 8,224.42 89.69 3.06 3,835.32 3,446.80 -3,243.093,774.92 6,012,875.88 548,243.34 1.33 2,365.92 3_MWD+IFR2+MS+Sag (4) 8/7/2020 5:36:02PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,287.83 89.63 2.64 3,835.70 3,510.14 -3,239.943,775.30 6,012,939.23 548,246.05 0.67 2,427.47 3_MWD+IFR2+MS+Sag (4) 8,351.55 90.25 3.18 3,835.76 3,573.77 -3,236.703,775.36 6,013,002.88 548,248.85 1.29 2,489.34 3_MWD+IFR2+MS+Sag (4) 8,414.77 90.06 4.82 3,835.59 3,636.84 -3,232.293,775.19 6,013,065.96 548,252.82 2.61 2,551.00 3_MWD+IFR2+MS+Sag (4) 8,478.31 90.49 6.63 3,835.29 3,700.06 -3,225.953,774.89 6,013,129.22 548,258.72 2.93 2,613.36 3_MWD+IFR2+MS+Sag (4) 8,541.45 91.67 5.99 3,834.10 3,762.80 -3,219.013,773.70 6,013,192.00 548,265.23 2.13 2,675.44 3_MWD+IFR2+MS+Sag (4) 8,605.19 90.31 8.46 3,833.00 3,826.02 -3,211.003,772.60 6,013,255.27 548,272.81 4.42 2,738.29 3_MWD+IFR2+MS+Sag (4) 8,668.48 90.49 11.13 3,832.55 3,888.38 -3,200.233,772.15 6,013,317.70 548,283.14 4.23 2,801.10 3_MWD+IFR2+MS+Sag (4) 8,732.04 91.17 12.88 3,831.63 3,950.54 -3,187.023,771.23 6,013,379.94 548,295.93 2.95 2,864.44 3_MWD+IFR2+MS+Sag (4) 8,795.64 92.10 13.67 3,829.82 4,012.41 -3,172.423,769.42 6,013,441.91 548,310.10 1.92 2,927.89 3_MWD+IFR2+MS+Sag (4) 8,859.30 93.21 14.52 3,826.87 4,074.09 -3,156.933,766.47 6,013,503.68 548,325.15 2.20 2,991.42 3_MWD+IFR2+MS+Sag (4) 8,923.43 93.39 14.16 3,823.18 4,136.12 -3,141.073,762.78 6,013,565.82 548,340.58 0.63 3,055.38 3_MWD+IFR2+MS+Sag (4) 8,986.88 92.84 13.13 3,819.73 4,197.68 -3,126.133,759.33 6,013,627.48 548,355.10 1.84 3,118.64 3_MWD+IFR2+MS+Sag (4) 9,050.66 90.67 11.09 3,817.78 4,260.01 -3,112.763,757.38 6,013,689.89 548,368.04 4.67 3,182.18 3_MWD+IFR2+MS+Sag (4) 9,114.11 89.94 9.34 3,817.44 4,322.45 -3,101.513,757.04 6,013,752.40 548,378.86 2.99 3,245.21 3_MWD+IFR2+MS+Sag (4) 9,177.53 88.89 7.15 3,818.09 4,385.21 -3,092.413,757.69 6,013,815.21 548,387.52 3.83 3,307.93 3_MWD+IFR2+MS+Sag (4) 9,240.95 89.87 5.69 3,818.77 4,448.22 -3,085.323,758.37 6,013,878.27 548,394.17 2.77 3,370.31 3_MWD+IFR2+MS+Sag (4) 9,304.41 90.74 5.72 3,818.44 4,511.37 -3,079.013,758.04 6,013,941.45 548,400.04 1.37 3,432.60 3_MWD+IFR2+MS+Sag (4) 9,367.87 91.36 6.08 3,817.27 4,574.48 -3,072.493,756.87 6,014,004.60 548,406.13 1.13 3,494.91 3_MWD+IFR2+MS+Sag (4) 9,431.64 90.87 6.50 3,816.03 4,637.85 -3,065.513,755.63 6,014,068.01 548,412.68 1.01 3,557.61 3_MWD+IFR2+MS+Sag (4) 9,495.27 88.76 6.79 3,816.24 4,701.05 -3,058.143,755.84 6,014,131.25 548,419.60 3.35 3,620.25 3_MWD+IFR2+MS+Sag (4) 9,558.61 88.58 6.76 3,817.71 4,763.93 -3,050.673,757.31 6,014,194.18 548,426.64 0.29 3,682.61 3_MWD+IFR2+MS+Sag (4) 9,622.25 87.65 6.74 3,819.80 4,827.10 -3,043.203,759.40 6,014,257.39 548,433.67 1.46 3,745.25 3_MWD+IFR2+MS+Sag (4) 9,685.95 87.65 6.54 3,822.41 4,890.32 -3,035.843,762.01 6,014,320.65 548,440.60 0.31 3,807.91 3_MWD+IFR2+MS+Sag (4) 9,749.80 87.65 5.68 3,825.03 4,953.75 -3,029.053,764.63 6,014,384.12 548,446.95 1.35 3,870.61 3_MWD+IFR2+MS+Sag (4) 9,813.32 87.90 5.03 3,827.50 5,016.94 -3,023.123,767.10 6,014,447.35 548,452.43 1.10 3,932.83 3_MWD+IFR2+MS+Sag (4) 9,876.73 87.47 4.22 3,830.06 5,080.10 -3,018.013,769.66 6,014,510.53 548,457.11 1.45 3,994.77 3_MWD+IFR2+MS+Sag (4) 9,940.26 86.23 5.18 3,833.55 5,143.31 -3,012.823,773.15 6,014,573.78 548,461.87 2.47 4,056.81 3_MWD+IFR2+MS+Sag (4) 10,003.98 86.23 5.84 3,837.74 5,206.60 -3,006.713,777.34 6,014,637.10 548,467.53 1.03 4,119.17 3_MWD+IFR2+MS+Sag (4) 10,067.76 86.04 5.86 3,842.04 5,269.91 -3,000.233,781.64 6,014,700.44 548,473.58 0.30 4,181.66 3_MWD+IFR2+MS+Sag (4) 10,131.49 87.53 6.08 3,845.61 5,333.19 -2,993.613,785.21 6,014,763.76 548,479.76 2.36 4,244.16 3_MWD+IFR2+MS+Sag (4) 10,195.30 89.07 6.14 3,847.51 5,396.61 -2,986.823,787.11 6,014,827.22 548,486.11 2.42 4,306.85 3_MWD+IFR2+MS+Sag (4) 10,258.86 88.76 7.22 3,848.71 5,459.72 -2,979.433,788.31 6,014,890.38 548,493.07 1.77 4,369.41 3_MWD+IFR2+MS+Sag (4) 10,322.34 88.95 8.17 3,849.98 5,522.62 -2,970.933,789.58 6,014,953.32 548,501.13 1.53 4,432.09 3_MWD+IFR2+MS+Sag (4) 10,385.75 88.08 9.19 3,851.62 5,585.28 -2,961.363,791.22 6,015,016.04 548,510.26 2.11 4,494.85 3_MWD+IFR2+MS+Sag (4) 10,449.69 87.09 9.46 3,854.31 5,648.32 -2,951.013,793.91 6,015,079.14 548,520.18 1.60 4,558.20 3_MWD+IFR2+MS+Sag (4) 10,513.21 87.09 10.54 3,857.54 5,710.79 -2,940.003,797.14 6,015,141.69 548,530.76 1.70 4,621.19 3_MWD+IFR2+MS+Sag (4) 10,576.84 87.09 11.07 3,860.77 5,773.21 -2,928.083,800.37 6,015,204.18 548,542.24 0.83 4,684.40 3_MWD+IFR2+MS+Sag (4) 10,640.23 87.59 10.89 3,863.71 5,835.37 -2,916.023,803.31 6,015,266.42 548,553.87 0.84 4,747.40 3_MWD+IFR2+MS+Sag (4) 10,703.91 87.47 10.27 3,866.46 5,897.91 -2,904.343,806.06 6,015,329.03 548,565.12 0.99 4,810.65 3_MWD+IFR2+MS+Sag (4) 10,767.71 87.65 10.20 3,869.17 5,960.64 -2,893.023,808.77 6,015,391.83 548,576.01 0.30 4,873.98 3_MWD+IFR2+MS+Sag (4) 8/7/2020 5:36:02PM COMPASS 5000.15 Build 91E Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 10,831.30 89.87 11.01 3,870.55 6,023.13 -2,881.323,810.15 6,015,454.39 548,587.28 3.72 4,937.19 3_MWD+IFR2+MS+Sag (4) 10,894.90 88.51 9.77 3,871.45 6,085.67 -2,869.853,811.05 6,015,517.01 548,598.31 2.89 5,000.39 3_MWD+IFR2+MS+Sag (4) 10,958.81 89.63 10.16 3,872.48 6,148.61 -2,858.793,812.08 6,015,580.01 548,608.93 1.86 5,063.84 3_MWD+IFR2+MS+Sag (4) 11,022.37 89.62 9.95 3,872.90 6,211.19 -2,847.693,812.50 6,015,642.67 548,619.60 0.33 5,126.97 3_MWD+IFR2+MS+Sag (4) 11,085.63 91.79 9.93 3,872.12 6,273.49 -2,836.773,811.72 6,015,705.03 548,630.08 3.43 5,189.77 3_MWD+IFR2+MS+Sag (4) 11,149.33 91.54 10.91 3,870.27 6,336.12 -2,825.263,809.87 6,015,767.73 548,641.16 1.59 5,253.05 3_MWD+IFR2+MS+Sag (4) 11,210.00 92.07 11.27 3,868.36 6,395.62 -2,813.593,807.96 6,015,827.31 548,652.42 1.06 5,313.40 3_MWD+IFR2+MS+Sag (5) 11,275.65 88.95 12.60 3,867.78 6,459.84 -2,800.023,807.38 6,015,891.61 548,665.55 5.17 5,378.80 3_MWD+IFR2+MS+Sag (5) 11,339.63 87.46 14.13 3,869.78 6,522.06 -2,785.243,809.38 6,015,953.92 548,679.89 3.34 5,442.64 3_MWD+IFR2+MS+Sag (5) 11,403.40 86.79 13.72 3,872.98 6,583.87 -2,769.913,812.58 6,016,015.84 548,694.79 1.23 5,506.25 3_MWD+IFR2+MS+Sag (5) 11,466.80 87.03 13.96 3,876.40 6,645.34 -2,754.773,816.00 6,016,077.41 548,709.51 0.53 5,569.48 3_MWD+IFR2+MS+Sag (5) 11,530.61 86.35 12.52 3,880.08 6,707.35 -2,740.183,819.68 6,016,139.51 548,723.67 2.49 5,633.06 3_MWD+IFR2+MS+Sag (5) 11,594.21 86.29 10.87 3,884.16 6,769.50 -2,727.313,823.76 6,016,201.74 548,736.10 2.59 5,696.28 3_MWD+IFR2+MS+Sag (5) 11,657.34 86.60 8.46 3,888.08 6,831.61 -2,716.743,827.68 6,016,263.91 548,746.25 3.84 5,758.80 3_MWD+IFR2+MS+Sag (5) 11,720.66 86.35 6.65 3,891.97 6,894.26 -2,708.433,831.57 6,016,326.61 548,754.13 2.88 5,821.19 3_MWD+IFR2+MS+Sag (5) 11,784.38 86.54 5.50 3,895.92 6,957.50 -2,701.703,835.52 6,016,389.89 548,760.42 1.83 5,883.68 3_MWD+IFR2+MS+Sag (5) 11,848.26 86.35 5.97 3,899.88 7,020.94 -2,695.333,839.48 6,016,453.36 548,766.35 0.79 5,946.26 3_MWD+IFR2+MS+Sag (5) 11,911.61 87.46 6.91 3,903.30 7,083.79 -2,688.233,842.90 6,016,516.26 548,773.01 2.29 6,008.50 3_MWD+IFR2+MS+Sag (5) 11,975.31 88.89 7.63 3,905.33 7,146.95 -2,680.173,844.93 6,016,579.46 548,780.63 2.51 6,071.29 3_MWD+IFR2+MS+Sag (5) 12,038.88 90.49 8.56 3,905.68 7,209.88 -2,671.223,845.28 6,016,642.45 548,789.15 2.91 6,134.14 3_MWD+IFR2+MS+Sag (5) 12,102.59 91.73 9.52 3,904.44 7,272.78 -2,661.223,844.04 6,016,705.42 548,798.72 2.46 6,197.26 3_MWD+IFR2+MS+Sag (5) 12,166.27 92.72 10.69 3,901.97 7,335.43 -2,650.053,841.57 6,016,768.13 548,809.45 2.41 6,260.46 3_MWD+IFR2+MS+Sag (5) 12,229.21 91.36 11.24 3,899.73 7,397.18 -2,638.093,839.33 6,016,829.95 548,820.99 2.33 6,323.04 3_MWD+IFR2+MS+Sag (5) 12,292.83 91.97 11.21 3,897.88 7,459.55 -2,625.713,837.48 6,016,892.41 548,832.93 0.96 6,386.34 3_MWD+IFR2+MS+Sag (5) 12,357.02 92.10 10.20 3,895.60 7,522.59 -2,613.793,835.20 6,016,955.52 548,844.41 1.59 6,450.13 3_MWD+IFR2+MS+Sag (5) 12,420.88 92.35 9.18 3,893.12 7,585.49 -2,603.053,832.72 6,017,018.48 548,854.72 1.64 6,513.45 3_MWD+IFR2+MS+Sag (5) 12,482.72 91.91 9.92 3,890.82 7,646.43 -2,592.803,830.42 6,017,079.49 548,864.55 1.39 6,574.76 3_MWD+IFR2+MS+Sag (5) 12,545.28 91.36 11.68 3,889.04 7,707.85 -2,581.083,828.64 6,017,140.98 548,875.84 2.95 6,636.96 3_MWD+IFR2+MS+Sag (5) 12,610.75 90.98 13.66 3,887.70 7,771.71 -2,566.733,827.30 6,017,204.93 548,889.75 3.08 6,702.25 3_MWD+IFR2+MS+Sag (5) 12,673.81 88.39 12.05 3,888.05 7,833.18 -2,552.703,827.65 6,017,266.50 548,903.35 4.84 6,765.15 3_MWD+IFR2+MS+Sag (5) 12,738.53 89.63 12.78 3,889.17 7,896.38 -2,538.793,828.77 6,017,329.78 548,916.83 2.22 6,829.68 3_MWD+IFR2+MS+Sag (5) 12,802.09 87.03 13.99 3,891.02 7,958.18 -2,524.083,830.62 6,017,391.67 548,931.10 4.51 6,893.09 3_MWD+IFR2+MS+Sag (5) 12,865.91 85.55 16.10 3,895.15 8,019.68 -2,507.553,834.75 6,017,453.28 548,947.21 4.03 6,956.74 3_MWD+IFR2+MS+Sag (5) 12,929.20 86.66 19.90 3,899.45 8,079.72 -2,488.043,839.05 6,017,513.45 548,966.30 6.24 7,019.86 3_MWD+IFR2+MS+Sag (5) 12,992.91 87.84 21.66 3,902.51 8,139.21 -2,465.463,842.11 6,017,573.09 548,988.46 3.32 7,083.34 3_MWD+IFR2+MS+Sag (5) 13,056.61 88.39 22.83 3,904.60 8,198.14 -2,441.363,844.20 6,017,632.17 549,012.15 2.03 7,146.71 3_MWD+IFR2+MS+Sag (5) 13,120.49 87.46 23.92 3,906.92 8,256.73 -2,416.043,846.52 6,017,690.94 549,037.07 2.24 7,210.12 3_MWD+IFR2+MS+Sag (5) 13,183.81 87.96 25.54 3,909.45 8,314.20 -2,389.573,849.05 6,017,748.58 549,063.14 2.68 7,272.77 3_MWD+IFR2+MS+Sag (5) 13,247.55 88.39 25.91 3,911.48 8,371.59 -2,361.923,851.08 6,017,806.16 549,090.39 0.89 7,335.70 3_MWD+IFR2+MS+Sag (5) 13,310.36 88.08 25.94 3,913.41 8,428.05 -2,334.473,853.01 6,017,862.80 549,117.45 0.50 7,397.68 3_MWD+IFR2+MS+Sag (5) 8/7/2020 5:36:02PM COMPASS 5000.15 Build 91E Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 13,374.19 88.08 25.97 3,915.55 8,485.41 -2,306.553,855.15 6,017,920.35 549,144.97 0.05 7,460.65 3_MWD+IFR2+MS+Sag (5) 13,437.69 88.02 24.94 3,917.71 8,542.71 -2,279.273,857.31 6,017,977.83 549,171.85 1.62 7,523.38 3_MWD+IFR2+MS+Sag (5) 13,500.87 88.39 24.29 3,919.69 8,600.12 -2,252.973,859.29 6,018,035.42 549,197.75 1.18 7,585.94 3_MWD+IFR2+MS+Sag (5) 13,564.83 89.01 23.23 3,921.14 8,658.65 -2,227.213,860.74 6,018,094.11 549,223.10 1.92 7,649.40 3_MWD+IFR2+MS+Sag (5) 13,628.58 89.13 21.66 3,922.17 8,717.56 -2,202.873,861.77 6,018,153.18 549,247.03 2.47 7,712.82 3_MWD+IFR2+MS+Sag (5) 13,691.95 90.24 20.60 3,922.52 8,776.67 -2,180.033,862.12 6,018,212.44 549,269.46 2.42 7,776.01 3_MWD+IFR2+MS+Sag (5) 13,755.28 90.49 20.04 3,922.12 8,836.05 -2,158.043,861.72 6,018,271.97 549,291.04 0.97 7,839.21 3_MWD+IFR2+MS+Sag (5) 13,819.53 89.07 18.79 3,922.37 8,896.65 -2,136.683,861.97 6,018,332.70 549,311.98 2.94 7,903.39 3_MWD+IFR2+MS+Sag (5) 13,883.16 89.44 18.72 3,923.19 8,956.89 -2,116.233,862.79 6,018,393.08 549,332.01 0.59 7,966.98 3_MWD+IFR2+MS+Sag (5) 13,946.83 89.87 19.13 3,923.58 9,017.12 -2,095.583,863.18 6,018,453.45 549,352.24 0.93 8,030.60 3_MWD+IFR2+MS+Sag (5) 14,010.62 89.07 20.09 3,924.17 9,077.21 -2,074.173,863.77 6,018,513.67 549,373.23 1.96 8,094.30 3_MWD+IFR2+MS+Sag (5) 14,074.37 89.01 20.53 3,925.23 9,136.98 -2,052.043,864.83 6,018,573.60 549,394.94 0.70 8,157.92 3_MWD+IFR2+MS+Sag (5) 14,137.53 88.95 20.46 3,926.36 9,196.14 -2,029.933,865.96 6,018,632.90 549,416.64 0.15 8,220.94 3_MWD+IFR2+MS+Sag (5) 14,200.98 88.70 21.33 3,927.66 9,255.40 -2,007.313,867.26 6,018,692.31 549,438.86 1.43 8,284.21 3_MWD+IFR2+MS+Sag (5) 14,264.35 87.90 22.18 3,929.54 9,314.23 -1,983.833,869.14 6,018,751.29 549,461.92 1.84 8,347.31 3_MWD+IFR2+MS+Sag (5) 14,328.07 87.09 22.15 3,932.33 9,373.18 -1,959.813,871.93 6,018,810.41 549,485.53 1.27 8,410.68 3_MWD+IFR2+MS+Sag (5) 14,392.05 87.47 21.89 3,935.36 9,432.43 -1,935.853,874.96 6,018,869.81 549,509.08 0.72 8,474.32 3_MWD+IFR2+MS+Sag (5) 14,455.57 88.52 20.19 3,937.58 9,491.68 -1,913.063,877.18 6,018,929.21 549,531.46 3.14 8,537.62 3_MWD+IFR2+MS+Sag (5) 14,518.84 88.33 17.88 3,939.32 9,551.46 -1,892.443,878.92 6,018,989.13 549,551.67 3.66 8,600.81 3_MWD+IFR2+MS+Sag (5) 14,582.68 89.94 15.26 3,940.29 9,612.63 -1,874.243,879.89 6,019,050.42 549,569.44 4.82 8,664.64 3_MWD+IFR2+MS+Sag (5) 14,646.33 89.26 14.62 3,940.73 9,674.13 -1,857.833,880.33 6,019,112.02 549,585.43 1.47 8,728.25 3_MWD+IFR2+MS+Sag (5) 14,709.82 88.76 15.22 3,941.83 9,735.47 -1,841.483,881.43 6,019,173.47 549,601.34 1.23 8,791.70 3_MWD+IFR2+MS+Sag (5) 14,773.37 89.81 16.53 3,942.62 9,796.59 -1,824.103,882.22 6,019,234.70 549,618.30 2.64 8,855.23 3_MWD+IFR2+MS+Sag (5) 14,836.96 90.37 17.51 3,942.52 9,857.39 -1,805.493,882.12 6,019,295.62 549,636.49 1.77 8,918.82 3_MWD+IFR2+MS+Sag (5) 14,900.57 89.63 17.90 3,942.52 9,917.99 -1,786.143,882.12 6,019,356.35 549,655.42 1.32 8,982.42 3_MWD+IFR2+MS+Sag (5) 14,964.15 89.50 18.82 3,943.00 9,978.33 -1,766.123,882.60 6,019,416.82 549,675.02 1.46 9,045.98 3_MWD+IFR2+MS+Sag (5) 15,027.97 89.63 19.25 3,943.49 10,038.66 -1,745.303,883.09 6,019,477.28 549,695.42 0.70 9,109.74 3_MWD+IFR2+MS+Sag (5) 15,091.77 90.00 20.64 3,943.69 10,098.63 -1,723.543,883.29 6,019,537.40 549,716.76 2.25 9,173.44 3_MWD+IFR2+MS+Sag (5) 15,154.92 88.58 21.32 3,944.48 10,157.59 -1,700.933,884.08 6,019,596.50 549,738.96 2.49 9,236.41 3_MWD+IFR2+MS+Sag (5) 15,218.65 88.46 22.57 3,946.12 10,216.68 -1,677.133,885.72 6,019,655.75 549,762.36 1.97 9,299.86 3_MWD+IFR2+MS+Sag (5) 15,281.57 89.32 22.44 3,947.34 10,274.80 -1,653.053,886.94 6,019,714.03 549,786.03 1.38 9,362.45 3_MWD+IFR2+MS+Sag (5) 15,345.82 88.33 22.06 3,948.66 10,334.25 -1,628.723,888.26 6,019,773.64 549,809.94 1.65 9,426.39 3_MWD+IFR2+MS+Sag (5) 15,409.36 88.21 23.93 3,950.58 10,392.71 -1,603.913,890.18 6,019,832.27 549,834.35 2.95 9,489.52 3_MWD+IFR2+MS+Sag (5) 15,431.78 88.15 23.90 3,951.29 10,413.20 -1,594.833,890.89 6,019,852.81 549,843.29 0.30 9,511.75 3_MWD+IFR2+MS+Sag (5) 15,500.00 88.15 23.90 3,953.49 10,475.53 -1,567.213,893.09 6,019,915.33 549,870.48 0.00 9,579.41 PROJECTED to TD Approved By:Checked By:Date: 8/7/2020 5:36:02PM COMPASS 5000.15 Build 91E Page 8 Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.08.07 14:44:22 -08'00'Benjamin Hand Digitally signed by Benjamin Hand Date: 2020.08.10 10:35:06 -08'00' 07 August, 2020 Milne Point M Pt I Pad MPU I-38PB1 Slot I-32 500292368470 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38PB1 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38PB1 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: MPU I-38 usft usft 0.00 0.00 6,009,451.89 551,509.84 33.80Wellhead Elevation:33.80 usft0.50 70° 26' 11.661 N 149° 34' 48.112 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-38PB1 Model NameMagnetics IFR 7/23/2020 15.89 80.86 57,377.70000000 Phase:Version: Audit Notes: Design MPU I-38PB1 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:26.60 16.750.000.0026.60 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 8/3/2020 Survey Date 3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing100.00 867.00 MPU I-38PB1 E-Line Gyro (MPU I-38PB1 07/15/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa929.14 6,401.54 MPU I-38PB1 MWD+IFR2+MS+Sag (1) (07/22/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa6,443.67 9,368.44 MPU I-38PB1 MWD+IFR2+MS+Sag (2) (07/30/2020 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 26.60 0.00 0.00 26.60 0.00 0.00-33.80 6,009,451.89 551,509.84 0.00 0.00 UNDEFINED 100.00 0.46 324.50 100.00 0.24 -0.1739.60 6,009,452.13 551,509.67 0.63 0.18 3_Gyro-GC_Csg (1) 200.00 0.61 271.25 200.00 0.58 -0.94139.60 6,009,452.46 551,508.90 0.50 0.28 3_Gyro-GC_Csg (1) 300.00 0.60 311.84 299.99 0.94 -1.86239.59 6,009,452.82 551,507.98 0.42 0.36 3_Gyro-GC_Csg (1) 363.00 0.51 255.31 362.99 1.09 -2.38302.59 6,009,452.96 551,507.46 0.84 0.36 3_Gyro-GC_Csg (1) 423.00 0.58 255.12 422.99 0.94 -2.93362.59 6,009,452.81 551,506.91 0.12 0.06 3_Gyro-GC_Csg (1) 490.00 1.23 243.65 489.98 0.54 -3.90429.58 6,009,452.40 551,505.94 1.00 -0.61 3_Gyro-GC_Csg (1) 553.00 2.48 219.93 552.94 -0.81 -5.38492.54 6,009,451.04 551,504.47 2.29 -2.33 3_Gyro-GC_Csg (1) 612.00 4.40 213.55 611.83 -3.67 -7.45551.43 6,009,448.16 551,502.42 3.31 -5.67 3_Gyro-GC_Csg (1) 678.00 5.54 208.10 677.59 -8.60 -10.35617.19 6,009,443.22 551,499.55 1.87 -11.21 3_Gyro-GC_Csg (1) 739.00 6.30 214.03 738.26 -13.97 -13.61677.86 6,009,437.83 551,496.33 1.60 -17.30 3_Gyro-GC_Csg (1) 803.00 7.26 219.14 801.81 -20.01 -18.13741.41 6,009,431.75 551,491.85 1.77 -24.39 3_Gyro-GC_Csg (1) 8/7/2020 5:37:15PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38PB1 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38PB1 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 867.00 9.90 228.94 865.09 -26.76 -24.83804.69 6,009,424.96 551,485.20 4.70 -32.79 3_Gyro-GC_Csg (1) 929.14 13.42 232.67 925.94 -34.65 -34.60865.54 6,009,417.01 551,475.49 5.79 -43.15 3_MWD+IFR2+MS+Sag (2) 991.71 16.55 237.76 986.38 -43.81 -47.91925.98 6,009,407.76 551,462.24 5.42 -55.76 3_MWD+IFR2+MS+Sag (2) 1,056.19 18.80 240.43 1,047.81 -53.84 -64.72987.41 6,009,397.61 551,445.50 3.71 -70.20 3_MWD+IFR2+MS+Sag (2) 1,118.13 21.25 242.57 1,106.00 -63.93 -83.361,045.60 6,009,387.39 551,426.93 4.13 -85.25 3_MWD+IFR2+MS+Sag (2) 1,183.52 23.28 245.70 1,166.52 -74.71 -105.661,106.12 6,009,376.46 551,404.71 3.59 -101.99 3_MWD+IFR2+MS+Sag (2) 1,246.43 26.83 247.13 1,223.50 -85.35 -130.081,163.10 6,009,365.65 551,380.36 5.72 -119.22 3_MWD+IFR2+MS+Sag (2) 1,310.16 30.28 247.73 1,279.47 -97.03 -158.211,219.07 6,009,353.78 551,352.32 5.43 -138.51 3_MWD+IFR2+MS+Sag (2) 1,374.12 33.97 248.78 1,333.63 -109.61 -189.801,273.23 6,009,340.98 551,320.82 5.83 -159.66 3_MWD+IFR2+MS+Sag (2) 1,437.83 34.30 250.03 1,386.36 -122.19 -223.271,325.96 6,009,328.17 551,287.44 1.22 -181.35 3_MWD+IFR2+MS+Sag (2) 1,501.43 36.45 252.43 1,438.22 -134.01 -258.131,377.82 6,009,316.11 551,252.67 4.02 -202.72 3_MWD+IFR2+MS+Sag (2) 1,564.84 37.86 255.24 1,488.76 -144.66 -294.901,428.36 6,009,305.21 551,215.97 3.48 -223.51 3_MWD+IFR2+MS+Sag (2) 1,628.40 40.81 256.80 1,537.92 -154.37 -334.001,477.52 6,009,295.23 551,176.95 4.89 -244.08 3_MWD+IFR2+MS+Sag (2) 1,692.28 44.14 259.53 1,585.03 -163.18 -376.211,524.63 6,009,286.13 551,134.80 5.96 -264.68 3_MWD+IFR2+MS+Sag (2) 1,755.56 45.88 260.10 1,629.77 -171.09 -420.251,569.37 6,009,277.91 551,090.82 2.82 -284.95 3_MWD+IFR2+MS+Sag (2) 1,819.28 48.75 260.45 1,672.96 -179.00 -466.421,612.56 6,009,269.69 551,044.72 4.52 -305.83 3_MWD+IFR2+MS+Sag (2) 1,883.18 49.91 260.60 1,714.61 -186.98 -514.221,654.21 6,009,261.38 550,996.97 1.82 -327.24 3_MWD+IFR2+MS+Sag (2) 1,947.05 49.32 260.28 1,755.99 -195.06 -562.201,695.59 6,009,252.97 550,949.06 1.00 -348.81 3_MWD+IFR2+MS+Sag (2) 2,010.60 50.52 259.92 1,796.90 -203.42 -610.101,736.50 6,009,244.28 550,901.22 1.94 -370.62 3_MWD+IFR2+MS+Sag (2) 2,073.80 50.55 260.42 1,837.08 -211.75 -658.171,776.68 6,009,235.62 550,853.21 0.61 -392.45 3_MWD+IFR2+MS+Sag (2) 2,137.07 52.13 260.46 1,876.60 -219.96 -706.891,816.20 6,009,227.08 550,804.56 2.50 -414.35 3_MWD+IFR2+MS+Sag (2) 2,200.76 51.50 260.58 1,915.97 -228.20 -756.271,855.57 6,009,218.49 550,755.24 1.00 -436.47 3_MWD+IFR2+MS+Sag (2) 2,264.43 51.15 261.61 1,955.76 -235.90 -805.371,895.36 6,009,210.46 550,706.19 1.38 -457.99 3_MWD+IFR2+MS+Sag (2) 2,327.73 51.66 260.84 1,995.25 -243.44 -854.271,934.85 6,009,202.57 550,657.36 1.25 -479.31 3_MWD+IFR2+MS+Sag (2) 2,390.99 51.00 261.26 2,034.77 -251.13 -903.061,974.37 6,009,194.55 550,608.63 1.16 -500.73 3_MWD+IFR2+MS+Sag (2) 2,455.08 51.02 260.90 2,075.10 -258.85 -952.272,014.70 6,009,186.49 550,559.48 0.44 -522.31 3_MWD+IFR2+MS+Sag (2) 2,518.47 51.01 261.19 2,114.98 -266.52 -1,000.942,054.58 6,009,178.49 550,510.86 0.36 -543.68 3_MWD+IFR2+MS+Sag (2) 2,581.89 51.74 259.59 2,154.57 -274.80 -1,049.792,094.17 6,009,169.88 550,462.08 2.28 -565.68 3_MWD+IFR2+MS+Sag (2) 2,645.30 51.19 259.67 2,194.07 -283.73 -1,098.582,133.67 6,009,160.61 550,413.35 0.87 -588.29 3_MWD+IFR2+MS+Sag (2) 2,709.39 51.36 259.97 2,234.17 -292.56 -1,147.792,173.77 6,009,151.44 550,364.21 0.45 -610.94 3_MWD+IFR2+MS+Sag (2) 2,773.28 51.81 261.65 2,273.87 -300.56 -1,197.212,213.47 6,009,143.10 550,314.85 2.18 -632.83 3_MWD+IFR2+MS+Sag (2) 2,837.15 52.06 264.22 2,313.25 -306.74 -1,247.102,252.85 6,009,136.58 550,265.01 3.19 -653.13 3_MWD+IFR2+MS+Sag (2) 2,900.04 52.09 266.52 2,351.91 -310.74 -1,296.542,291.51 6,009,132.23 550,215.60 2.89 -671.22 3_MWD+IFR2+MS+Sag (2) 2,963.55 53.13 268.59 2,390.47 -312.89 -1,346.952,330.07 6,009,129.74 550,165.21 3.06 -687.80 3_MWD+IFR2+MS+Sag (2) 3,025.52 53.42 272.60 2,427.54 -312.37 -1,396.602,367.14 6,009,129.91 550,115.56 5.21 -701.61 3_MWD+IFR2+MS+Sag (2) 3,090.97 54.85 276.41 2,465.89 -308.19 -1,449.462,405.49 6,009,133.73 550,062.68 5.20 -712.84 3_MWD+IFR2+MS+Sag (2) 3,153.91 56.12 279.65 2,501.56 -300.93 -1,500.802,441.16 6,009,140.63 550,011.30 4.70 -720.69 3_MWD+IFR2+MS+Sag (2) 3,217.54 57.89 283.47 2,536.22 -290.23 -1,553.062,475.82 6,009,150.97 549,958.97 5.75 -725.50 3_MWD+IFR2+MS+Sag (2) 3,281.59 56.60 286.24 2,570.88 -276.43 -1,605.122,510.48 6,009,164.41 549,906.82 4.16 -727.29 3_MWD+IFR2+MS+Sag (2) 3,345.17 57.60 285.92 2,605.41 -261.64 -1,656.412,545.01 6,009,178.84 549,855.43 1.63 -727.91 3_MWD+IFR2+MS+Sag (2) 8/7/2020 5:37:15PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38PB1 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38PB1 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,408.61 57.41 286.62 2,639.50 -246.65 -1,707.782,579.10 6,009,193.47 549,803.97 0.98 -728.36 3_MWD+IFR2+MS+Sag (2) 3,470.73 57.85 284.84 2,672.76 -232.43 -1,758.282,612.36 6,009,207.34 549,753.38 2.52 -729.30 3_MWD+IFR2+MS+Sag (2) 3,536.32 58.34 283.12 2,707.42 -218.98 -1,812.312,647.02 6,009,220.42 549,699.26 2.35 -731.99 3_MWD+IFR2+MS+Sag (2) 3,599.19 58.58 282.82 2,740.31 -206.96 -1,864.522,679.91 6,009,232.08 549,646.97 0.56 -735.52 3_MWD+IFR2+MS+Sag (2) 3,663.46 58.61 283.58 2,773.80 -194.43 -1,917.932,713.40 6,009,244.24 549,593.49 1.01 -738.92 3_MWD+IFR2+MS+Sag (2) 3,726.84 58.27 283.84 2,806.97 -181.63 -1,970.392,746.57 6,009,256.67 549,540.94 0.64 -741.78 3_MWD+IFR2+MS+Sag (2) 3,790.23 58.61 284.50 2,840.15 -168.41 -2,022.762,779.75 6,009,269.53 549,488.48 1.04 -744.22 3_MWD+IFR2+MS+Sag (2) 3,853.96 57.55 283.32 2,873.85 -155.40 -2,075.272,813.45 6,009,282.18 549,435.90 2.29 -746.89 3_MWD+IFR2+MS+Sag (2) 3,917.15 55.49 283.30 2,908.70 -143.27 -2,126.562,848.30 6,009,293.95 549,384.53 3.26 -750.05 3_MWD+IFR2+MS+Sag (2) 3,981.09 55.95 283.73 2,944.72 -130.92 -2,177.932,884.32 6,009,305.94 549,333.08 0.91 -753.04 3_MWD+IFR2+MS+Sag (2) 4,043.45 57.60 284.35 2,978.88 -118.26 -2,228.532,918.48 6,009,318.25 549,282.40 2.77 -755.50 3_MWD+IFR2+MS+Sag (2) 4,108.49 57.93 286.74 3,013.58 -103.52 -2,281.532,953.18 6,009,332.63 549,229.30 3.15 -756.65 3_MWD+IFR2+MS+Sag (2) 4,171.99 57.19 289.13 3,047.65 -87.02 -2,332.512,987.25 6,009,348.77 549,178.21 3.38 -755.55 3_MWD+IFR2+MS+Sag (2) 4,235.18 56.89 293.24 3,082.04 -67.87 -2,381.933,021.64 6,009,367.58 549,128.67 5.48 -751.45 3_MWD+IFR2+MS+Sag (2) 4,298.95 57.57 296.26 3,116.56 -45.42 -2,430.613,056.16 6,009,389.69 549,079.83 4.12 -743.99 3_MWD+IFR2+MS+Sag (2) 4,362.78 58.68 299.69 3,150.27 -19.99 -2,478.473,089.87 6,009,414.78 549,031.81 4.88 -733.43 3_MWD+IFR2+MS+Sag (2) 4,426.42 60.16 302.55 3,182.65 8.33 -2,525.363,122.25 6,009,442.78 548,984.73 4.51 -719.82 3_MWD+IFR2+MS+Sag (2) 4,489.88 61.01 305.71 3,213.82 39.34 -2,571.103,153.42 6,009,473.47 548,938.78 4.54 -703.31 3_MWD+IFR2+MS+Sag (2) 4,553.54 61.28 308.58 3,244.55 73.01 -2,615.543,184.15 6,009,506.82 548,894.11 3.97 -683.88 3_MWD+IFR2+MS+Sag (2) 4,617.44 61.78 311.01 3,275.02 108.96 -2,658.693,214.62 6,009,542.47 548,850.72 3.43 -661.89 3_MWD+IFR2+MS+Sag (2) 4,680.61 62.58 314.17 3,304.50 146.76 -2,699.813,244.10 6,009,579.99 548,809.34 4.60 -637.54 3_MWD+IFR2+MS+Sag (2) 4,744.09 64.27 315.22 3,332.90 186.69 -2,740.163,272.50 6,009,619.64 548,768.72 3.05 -610.93 3_MWD+IFR2+MS+Sag (2) 4,807.74 65.30 317.43 3,360.02 228.34 -2,779.923,299.62 6,009,661.01 548,728.68 3.53 -582.51 3_MWD+IFR2+MS+Sag (2) 4,871.34 65.84 320.78 3,386.33 272.11 -2,817.823,325.93 6,009,704.50 548,690.48 4.87 -551.52 3_MWD+IFR2+MS+Sag (2) 4,934.72 67.74 324.07 3,411.31 318.27 -2,853.333,350.91 6,009,750.42 548,654.66 5.63 -517.55 3_MWD+IFR2+MS+Sag (2) 4,998.78 67.82 326.25 3,435.54 366.94 -2,887.203,375.14 6,009,798.85 548,620.45 3.15 -480.71 3_MWD+IFR2+MS+Sag (2) 5,062.44 68.99 328.46 3,458.97 416.78 -2,919.133,398.57 6,009,848.46 548,588.19 3.71 -442.19 3_MWD+IFR2+MS+Sag (2) 5,126.00 68.64 329.71 3,481.94 467.62 -2,949.573,421.54 6,009,899.09 548,557.39 1.91 -402.27 3_MWD+IFR2+MS+Sag (2) 5,188.76 68.28 329.99 3,504.98 518.10 -2,978.893,444.58 6,009,949.36 548,527.73 0.71 -362.39 3_MWD+IFR2+MS+Sag (2) 5,253.17 66.96 330.94 3,529.51 569.92 -3,008.253,469.11 6,010,000.96 548,498.01 2.46 -321.23 3_MWD+IFR2+MS+Sag (2) 5,317.20 65.63 332.62 3,555.25 621.57 -3,035.983,494.85 6,010,052.42 548,469.93 3.18 -279.76 3_MWD+IFR2+MS+Sag (2) 5,379.75 68.84 333.87 3,579.45 673.07 -3,061.933,519.05 6,010,103.73 548,443.63 5.45 -237.93 3_MWD+IFR2+MS+Sag (2) 5,443.44 69.82 334.93 3,601.93 726.81 -3,087.683,541.53 6,010,157.29 548,417.51 2.19 -193.89 3_MWD+IFR2+MS+Sag (2) 5,506.96 70.34 334.82 3,623.58 780.88 -3,113.043,563.18 6,010,211.17 548,391.79 0.83 -149.42 3_MWD+IFR2+MS+Sag (2) 5,570.47 72.13 335.65 3,644.01 835.48 -3,138.223,583.61 6,010,265.60 548,366.23 3.08 -104.39 3_MWD+IFR2+MS+Sag (2) 5,634.24 71.80 337.50 3,663.75 891.11 -3,162.333,603.35 6,010,321.06 548,341.74 2.81 -58.07 3_MWD+IFR2+MS+Sag (2) 5,697.75 73.40 338.63 3,682.74 947.33 -3,184.963,622.34 6,010,377.11 548,318.72 3.04 -10.76 3_MWD+IFR2+MS+Sag (2) 5,761.34 75.99 340.99 3,699.53 1,004.89 -3,206.123,639.13 6,010,434.52 548,297.17 5.42 38.26 3_MWD+IFR2+MS+Sag (2) 5,825.34 76.81 342.95 3,714.58 1,064.04 -3,225.373,654.18 6,010,493.52 548,277.51 3.24 89.35 3_MWD+IFR2+MS+Sag (2) 5,888.66 75.92 346.07 3,729.51 1,123.33 -3,241.813,669.11 6,010,552.69 548,260.67 4.99 141.39 3_MWD+IFR2+MS+Sag (2) 8/7/2020 5:37:15PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38PB1 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38PB1 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 5,952.32 76.80 348.57 3,744.52 1,183.68 -3,255.383,684.12 6,010,612.94 548,246.68 4.06 195.27 3_MWD+IFR2+MS+Sag (2) 6,015.59 79.33 351.09 3,757.61 1,244.60 -3,266.303,697.21 6,010,673.78 548,235.33 5.58 250.45 3_MWD+IFR2+MS+Sag (2) 6,079.29 81.92 353.17 3,767.98 1,306.85 -3,274.903,707.58 6,010,735.96 548,226.31 5.19 307.58 3_MWD+IFR2+MS+Sag (2) 6,142.80 83.70 355.71 3,775.93 1,369.55 -3,281.013,715.53 6,010,798.62 548,219.77 4.86 365.87 3_MWD+IFR2+MS+Sag (2) 6,206.64 83.64 358.33 3,782.97 1,432.91 -3,284.303,722.57 6,010,861.95 548,216.04 4.08 425.59 3_MWD+IFR2+MS+Sag (2) 6,270.00 83.62 1.69 3,790.01 1,495.87 -3,284.293,729.61 6,010,924.90 548,215.61 5.27 485.88 3_MWD+IFR2+MS+Sag (2) 6,333.99 84.25 1.96 3,796.77 1,559.47 -3,282.273,736.37 6,010,988.51 548,217.20 1.07 547.37 3_MWD+IFR2+MS+Sag (2) 6,401.54 88.22 2.00 3,801.20 1,626.82 -3,279.943,740.80 6,011,055.86 548,219.06 5.88 612.53 3_MWD+IFR2+MS+Sag (2) 6,443.67 89.44 2.28 3,802.06 1,668.91 -3,278.373,741.66 6,011,097.96 548,220.34 2.97 653.29 3_MWD+IFR2+MS+Sag (3) 6,507.64 88.95 0.89 3,802.96 1,732.85 -3,276.603,742.56 6,011,161.90 548,221.67 2.30 715.03 3_MWD+IFR2+MS+Sag (3) 6,571.50 89.87 0.29 3,803.62 1,796.70 -3,275.943,743.22 6,011,225.75 548,221.89 1.72 776.36 3_MWD+IFR2+MS+Sag (3) 6,635.02 90.00 0.23 3,803.69 1,860.22 -3,275.653,743.29 6,011,289.27 548,221.74 0.23 837.27 3_MWD+IFR2+MS+Sag (3) 6,699.01 90.43 0.22 3,803.45 1,924.21 -3,275.403,743.05 6,011,353.25 548,221.55 0.67 898.61 3_MWD+IFR2+MS+Sag (3) 6,762.25 90.12 0.20 3,803.15 1,987.45 -3,275.173,742.75 6,011,416.48 548,221.34 0.49 959.23 3_MWD+IFR2+MS+Sag (3) 6,826.08 91.48 0.45 3,802.26 2,051.27 -3,274.813,741.86 6,011,480.30 548,221.26 2.17 1,020.45 3_MWD+IFR2+MS+Sag (3) 6,887.94 91.48 0.58 3,800.66 2,113.11 -3,274.253,740.26 6,011,542.13 548,221.39 0.21 1,079.82 3_MWD+IFR2+MS+Sag (3) 6,951.61 91.42 0.25 3,799.05 2,176.76 -3,273.793,738.65 6,011,605.77 548,221.41 0.53 1,140.91 3_MWD+IFR2+MS+Sag (3) 7,014.70 91.36 0.57 3,797.52 2,239.83 -3,273.343,737.12 6,011,668.84 548,221.43 0.52 1,201.43 3_MWD+IFR2+MS+Sag (3) 7,080.13 90.62 359.86 3,796.39 2,305.24 -3,273.093,735.99 6,011,734.25 548,221.22 1.57 1,264.14 3_MWD+IFR2+MS+Sag (3) 7,143.77 90.99 359.67 3,795.49 2,368.88 -3,273.353,735.09 6,011,797.88 548,220.52 0.65 1,325.00 3_MWD+IFR2+MS+Sag (3) 7,207.39 90.92 359.86 3,794.43 2,432.49 -3,273.613,734.03 6,011,861.48 548,219.82 0.32 1,385.84 3_MWD+IFR2+MS+Sag (3) 7,270.93 91.54 359.53 3,793.07 2,496.01 -3,273.953,732.67 6,011,924.99 548,219.05 1.11 1,446.57 3_MWD+IFR2+MS+Sag (3) 7,334.84 91.85 359.36 3,791.18 2,559.89 -3,274.573,730.78 6,011,988.86 548,217.99 0.55 1,507.56 3_MWD+IFR2+MS+Sag (3) 7,398.12 91.85 0.05 3,789.13 2,623.14 -3,274.903,728.73 6,012,052.09 548,217.22 1.09 1,568.03 3_MWD+IFR2+MS+Sag (3) 7,461.78 92.03 0.19 3,786.98 2,686.76 -3,274.763,726.58 6,012,115.71 548,216.92 0.36 1,628.99 3_MWD+IFR2+MS+Sag (3) 7,525.44 91.98 0.29 3,784.75 2,750.38 -3,274.503,724.35 6,012,179.32 548,216.74 0.18 1,689.99 3_MWD+IFR2+MS+Sag (3) 7,589.18 90.92 359.90 3,783.14 2,814.10 -3,274.393,722.74 6,012,243.04 548,216.41 1.77 1,751.03 3_MWD+IFR2+MS+Sag (3) 7,652.91 90.18 359.85 3,782.53 2,877.83 -3,274.533,722.13 6,012,306.75 548,215.83 1.16 1,812.02 3_MWD+IFR2+MS+Sag (3) 7,716.01 89.63 0.20 3,782.63 2,940.93 -3,274.503,722.23 6,012,369.85 548,215.42 1.03 1,872.45 3_MWD+IFR2+MS+Sag (3) 7,779.89 87.40 359.88 3,784.29 3,004.78 -3,274.463,723.89 6,012,433.69 548,215.03 3.53 1,933.60 3_MWD+IFR2+MS+Sag (3) 7,843.19 85.42 359.67 3,788.25 3,067.95 -3,274.713,727.85 6,012,496.86 548,214.34 3.15 1,994.02 3_MWD+IFR2+MS+Sag (3) 7,906.72 85.73 359.91 3,793.15 3,131.29 -3,274.943,732.75 6,012,560.19 548,213.67 0.62 2,054.61 3_MWD+IFR2+MS+Sag (3) 7,969.53 85.85 0.36 3,797.76 3,193.93 -3,274.793,737.36 6,012,622.82 548,213.39 0.74 2,114.64 3_MWD+IFR2+MS+Sag (3) 8,033.69 86.35 0.82 3,802.13 3,257.94 -3,274.133,741.73 6,012,686.82 548,213.60 1.06 2,176.12 3_MWD+IFR2+MS+Sag (3) 8,097.65 86.79 1.79 3,805.95 3,321.77 -3,272.683,745.55 6,012,750.65 548,214.62 1.66 2,237.66 3_MWD+IFR2+MS+Sag (3) 8,161.47 85.79 4.11 3,810.08 3,385.36 -3,269.403,749.68 6,012,814.27 548,217.45 3.95 2,299.50 3_MWD+IFR2+MS+Sag (3) 8,224.90 84.99 6.05 3,815.18 3,448.34 -3,263.803,754.78 6,012,877.27 548,222.62 3.30 2,361.41 3_MWD+IFR2+MS+Sag (3) 8,288.70 84.99 6.76 3,820.75 3,511.50 -3,256.713,760.35 6,012,940.47 548,229.27 1.11 2,423.94 3_MWD+IFR2+MS+Sag (3) 8,352.08 85.36 6.90 3,826.08 3,574.20 -3,249.203,765.68 6,013,003.22 548,236.35 0.62 2,486.15 3_MWD+IFR2+MS+Sag (3) 8,415.62 87.22 8.06 3,830.20 3,637.07 -3,240.953,769.80 6,013,066.13 548,244.17 3.45 2,548.72 3_MWD+IFR2+MS+Sag (3) 8/7/2020 5:37:15PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38PB1 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38PB1 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,478.57 89.63 8.18 3,831.93 3,699.36 -3,232.063,771.53 6,013,128.48 548,252.62 3.83 2,610.93 3_MWD+IFR2+MS+Sag (3) 8,541.67 88.89 7.38 3,832.74 3,761.87 -3,223.523,772.34 6,013,191.04 548,260.73 1.73 2,673.25 3_MWD+IFR2+MS+Sag (3) 8,605.11 90.31 6.79 3,833.18 3,824.82 -3,215.703,772.78 6,013,254.04 548,268.12 2.42 2,735.79 3_MWD+IFR2+MS+Sag (3) 8,668.91 90.37 6.25 3,832.81 3,888.21 -3,208.453,772.41 6,013,317.47 548,274.92 0.85 2,798.57 3_MWD+IFR2+MS+Sag (3) 8,732.37 90.37 5.97 3,832.40 3,951.31 -3,201.703,772.00 6,013,380.61 548,281.24 0.44 2,860.94 3_MWD+IFR2+MS+Sag (3) 8,795.90 90.68 6.60 3,831.81 4,014.45 -3,194.743,771.41 6,013,443.79 548,287.76 1.11 2,923.41 3_MWD+IFR2+MS+Sag (3) 8,859.78 90.24 5.86 3,831.30 4,077.95 -3,187.813,770.90 6,013,507.33 548,294.25 1.35 2,986.22 3_MWD+IFR2+MS+Sag (3) 8,923.76 90.80 6.25 3,830.72 4,141.57 -3,181.063,770.32 6,013,570.99 548,300.56 1.07 3,049.08 3_MWD+IFR2+MS+Sag (3) 8,987.18 93.21 6.48 3,828.50 4,204.56 -3,174.043,768.10 6,013,634.02 548,307.15 3.82 3,111.42 3_MWD+IFR2+MS+Sag (3) 9,050.77 95.07 7.13 3,823.91 4,267.53 -3,166.523,763.51 6,013,697.04 548,314.23 3.10 3,173.89 3_MWD+IFR2+MS+Sag (3) 9,113.91 93.76 7.15 3,819.05 4,330.00 -3,158.703,758.65 6,013,759.55 548,321.62 2.07 3,235.95 3_MWD+IFR2+MS+Sag (3) 9,177.21 93.46 6.95 3,815.06 4,392.69 -3,150.943,754.66 6,013,822.29 548,328.94 0.57 3,298.23 3_MWD+IFR2+MS+Sag (3) 9,240.69 91.29 6.97 3,812.43 4,455.65 -3,143.263,752.03 6,013,885.29 548,336.19 3.42 3,360.72 3_MWD+IFR2+MS+Sag (3) 9,304.35 90.43 6.20 3,811.48 4,518.88 -3,135.963,751.08 6,013,948.56 548,343.05 1.81 3,423.38 3_MWD+IFR2+MS+Sag (3) 9,368.44 88.64 5.75 3,812.00 4,582.61 -3,129.293,751.60 6,014,012.34 548,349.28 2.88 3,486.33 3_MWD+IFR2+MS+Sag (3) 9,459.00 88.64 5.75 3,814.15 4,672.69 -3,120.223,753.75 6,014,102.47 548,357.73 0.00 3,575.20 PROJECTED to TD Approved By:Checked By:Date: 8/7/2020 5:37:15PM COMPASS 5000.15 Build 91E Page 6 Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.08.07 14:41:21 -08'00' Benjamin Hand Digitally signed by Benjamin Hand Date: 2020.08.10 10:41:09 -08'00' 10 August, 2020 Milne Point M Pt I Pad MPU I-38PB2 500292368471 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38PB2 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38PB2 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: MPU I-38 usft usft 0.00 0.00 6,009,451.89 551,509.84 33.80Wellhead Elevation:33.80 usft0.50 70° 26' 11.661 N 149° 34' 48.112 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-38PB2 Model NameMagnetics IFR 7/23/2020 15.89 80.86 57,377.70000000 Phase:Version: Audit Notes: Design MPU I-38PB2 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:7,398.12 16.750.000.0026.60 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 8/3/2020 Survey Date 3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing100.00 867.00 MPU I-38PB1 E-Line Gyro (MPU I-38PB1 07/15/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa929.14 6,401.54 MPU I-38PB1 MWD+IFR2+MS+Sag (1) (07/22/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa6,443.67 7,398.12 MPU I-38PB1 MWD+IFR2+MS+Sag (2) (07/30/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa7,406.00 11,506.03 MPU I-38PB2 MWD+IFR2+MS+Sag (3) (07/31/2020 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 26.60 0.00 0.00 26.60 0.00 0.00-33.80 6,009,451.89 551,509.84 0.00 0.00 UNDEFINED 100.00 0.46 324.50 100.00 0.24 -0.1739.60 6,009,452.13 551,509.67 0.63 0.18 3_Gyro-GC_Csg (1) 200.00 0.61 271.25 200.00 0.58 -0.94139.60 6,009,452.46 551,508.90 0.50 0.28 3_Gyro-GC_Csg (1) 300.00 0.60 311.84 299.99 0.94 -1.86239.59 6,009,452.82 551,507.98 0.42 0.36 3_Gyro-GC_Csg (1) 363.00 0.51 255.31 362.99 1.09 -2.38302.59 6,009,452.96 551,507.46 0.84 0.36 3_Gyro-GC_Csg (1) 423.00 0.58 255.12 422.99 0.94 -2.93362.59 6,009,452.81 551,506.91 0.12 0.06 3_Gyro-GC_Csg (1) 490.00 1.23 243.65 489.98 0.54 -3.90429.58 6,009,452.40 551,505.94 1.00 -0.61 3_Gyro-GC_Csg (1) 553.00 2.48 219.93 552.94 -0.81 -5.38492.54 6,009,451.04 551,504.47 2.29 -2.33 3_Gyro-GC_Csg (1) 612.00 4.40 213.55 611.83 -3.67 -7.45551.43 6,009,448.16 551,502.42 3.31 -5.67 3_Gyro-GC_Csg (1) 678.00 5.54 208.10 677.59 -8.60 -10.35617.19 6,009,443.22 551,499.55 1.87 -11.21 3_Gyro-GC_Csg (1) 739.00 6.30 214.03 738.26 -13.97 -13.61677.86 6,009,437.83 551,496.33 1.60 -17.30 3_Gyro-GC_Csg (1) 8/10/2020 1:49:15PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38PB2 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38PB2 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 803.00 7.26 219.14 801.81 -20.01 -18.13741.41 6,009,431.75 551,491.85 1.77 -24.39 3_Gyro-GC_Csg (1) 867.00 9.90 228.94 865.09 -26.76 -24.83804.69 6,009,424.96 551,485.20 4.70 -32.79 3_Gyro-GC_Csg (1) 929.14 13.42 232.67 925.94 -34.65 -34.60865.54 6,009,417.01 551,475.49 5.79 -43.15 3_MWD+IFR2+MS+Sag (2) 991.71 16.55 237.76 986.38 -43.81 -47.91925.98 6,009,407.76 551,462.24 5.42 -55.76 3_MWD+IFR2+MS+Sag (2) 1,056.19 18.80 240.43 1,047.81 -53.84 -64.72987.41 6,009,397.61 551,445.50 3.71 -70.20 3_MWD+IFR2+MS+Sag (2) 1,118.13 21.25 242.57 1,106.00 -63.93 -83.361,045.60 6,009,387.39 551,426.93 4.13 -85.25 3_MWD+IFR2+MS+Sag (2) 1,183.52 23.28 245.70 1,166.52 -74.71 -105.661,106.12 6,009,376.46 551,404.71 3.59 -101.99 3_MWD+IFR2+MS+Sag (2) 1,246.43 26.83 247.13 1,223.50 -85.35 -130.081,163.10 6,009,365.65 551,380.36 5.72 -119.22 3_MWD+IFR2+MS+Sag (2) 1,310.16 30.28 247.73 1,279.47 -97.03 -158.211,219.07 6,009,353.78 551,352.32 5.43 -138.51 3_MWD+IFR2+MS+Sag (2) 1,374.12 33.97 248.78 1,333.63 -109.61 -189.801,273.23 6,009,340.98 551,320.82 5.83 -159.66 3_MWD+IFR2+MS+Sag (2) 1,437.83 34.30 250.03 1,386.36 -122.19 -223.271,325.96 6,009,328.17 551,287.44 1.22 -181.35 3_MWD+IFR2+MS+Sag (2) 1,501.43 36.45 252.43 1,438.22 -134.01 -258.131,377.82 6,009,316.11 551,252.67 4.02 -202.72 3_MWD+IFR2+MS+Sag (2) 1,564.84 37.86 255.24 1,488.76 -144.66 -294.901,428.36 6,009,305.21 551,215.97 3.48 -223.51 3_MWD+IFR2+MS+Sag (2) 1,628.40 40.81 256.80 1,537.92 -154.37 -334.001,477.52 6,009,295.23 551,176.95 4.89 -244.08 3_MWD+IFR2+MS+Sag (2) 1,692.28 44.14 259.53 1,585.03 -163.18 -376.211,524.63 6,009,286.13 551,134.80 5.96 -264.68 3_MWD+IFR2+MS+Sag (2) 1,755.56 45.88 260.10 1,629.77 -171.09 -420.251,569.37 6,009,277.91 551,090.82 2.82 -284.95 3_MWD+IFR2+MS+Sag (2) 1,819.28 48.75 260.45 1,672.96 -179.00 -466.421,612.56 6,009,269.69 551,044.72 4.52 -305.83 3_MWD+IFR2+MS+Sag (2) 1,883.18 49.91 260.60 1,714.61 -186.98 -514.221,654.21 6,009,261.38 550,996.97 1.82 -327.24 3_MWD+IFR2+MS+Sag (2) 1,947.05 49.32 260.28 1,755.99 -195.06 -562.201,695.59 6,009,252.97 550,949.06 1.00 -348.81 3_MWD+IFR2+MS+Sag (2) 2,010.60 50.52 259.92 1,796.90 -203.42 -610.101,736.50 6,009,244.28 550,901.22 1.94 -370.62 3_MWD+IFR2+MS+Sag (2) 2,073.80 50.55 260.42 1,837.08 -211.75 -658.171,776.68 6,009,235.62 550,853.21 0.61 -392.45 3_MWD+IFR2+MS+Sag (2) 2,137.07 52.13 260.46 1,876.60 -219.96 -706.891,816.20 6,009,227.08 550,804.56 2.50 -414.35 3_MWD+IFR2+MS+Sag (2) 2,200.76 51.50 260.58 1,915.97 -228.20 -756.271,855.57 6,009,218.49 550,755.24 1.00 -436.47 3_MWD+IFR2+MS+Sag (2) 2,264.43 51.15 261.61 1,955.76 -235.90 -805.371,895.36 6,009,210.46 550,706.19 1.38 -457.99 3_MWD+IFR2+MS+Sag (2) 2,327.73 51.66 260.84 1,995.25 -243.44 -854.271,934.85 6,009,202.57 550,657.36 1.25 -479.31 3_MWD+IFR2+MS+Sag (2) 2,390.99 51.00 261.26 2,034.77 -251.13 -903.061,974.37 6,009,194.55 550,608.63 1.16 -500.73 3_MWD+IFR2+MS+Sag (2) 2,455.08 51.02 260.90 2,075.10 -258.85 -952.272,014.70 6,009,186.49 550,559.48 0.44 -522.31 3_MWD+IFR2+MS+Sag (2) 2,518.47 51.01 261.19 2,114.98 -266.52 -1,000.942,054.58 6,009,178.49 550,510.86 0.36 -543.68 3_MWD+IFR2+MS+Sag (2) 2,581.89 51.74 259.59 2,154.57 -274.80 -1,049.792,094.17 6,009,169.88 550,462.08 2.28 -565.68 3_MWD+IFR2+MS+Sag (2) 2,645.30 51.19 259.67 2,194.07 -283.73 -1,098.582,133.67 6,009,160.61 550,413.35 0.87 -588.29 3_MWD+IFR2+MS+Sag (2) 2,709.39 51.36 259.97 2,234.17 -292.56 -1,147.792,173.77 6,009,151.44 550,364.21 0.45 -610.94 3_MWD+IFR2+MS+Sag (2) 2,773.28 51.81 261.65 2,273.87 -300.56 -1,197.212,213.47 6,009,143.10 550,314.85 2.18 -632.83 3_MWD+IFR2+MS+Sag (2) 2,837.15 52.06 264.22 2,313.25 -306.74 -1,247.102,252.85 6,009,136.58 550,265.01 3.19 -653.13 3_MWD+IFR2+MS+Sag (2) 2,900.04 52.09 266.52 2,351.91 -310.74 -1,296.542,291.51 6,009,132.23 550,215.60 2.89 -671.22 3_MWD+IFR2+MS+Sag (2) 2,963.55 53.13 268.59 2,390.47 -312.89 -1,346.952,330.07 6,009,129.74 550,165.21 3.06 -687.80 3_MWD+IFR2+MS+Sag (2) 3,025.52 53.42 272.60 2,427.54 -312.37 -1,396.602,367.14 6,009,129.91 550,115.56 5.21 -701.61 3_MWD+IFR2+MS+Sag (2) 3,090.97 54.85 276.41 2,465.89 -308.19 -1,449.462,405.49 6,009,133.73 550,062.68 5.20 -712.84 3_MWD+IFR2+MS+Sag (2) 3,153.91 56.12 279.65 2,501.56 -300.93 -1,500.802,441.16 6,009,140.63 550,011.30 4.70 -720.69 3_MWD+IFR2+MS+Sag (2) 3,217.54 57.89 283.47 2,536.22 -290.23 -1,553.062,475.82 6,009,150.97 549,958.97 5.75 -725.50 3_MWD+IFR2+MS+Sag (2) 3,281.59 56.60 286.24 2,570.88 -276.43 -1,605.122,510.48 6,009,164.41 549,906.82 4.16 -727.29 3_MWD+IFR2+MS+Sag (2) 8/10/2020 1:49:15PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38PB2 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38PB2 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,345.17 57.60 285.92 2,605.41 -261.64 -1,656.412,545.01 6,009,178.84 549,855.43 1.63 -727.91 3_MWD+IFR2+MS+Sag (2) 3,408.61 57.41 286.62 2,639.50 -246.65 -1,707.782,579.10 6,009,193.47 549,803.97 0.98 -728.36 3_MWD+IFR2+MS+Sag (2) 3,470.73 57.85 284.84 2,672.76 -232.43 -1,758.282,612.36 6,009,207.34 549,753.38 2.52 -729.30 3_MWD+IFR2+MS+Sag (2) 3,536.32 58.34 283.12 2,707.42 -218.98 -1,812.312,647.02 6,009,220.42 549,699.26 2.35 -731.99 3_MWD+IFR2+MS+Sag (2) 3,599.19 58.58 282.82 2,740.31 -206.96 -1,864.522,679.91 6,009,232.08 549,646.97 0.56 -735.52 3_MWD+IFR2+MS+Sag (2) 3,663.46 58.61 283.58 2,773.80 -194.43 -1,917.932,713.40 6,009,244.24 549,593.49 1.01 -738.92 3_MWD+IFR2+MS+Sag (2) 3,726.84 58.27 283.84 2,806.97 -181.63 -1,970.392,746.57 6,009,256.67 549,540.94 0.64 -741.78 3_MWD+IFR2+MS+Sag (2) 3,790.23 58.61 284.50 2,840.15 -168.41 -2,022.762,779.75 6,009,269.53 549,488.48 1.04 -744.22 3_MWD+IFR2+MS+Sag (2) 3,853.96 57.55 283.32 2,873.85 -155.40 -2,075.272,813.45 6,009,282.18 549,435.90 2.29 -746.89 3_MWD+IFR2+MS+Sag (2) 3,917.15 55.49 283.30 2,908.70 -143.27 -2,126.562,848.30 6,009,293.95 549,384.53 3.26 -750.05 3_MWD+IFR2+MS+Sag (2) 3,981.09 55.95 283.73 2,944.72 -130.92 -2,177.932,884.32 6,009,305.94 549,333.08 0.91 -753.04 3_MWD+IFR2+MS+Sag (2) 4,043.45 57.60 284.35 2,978.88 -118.26 -2,228.532,918.48 6,009,318.25 549,282.40 2.77 -755.50 3_MWD+IFR2+MS+Sag (2) 4,108.49 57.93 286.74 3,013.58 -103.52 -2,281.532,953.18 6,009,332.63 549,229.30 3.15 -756.65 3_MWD+IFR2+MS+Sag (2) 4,171.99 57.19 289.13 3,047.65 -87.02 -2,332.512,987.25 6,009,348.77 549,178.21 3.38 -755.55 3_MWD+IFR2+MS+Sag (2) 4,235.18 56.89 293.24 3,082.04 -67.87 -2,381.933,021.64 6,009,367.58 549,128.67 5.48 -751.45 3_MWD+IFR2+MS+Sag (2) 4,298.95 57.57 296.26 3,116.56 -45.42 -2,430.613,056.16 6,009,389.69 549,079.83 4.12 -743.99 3_MWD+IFR2+MS+Sag (2) 4,362.78 58.68 299.69 3,150.27 -19.99 -2,478.473,089.87 6,009,414.78 549,031.81 4.88 -733.43 3_MWD+IFR2+MS+Sag (2) 4,426.42 60.16 302.55 3,182.65 8.33 -2,525.363,122.25 6,009,442.78 548,984.73 4.51 -719.82 3_MWD+IFR2+MS+Sag (2) 4,489.88 61.01 305.71 3,213.82 39.34 -2,571.103,153.42 6,009,473.47 548,938.78 4.54 -703.31 3_MWD+IFR2+MS+Sag (2) 4,553.54 61.28 308.58 3,244.55 73.01 -2,615.543,184.15 6,009,506.82 548,894.11 3.97 -683.88 3_MWD+IFR2+MS+Sag (2) 4,617.44 61.78 311.01 3,275.02 108.96 -2,658.693,214.62 6,009,542.47 548,850.72 3.43 -661.89 3_MWD+IFR2+MS+Sag (2) 4,680.61 62.58 314.17 3,304.50 146.76 -2,699.813,244.10 6,009,579.99 548,809.34 4.60 -637.54 3_MWD+IFR2+MS+Sag (2) 4,744.09 64.27 315.22 3,332.90 186.69 -2,740.163,272.50 6,009,619.64 548,768.72 3.05 -610.93 3_MWD+IFR2+MS+Sag (2) 4,807.74 65.30 317.43 3,360.02 228.34 -2,779.923,299.62 6,009,661.01 548,728.68 3.53 -582.51 3_MWD+IFR2+MS+Sag (2) 4,871.34 65.84 320.78 3,386.33 272.11 -2,817.823,325.93 6,009,704.50 548,690.48 4.87 -551.52 3_MWD+IFR2+MS+Sag (2) 4,934.72 67.74 324.07 3,411.31 318.27 -2,853.333,350.91 6,009,750.42 548,654.66 5.63 -517.55 3_MWD+IFR2+MS+Sag (2) 4,998.78 67.82 326.25 3,435.54 366.94 -2,887.203,375.14 6,009,798.85 548,620.45 3.15 -480.71 3_MWD+IFR2+MS+Sag (2) 5,062.44 68.99 328.46 3,458.97 416.78 -2,919.133,398.57 6,009,848.46 548,588.19 3.71 -442.19 3_MWD+IFR2+MS+Sag (2) 5,126.00 68.64 329.71 3,481.94 467.62 -2,949.573,421.54 6,009,899.09 548,557.39 1.91 -402.27 3_MWD+IFR2+MS+Sag (2) 5,188.76 68.28 329.99 3,504.98 518.10 -2,978.893,444.58 6,009,949.36 548,527.73 0.71 -362.39 3_MWD+IFR2+MS+Sag (2) 5,253.17 66.96 330.94 3,529.51 569.92 -3,008.253,469.11 6,010,000.96 548,498.01 2.46 -321.23 3_MWD+IFR2+MS+Sag (2) 5,317.20 65.63 332.62 3,555.25 621.57 -3,035.983,494.85 6,010,052.42 548,469.93 3.18 -279.76 3_MWD+IFR2+MS+Sag (2) 5,379.75 68.84 333.87 3,579.45 673.07 -3,061.933,519.05 6,010,103.73 548,443.63 5.45 -237.93 3_MWD+IFR2+MS+Sag (2) 5,443.44 69.82 334.93 3,601.93 726.81 -3,087.683,541.53 6,010,157.29 548,417.51 2.19 -193.89 3_MWD+IFR2+MS+Sag (2) 5,506.96 70.34 334.82 3,623.58 780.88 -3,113.043,563.18 6,010,211.17 548,391.79 0.83 -149.42 3_MWD+IFR2+MS+Sag (2) 5,570.47 72.13 335.65 3,644.01 835.48 -3,138.223,583.61 6,010,265.60 548,366.23 3.08 -104.39 3_MWD+IFR2+MS+Sag (2) 5,634.24 71.80 337.50 3,663.75 891.11 -3,162.333,603.35 6,010,321.06 548,341.74 2.81 -58.07 3_MWD+IFR2+MS+Sag (2) 5,697.75 73.40 338.63 3,682.74 947.33 -3,184.963,622.34 6,010,377.11 548,318.72 3.04 -10.76 3_MWD+IFR2+MS+Sag (2) 5,761.34 75.99 340.99 3,699.53 1,004.89 -3,206.123,639.13 6,010,434.52 548,297.17 5.42 38.26 3_MWD+IFR2+MS+Sag (2) 5,825.34 76.81 342.95 3,714.58 1,064.04 -3,225.373,654.18 6,010,493.52 548,277.51 3.24 89.35 3_MWD+IFR2+MS+Sag (2) 8/10/2020 1:49:15PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38PB2 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38PB2 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 5,888.66 75.92 346.07 3,729.51 1,123.33 -3,241.813,669.11 6,010,552.69 548,260.67 4.99 141.39 3_MWD+IFR2+MS+Sag (2) 5,952.32 76.80 348.57 3,744.52 1,183.68 -3,255.383,684.12 6,010,612.94 548,246.68 4.06 195.27 3_MWD+IFR2+MS+Sag (2) 6,015.59 79.33 351.09 3,757.61 1,244.60 -3,266.303,697.21 6,010,673.78 548,235.33 5.58 250.45 3_MWD+IFR2+MS+Sag (2) 6,079.29 81.92 353.17 3,767.98 1,306.85 -3,274.903,707.58 6,010,735.96 548,226.31 5.19 307.58 3_MWD+IFR2+MS+Sag (2) 6,142.80 83.70 355.71 3,775.93 1,369.55 -3,281.013,715.53 6,010,798.62 548,219.77 4.86 365.87 3_MWD+IFR2+MS+Sag (2) 6,206.64 83.64 358.33 3,782.97 1,432.91 -3,284.303,722.57 6,010,861.95 548,216.04 4.08 425.59 3_MWD+IFR2+MS+Sag (2) 6,270.00 83.62 1.69 3,790.01 1,495.87 -3,284.293,729.61 6,010,924.90 548,215.61 5.27 485.88 3_MWD+IFR2+MS+Sag (2) 6,333.99 84.25 1.96 3,796.77 1,559.47 -3,282.273,736.37 6,010,988.51 548,217.20 1.07 547.37 3_MWD+IFR2+MS+Sag (2) 6,401.54 88.22 2.00 3,801.20 1,626.82 -3,279.943,740.80 6,011,055.86 548,219.06 5.88 612.53 3_MWD+IFR2+MS+Sag (2) 6,443.67 89.44 2.28 3,802.06 1,668.91 -3,278.373,741.66 6,011,097.96 548,220.34 2.97 653.29 3_MWD+IFR2+MS+Sag (3) 6,507.64 88.95 0.89 3,802.96 1,732.85 -3,276.603,742.56 6,011,161.90 548,221.67 2.30 715.03 3_MWD+IFR2+MS+Sag (3) 6,571.50 89.87 0.29 3,803.62 1,796.70 -3,275.943,743.22 6,011,225.75 548,221.89 1.72 776.36 3_MWD+IFR2+MS+Sag (3) 6,635.02 90.00 0.23 3,803.69 1,860.22 -3,275.653,743.29 6,011,289.27 548,221.74 0.23 837.27 3_MWD+IFR2+MS+Sag (3) 6,699.01 90.43 0.22 3,803.45 1,924.21 -3,275.403,743.05 6,011,353.25 548,221.55 0.67 898.61 3_MWD+IFR2+MS+Sag (3) 6,762.25 90.12 0.20 3,803.15 1,987.45 -3,275.173,742.75 6,011,416.48 548,221.34 0.49 959.23 3_MWD+IFR2+MS+Sag (3) 6,826.08 91.48 0.45 3,802.26 2,051.27 -3,274.813,741.86 6,011,480.30 548,221.26 2.17 1,020.45 3_MWD+IFR2+MS+Sag (3) 6,887.94 91.48 0.58 3,800.66 2,113.11 -3,274.253,740.26 6,011,542.13 548,221.39 0.21 1,079.82 3_MWD+IFR2+MS+Sag (3) 6,951.61 91.42 0.25 3,799.05 2,176.76 -3,273.793,738.65 6,011,605.77 548,221.41 0.53 1,140.91 3_MWD+IFR2+MS+Sag (3) 7,014.70 91.36 0.57 3,797.52 2,239.83 -3,273.343,737.12 6,011,668.84 548,221.43 0.52 1,201.43 3_MWD+IFR2+MS+Sag (3) 7,080.13 90.62 359.86 3,796.39 2,305.24 -3,273.093,735.99 6,011,734.25 548,221.22 1.57 1,264.14 3_MWD+IFR2+MS+Sag (3) 7,143.77 90.99 359.67 3,795.49 2,368.88 -3,273.353,735.09 6,011,797.88 548,220.52 0.65 1,325.00 3_MWD+IFR2+MS+Sag (3) 7,207.39 90.92 359.86 3,794.43 2,432.49 -3,273.613,734.03 6,011,861.48 548,219.82 0.32 1,385.84 3_MWD+IFR2+MS+Sag (3) 7,270.93 91.54 359.53 3,793.07 2,496.01 -3,273.953,732.67 6,011,924.99 548,219.05 1.11 1,446.57 3_MWD+IFR2+MS+Sag (3) 7,334.84 91.85 359.36 3,791.18 2,559.89 -3,274.573,730.78 6,011,988.86 548,217.99 0.55 1,507.56 3_MWD+IFR2+MS+Sag (3) 7,398.12 91.85 0.05 3,789.13 2,623.14 -3,274.903,728.73 6,012,052.09 548,217.22 1.09 1,568.03 3_MWD+IFR2+MS+Sag (3) 7,406.00 91.87 0.07 3,788.88 2,631.01 -3,274.893,728.48 6,012,059.97 548,217.18 0.36 1,575.57 3_MWD+IFR2+MS+Sag (4) 7,461.19 89.44 0.89 3,788.25 2,686.19 -3,274.433,727.85 6,012,115.14 548,217.26 4.65 1,628.54 3_MWD+IFR2+MS+Sag (4) 7,524.78 86.97 1.47 3,790.24 2,749.73 -3,273.123,729.84 6,012,178.69 548,218.13 3.99 1,689.76 3_MWD+IFR2+MS+Sag (4) 7,588.73 85.18 2.34 3,794.62 2,813.49 -3,271.003,734.22 6,012,242.45 548,219.81 3.11 1,751.43 3_MWD+IFR2+MS+Sag (4) 7,651.96 85.12 2.30 3,799.96 2,876.45 -3,268.453,739.56 6,012,305.42 548,221.92 0.11 1,812.45 3_MWD+IFR2+MS+Sag (4) 7,715.23 84.62 2.19 3,805.62 2,939.41 -3,265.983,745.22 6,012,368.39 548,223.96 0.81 1,873.46 3_MWD+IFR2+MS+Sag (4) 7,779.29 83.88 2.15 3,812.04 3,003.11 -3,263.563,751.64 6,012,432.09 548,225.93 1.16 1,935.14 3_MWD+IFR2+MS+Sag (4) 7,842.97 84.31 2.32 3,818.59 3,066.40 -3,261.093,758.19 6,012,495.40 548,227.96 0.73 1,996.46 3_MWD+IFR2+MS+Sag (4) 7,906.41 84.80 2.88 3,824.61 3,129.49 -3,258.233,764.21 6,012,558.50 548,230.39 1.17 2,057.70 3_MWD+IFR2+MS+Sag (4) 7,969.52 86.48 2.75 3,829.41 3,192.34 -3,255.143,769.01 6,012,621.36 548,233.05 2.67 2,118.77 3_MWD+IFR2+MS+Sag (4) 8,033.18 86.97 2.42 3,833.04 3,255.83 -3,252.273,772.64 6,012,684.86 548,235.47 0.93 2,180.39 3_MWD+IFR2+MS+Sag (4) 8,096.84 89.19 2.88 3,835.18 3,319.38 -3,249.333,774.78 6,012,748.43 548,237.98 3.56 2,242.10 3_MWD+IFR2+MS+Sag (4) 8,160.67 90.43 2.64 3,835.39 3,383.13 -3,246.263,774.99 6,012,812.20 548,240.61 1.98 2,304.03 3_MWD+IFR2+MS+Sag (4) 8,224.42 89.69 3.06 3,835.32 3,446.80 -3,243.093,774.92 6,012,875.88 548,243.34 1.33 2,365.92 3_MWD+IFR2+MS+Sag (4) 8,287.83 89.63 2.64 3,835.70 3,510.14 -3,239.943,775.30 6,012,939.23 548,246.05 0.67 2,427.47 3_MWD+IFR2+MS+Sag (4) 8/10/2020 1:49:15PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38PB2 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38PB2 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,351.55 90.25 3.18 3,835.76 3,573.77 -3,236.703,775.36 6,013,002.88 548,248.85 1.29 2,489.34 3_MWD+IFR2+MS+Sag (4) 8,414.77 90.06 4.82 3,835.59 3,636.84 -3,232.293,775.19 6,013,065.96 548,252.82 2.61 2,551.00 3_MWD+IFR2+MS+Sag (4) 8,478.31 90.49 6.63 3,835.29 3,700.06 -3,225.953,774.89 6,013,129.22 548,258.72 2.93 2,613.36 3_MWD+IFR2+MS+Sag (4) 8,541.45 91.67 5.99 3,834.10 3,762.80 -3,219.013,773.70 6,013,192.00 548,265.23 2.13 2,675.44 3_MWD+IFR2+MS+Sag (4) 8,605.19 90.31 8.46 3,833.00 3,826.02 -3,211.003,772.60 6,013,255.27 548,272.81 4.42 2,738.29 3_MWD+IFR2+MS+Sag (4) 8,668.48 90.49 11.13 3,832.55 3,888.38 -3,200.233,772.15 6,013,317.70 548,283.14 4.23 2,801.10 3_MWD+IFR2+MS+Sag (4) 8,732.04 91.17 12.88 3,831.63 3,950.54 -3,187.023,771.23 6,013,379.94 548,295.93 2.95 2,864.44 3_MWD+IFR2+MS+Sag (4) 8,795.64 92.10 13.67 3,829.82 4,012.41 -3,172.423,769.42 6,013,441.91 548,310.10 1.92 2,927.89 3_MWD+IFR2+MS+Sag (4) 8,859.30 93.21 14.52 3,826.87 4,074.09 -3,156.933,766.47 6,013,503.68 548,325.15 2.20 2,991.42 3_MWD+IFR2+MS+Sag (4) 8,923.43 93.39 14.16 3,823.18 4,136.12 -3,141.073,762.78 6,013,565.82 548,340.58 0.63 3,055.38 3_MWD+IFR2+MS+Sag (4) 8,986.88 92.84 13.13 3,819.73 4,197.68 -3,126.133,759.33 6,013,627.48 548,355.10 1.84 3,118.64 3_MWD+IFR2+MS+Sag (4) 9,050.66 90.67 11.09 3,817.78 4,260.01 -3,112.763,757.38 6,013,689.89 548,368.04 4.67 3,182.18 3_MWD+IFR2+MS+Sag (4) 9,114.11 89.94 9.34 3,817.44 4,322.45 -3,101.513,757.04 6,013,752.40 548,378.86 2.99 3,245.21 3_MWD+IFR2+MS+Sag (4) 9,177.53 88.89 7.15 3,818.09 4,385.21 -3,092.413,757.69 6,013,815.21 548,387.52 3.83 3,307.93 3_MWD+IFR2+MS+Sag (4) 9,240.95 89.87 5.69 3,818.77 4,448.22 -3,085.323,758.37 6,013,878.27 548,394.17 2.77 3,370.31 3_MWD+IFR2+MS+Sag (4) 9,304.41 90.74 5.72 3,818.44 4,511.37 -3,079.013,758.04 6,013,941.45 548,400.04 1.37 3,432.60 3_MWD+IFR2+MS+Sag (4) 9,367.87 91.36 6.08 3,817.27 4,574.48 -3,072.493,756.87 6,014,004.60 548,406.13 1.13 3,494.91 3_MWD+IFR2+MS+Sag (4) 9,431.64 90.87 6.50 3,816.03 4,637.85 -3,065.513,755.63 6,014,068.01 548,412.68 1.01 3,557.61 3_MWD+IFR2+MS+Sag (4) 9,495.27 88.76 6.79 3,816.24 4,701.05 -3,058.143,755.84 6,014,131.25 548,419.60 3.35 3,620.25 3_MWD+IFR2+MS+Sag (4) 9,558.61 88.58 6.76 3,817.71 4,763.93 -3,050.673,757.31 6,014,194.18 548,426.64 0.29 3,682.61 3_MWD+IFR2+MS+Sag (4) 9,622.25 87.65 6.74 3,819.80 4,827.10 -3,043.203,759.40 6,014,257.39 548,433.67 1.46 3,745.25 3_MWD+IFR2+MS+Sag (4) 9,685.95 87.65 6.54 3,822.41 4,890.32 -3,035.843,762.01 6,014,320.65 548,440.60 0.31 3,807.91 3_MWD+IFR2+MS+Sag (4) 9,749.80 87.65 5.68 3,825.03 4,953.75 -3,029.053,764.63 6,014,384.12 548,446.95 1.35 3,870.61 3_MWD+IFR2+MS+Sag (4) 9,813.32 87.90 5.03 3,827.50 5,016.94 -3,023.123,767.10 6,014,447.35 548,452.43 1.10 3,932.83 3_MWD+IFR2+MS+Sag (4) 9,876.73 87.47 4.22 3,830.06 5,080.10 -3,018.013,769.66 6,014,510.53 548,457.11 1.45 3,994.77 3_MWD+IFR2+MS+Sag (4) 9,940.26 86.23 5.18 3,833.55 5,143.31 -3,012.823,773.15 6,014,573.78 548,461.87 2.47 4,056.81 3_MWD+IFR2+MS+Sag (4) 10,003.98 86.23 5.84 3,837.74 5,206.60 -3,006.713,777.34 6,014,637.10 548,467.53 1.03 4,119.17 3_MWD+IFR2+MS+Sag (4) 10,067.76 86.04 5.86 3,842.04 5,269.91 -3,000.233,781.64 6,014,700.44 548,473.58 0.30 4,181.66 3_MWD+IFR2+MS+Sag (4) 10,131.49 87.53 6.08 3,845.61 5,333.19 -2,993.613,785.21 6,014,763.76 548,479.76 2.36 4,244.16 3_MWD+IFR2+MS+Sag (4) 10,195.30 89.07 6.14 3,847.51 5,396.61 -2,986.823,787.11 6,014,827.22 548,486.11 2.42 4,306.85 3_MWD+IFR2+MS+Sag (4) 10,258.86 88.76 7.22 3,848.71 5,459.72 -2,979.433,788.31 6,014,890.38 548,493.07 1.77 4,369.41 3_MWD+IFR2+MS+Sag (4) 10,322.34 88.95 8.17 3,849.98 5,522.62 -2,970.933,789.58 6,014,953.32 548,501.13 1.53 4,432.09 3_MWD+IFR2+MS+Sag (4) 10,385.75 88.08 9.19 3,851.62 5,585.28 -2,961.363,791.22 6,015,016.04 548,510.26 2.11 4,494.85 3_MWD+IFR2+MS+Sag (4) 10,449.69 87.09 9.46 3,854.31 5,648.32 -2,951.013,793.91 6,015,079.14 548,520.18 1.60 4,558.20 3_MWD+IFR2+MS+Sag (4) 10,513.21 87.09 10.54 3,857.54 5,710.79 -2,940.003,797.14 6,015,141.69 548,530.76 1.70 4,621.19 3_MWD+IFR2+MS+Sag (4) 10,576.84 87.09 11.07 3,860.77 5,773.21 -2,928.083,800.37 6,015,204.18 548,542.24 0.83 4,684.40 3_MWD+IFR2+MS+Sag (4) 10,640.23 87.59 10.89 3,863.71 5,835.37 -2,916.023,803.31 6,015,266.42 548,553.87 0.84 4,747.40 3_MWD+IFR2+MS+Sag (4) 10,703.91 87.47 10.27 3,866.46 5,897.91 -2,904.343,806.06 6,015,329.03 548,565.12 0.99 4,810.65 3_MWD+IFR2+MS+Sag (4) 10,767.71 87.65 10.20 3,869.17 5,960.64 -2,893.023,808.77 6,015,391.83 548,576.01 0.30 4,873.98 3_MWD+IFR2+MS+Sag (4) 10,831.30 89.87 11.01 3,870.55 6,023.13 -2,881.323,810.15 6,015,454.39 548,587.28 3.72 4,937.19 3_MWD+IFR2+MS+Sag (4) 8/10/2020 1:49:15PM COMPASS 5000.15 Build 91E Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-38 MPU I-38PB2 Survey Calculation Method:Minimum Curvature MPU I-38 Actual RKB @ 60.40usft Design:MPU I-38PB2 Database:NORTH US + CANADA MD Reference:MPU I-38 Actual RKB @ 60.40usft North Reference: Well MPU I-38 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 10,894.90 88.51 9.77 3,871.45 6,085.67 -2,869.853,811.05 6,015,517.01 548,598.31 2.89 5,000.39 3_MWD+IFR2+MS+Sag (4) 10,958.81 89.63 10.16 3,872.48 6,148.61 -2,858.793,812.08 6,015,580.01 548,608.93 1.86 5,063.84 3_MWD+IFR2+MS+Sag (4) 11,022.37 89.62 9.95 3,872.90 6,211.19 -2,847.693,812.50 6,015,642.67 548,619.60 0.33 5,126.97 3_MWD+IFR2+MS+Sag (4) 11,085.63 91.79 9.93 3,872.12 6,273.49 -2,836.773,811.72 6,015,705.03 548,630.08 3.43 5,189.77 3_MWD+IFR2+MS+Sag (4) 11,149.33 91.54 10.91 3,870.27 6,336.12 -2,825.263,809.87 6,015,767.73 548,641.16 1.59 5,253.05 3_MWD+IFR2+MS+Sag (4) 11,212.64 92.09 11.29 3,868.27 6,398.21 -2,813.083,807.87 6,015,829.90 548,652.92 1.06 5,316.02 3_MWD+IFR2+MS+Sag (4) 11,276.22 92.53 10.95 3,865.70 6,460.55 -2,800.823,805.30 6,015,892.31 548,664.74 0.87 5,379.25 3_MWD+IFR2+MS+Sag (4) 11,339.99 92.41 10.49 3,862.96 6,523.14 -2,788.973,802.56 6,015,954.99 548,676.15 0.74 5,442.60 3_MWD+IFR2+MS+Sag (4) 11,403.48 93.33 9.56 3,859.78 6,585.59 -2,777.943,799.38 6,016,017.49 548,686.76 2.06 5,505.58 3_MWD+IFR2+MS+Sag (4) 11,467.13 95.38 8.75 3,854.94 6,648.24 -2,767.843,794.54 6,016,080.21 548,696.42 3.46 5,568.48 3_MWD+IFR2+MS+Sag (4) 11,506.03 95.69 8.90 3,851.19 6,686.50 -2,761.903,790.79 6,016,118.51 548,702.10 0.88 5,606.83 3_MWD+IFR2+MS+Sag (4) 11,575.00 95.69 8.90 3,844.35 6,754.30 -2,751.283,783.95 6,016,186.38 548,712.25 0.00 5,674.82 PROJECTED to TD Approved By:Checked By:Date: 8/10/2020 1:49:15PM COMPASS 5000.15 Build 91E Page 7 Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.08.10 10:51:32 -08'00'Benjamin Hand Digitally signed by Benjamin Hand Date: 2020.08.10 10:58:47 -08'00' STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Supry j-PjP— eq' j6 pT 7V DIVERTER Test Report for: MILNE PT UNIT I-38 Comm Contractor/Rig No.: Hilcorp Innovation PTD#: 2200570 - DATE: 7/21/2020 ' Inspector Adam Earl Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: S. Barber / C. Montague Rig Rep: A. Leslie / E. Evans Inspector Well Class: DEV Inspection No: divAGE200723124903 Related Insp No: MISC. INSPECTIONS: GAS DETECTORS: Visual Alarm Methane: P P Hydrogen Sulfide: P 'P Gas Detectors Mise: 0 NA TEST DATA MUD SYSTEM: P/F Location Gen.: P Housekeeping: P Warning Sign P - 24 hr Notice: P Well Sign: P Drlg. Rig. P Misc: NA GAS DETECTORS: Visual Alarm Methane: P P Hydrogen Sulfide: P 'P Gas Detectors Mise: 0 NA TEST DATA MUD SYSTEM: P/F Visual Alarm Trip Tank: P _ P Mud Pits: P _ " P " Flow Monitor: P - P Mud System Misc: 0 NA ACCUMULATOR SYSTEM: P/F Time/Pressure P/F Systems Pressure: 3050 _ P Pressure After Closure: 1950 P 200 psi Recharge Time: 13 _ _ P _ Full Recharge Time: 56 P Nitrogen Bottles (Number of): 6 P_ " Avg. Pressure: 2300 P Accumulator Misc:-O NA DIVERTER SYSTEM: Size P/F Designed to Avoid Freeze-up?_ P_ Remote Operated Diverter?__ P " No Threaded Connections? P " Vent line Below Diverter? P Diverter Size: 13.62 P Hole Size: 12.25 P Vent Line(s) Size: 16 P Vent Line(s) Length: 177 P Closest Ignition Source: 80 P Outlet from Rig Substructure: 165 P " Vent Line(s) Anchored: P Turns Targeted / Long Radius: NA Divert Valve(s) Full Opening: P - Valve(s) Auto & Simultaneous: P" Annular Closed Time: 9 P Knife Valve Open Time: 6 P Diverter Misc: 0 NA Number of Failures: 0 V, Test Time: 1 Remarks: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU I-38 Hilcorp Alaska, LLC Permit to Drill Number: 220-057 Surface Location: 2337' FSL, 3861' FEL, Sec 33, T13N, R10E, UM, AK Bottomhole Location: 1399' FNL, 225' FWL, Sec 21, T13N, R10E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of July, 2020. Sincerely, 13 1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:6. Proposed Depth: 12. Field/Pool(s): MD: 17,208' TVD: 4,013' 4a. Location of Well (Governmental Section):7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date: Total Depth:9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 60.3' 15. Distance to Nearest Well Open Surface: x- 551509 y- 6009451 Zone-4 33.8' to Same Pool: 20' to MPU J-25 16. Deviated wells:Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD Cond 20" 129.5# X-56 Weld 107' Surface Surface 107' 107' 47# L-80 TXP 2,000' Surface Surface 2,000' 1,786' 40# L-80 TXP 4,420' 2,000' 1,786' 6,420' 4,010' 8-1/2" 4-1/2" 20# L-80 Hyd 625 10,938' 6,270' 3,773' 17,208' 4,013' Tieback 7-5/8" 29.7# L-80 Hyd 521 6,270' Surface Surface 6,270' 3,773' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned?Yes No 20. Attachments:Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Contact Email: Contact Phone: Date: Permit to Drill API Number: Permit Approval Number:50- Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Sr Pet Eng Sr Pet Geo Sr Res Eng 12-1/4"9-5/8" GL / BF Elevation above MSL (ft): 7/7/2020 See cover letter for other requirements. Perforation Depth MD (ft): 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Perforation Depth TVD (ft): Commission Use Only Authorized Signature: Surface Production Liner Casing Intermediate Cementless Screens Liner Tieback Assembly Effect. Depth MD (ft): Stg 1 L - 1189 ft3 / T - 458 ft3 Effect. Depth TVD (ft): Conductor/Structural Length 1669 Total Depth MD (ft):Total Depth TVD (ft): Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) Driven STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Stg 2 L - 1937 ft3 / T - 314 ft3 1328 1365' FNL, 1849' FEL, Sec 32, T13N, R10E, UM, AK 1399' FNL, 225' FWL, Sec 21, T13N, R10E, UM, AK LONS 88-004 8939 MPU I-38 Milne Point Field Schrader Bluff Oil Pool 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp Alaska, LLC 2337' FSL, 3861' FEL, Sec 33, T13N, R10E, UM, AK ADL025906, ADL025517, ADL025515, ADL315848 022224484 3915' to nearest unit boundary 7/17/2020 Authorized Name: Monty Myers Authorized Title: Drilling Manager Joe Engel jengel@hilcorp.com 777-8395 18. Casing Program:Top - Setting Depth - BottomSpecifications es N ype of W L l R L 1b S Class: os N es No s N o D s s s D 84 o : well is p G S S 20 S S S es No s No S G E S es No s Form 10-401 Revised 3/2020 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Samantha Carlisle at 8:56 am, Jul 07, 2020 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.07.06 19:10:15 -08'00' Monty M Myers X DSR-7/7/2020MGR09JUL2020 X 220-057 029-23684-00-00 X X BOPE test to 3000 psi. Annular test to 2500 psi. X X DLB 07/07/2020 X R09JJJJJJUUUL2U020 7/13/2020 Milne Point Unit (MPU) I-38 Drilling Program Version 1 7/7/2020 Table of Contents 1.0 Well Summary ........................................................................................................................... 2 2.0 Management of Change Information ........................................................................................ 3 3.0 Tubular Program:...................................................................................................................... 4 4.0 Drill Pipe Information: .............................................................................................................. 4 5.0 Internal Reporting Requirements ............................................................................................. 5 6.0 Planned Wellbore Schematic ..................................................................................................... 6 7.0 Drilling / Completion Summary ................................................................................................ 7 8.0 Mandatory Regulatory Compliance / Notifications .................................................................. 8 9.0 R/U and Preparatory Work ..................................................................................................... 10 10.0 N/U 13-5/8” 5M Diverter System ............................................................................................. 11 11.0 Drill 12-1/4” Hole Section ........................................................................................................ 13 12.0 Run 9-5/8” Surface Casing ...................................................................................................... 16 13.0 Cement 9-5/8” Surface Casing ................................................................................................. 22 14.0 ND Diverter, NU BOPE, & Test .............................................................................................. 27 15.0 Drill 8-1/2” Hole Section .......................................................................................................... 28 16.0 Run 4-1/2” Screen Liner .......................................................................................................... 33 17.0 Run 7-5/8” Tieback .................................................................................................................. 37 18.0 Run Upper Completion - ESP ................................................................................................. 40 19.0 Innovation Rig Diverter Schematic ......................................................................................... 42 20.0 Innovation Rig BOP Schematic ............................................................................................... 43 21.0 Wellhead Schematic ................................................................................................................. 44 22.0 Days Vs Depth .......................................................................................................................... 45 23.0 Formation Tops & Information............................................................................................... 46 24.0 Anticipated Drilling Hazards .................................................................................................. 47 25.0 Innovation Rig Layout ............................................................................................................. 51 26.0 FIT Procedure .......................................................................................................................... 52 27.0 Innovation Rig Choke Manifold Schematic ............................................................................ 53 28.0 Casing Design ........................................................................................................................... 54 29.0 8-1/2” Hole Section MASP ....................................................................................................... 55 30.0 Spider Plot (NAD 27) (Governmental Sections) ...................................................................... 56 31.0 Surface Plat (As Built) (NAD 27) ............................................................................................. 57 Page 2 Milne Point Unit I-38 SB NB Producer Drilling Procedure 1.0 Well Summary Well MPU I-38 Pad Milne Point “I” Pad Planned Completion Type ESP on 3-1/2 tubing Target Reservoir(s) Schrader Bluff NB Sand Planned Well TD, MD / TVD 17,208’ MD / 4,013’ TVD PBTD, MD / TVD 17,198’ MD / 4,013’ TVD Surface Location (Governmental) 2337' FSL, 3861' FEL, Sec 33, T13N, R10E, UM, AK Surface Location (NAD 27) X= 551509, Y= 6009451 Top of Productive Horizon (Governmental) 1365' FNL, 1849' FEL, Sec 32, T13N, R10E, UM, AK TPH Location (NAD 27) X= 548227 Y= 6011007 BHL (Governmental) 1399' FNL, 225' FWL, Sec 21, T13N, R10E, UM, AK BHL (NAD 27) X= 550200, Y= 6021545 AFE Number 2012234 AFE Drilling Days 21 AFE Completion Days 4 AFE Drilling Amount $3,893,528 AFE Completion Amount $2,604,097 AFE Facility Amount $391,000 Maximum Anticipated Pressure (Surface) 1328 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1669 psig Work String 5” 19.5# S-135 NC 50 Innovation KB Elevation above MSL: 26.5 ft + 32.2 ft = 58.7 ft GL Elevation above MSL: 32.2 ft BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams Page 3 Milne Point Unit I-38 SB NB Producer Drilling Procedure 2.0 Management of Change Information Page 4 Milne Point Unit I-38 SB NB Producer Drilling Procedure 3.0 Tubular Program: Hole Section OD (in) ID (in) Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) Cond 20” 19.25” - - - X-52 Weld 12-1/4” 9-5/8” 8.835” 8.679” 10.625” 40 L-80 TXP 5,750 3,090 916 9-5/8” 8.681” 8.525” 10.625” 47 L-80 TXP 6,870 4,750 1,086 Tieback 7-5/8” 6.875” 6.75” 8.5” 29.7 L-80 HYD 563 6,890 4,790 683 8-1/2” 4-1/2” Screens 3.920 3.795 4.714 13.5 L-80 Hydril 625 9,020 8,540 279 4.0 Drill Pipe Information: Hole Section OD (in) ID (in) TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn M/U (Min) M/U (Max) Tension (k-lbs) Surface & Production 5” 4.276” 3.25” 6.625” 19.5 S-135 DS50 36,100 43,100 560klb 5” 4.276” 3.25” 6.625” 19.5 S-135 NC50 30,730 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 5 Milne Point Unit I-38 SB NB Producer Drilling Procedure 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on WellEz. x Report covers operations from 6am to 6am x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area – this will not save the data entered, and will navigate to another data entry. x Ensure time entry adds up to 24 hours total. x Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. x Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates x Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorp, jengel@hilcorp.com and cdinger@hilcorp.com 5.3 Intranet Home Page Morning Update x Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 5.4 EHS Incident Reporting x Health and Safety: Notify EHS field coordinator. x Environmental: Drilling Environmental Coordinator x Notify Drilling Manager & Drilling Engineer on all incidents x Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally x Send final “As-Run” Casing tally to mmyers@hilcorp,com jengel@hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cement report x Send casing and cement report for each string of casing to mmyers@hilcorp.com jengel@hilcorp.com and cdinger@hilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 jengel@hilcorp.com Completion Engineer Ian Toomey 907.777.8434 907.903-3987 itoomey@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com Drilling Env. Coordinator Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 cajones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 6 Milne Point Unit I-38 SB NB Producer Drilling Procedure 6.0 Planned Wellbore Schematic Page 7 Milne Point Unit I-38 SB NB Producer Drilling Procedure 7.0 Drilling / Completion Summary MPU I-38 is a grassroots producer planned to be drilled in the Schrader Bluff Nb sand. I-38 is part of a multi well program targeting the Schrader Bluff sand on I-Pad The directional plan is a catenary well path build, 12.25” hole with 9-5/8” surface casing set into the top of the Schrader Bluff Nb sand. An 8.5” lateral section will then be drilled. A 4-1/2” screen liner will be run in the open hole section and the well produced with an ESP assembly. The Innovation Rig will be used to drill and complete the wellbore Drilling operations are expected to commence approximately July 17, 2020, pending rig schedule. Surface casing will be run to 6,420’ MD / 3,793’ TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point “B” pad G&I facility. General sequence of operations: 1. MIRU Innovation Rig to well site 2. N/U & Test 13-5/8” Diverter and 16” diverter line 3. Drill 12-1/4” hole to TD of surface hole section. Run and c ement 9-5/8” surface casing 4. N/D diverter, N/U wellhead, NU 13-5/8” 5M BOP & Test 5. Drill 8-1/2” lateral to well TD. 6. Run 6-5/8” production liner 7. Run 7” tieback 8. Run Upper Completion 9. N/D BOP, N/U Tree, RDMO Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res 2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering) 7-5/8" 4-1/2", screens. Page 8 Milne Point Unit I-38 SB NB Producer Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the all applicable AOGCC regulations, specific regulations are listed below. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x BOPs shall be tested at (2) week intervals during the drilling and completion of MPU I-38. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. x The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. x If the BOP is used to shut in on the well in a well control situation or control fluid flow from the well bore, AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program and drilling fluid system”. x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements”. o Ensure the diverter vent line is at least 75’ away from potential ignition sources x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: No variances are requested at this time. Page 9 Milne Point Unit I-38 SB NB Producer Drilling Procedure Summary of Innovation BOP Equipment & Test Requirements Hole Section Equipment Test Pressure (psi) 12 1/4” x 13-5/8” 5M CTI Annular BOP w/ 16” diverter line Function Test Only 8-1/2” x 13-5/8” x 5M Control Technology Inc Annular BOP x 13-5/8” x 5M Control Technology Inc Double Gate o Blind ram in btm cavity x Mud cross w/ 3” x 5M side outlets x 13-5/8” x 5M Control Technology Single ram x 3-1/8” x 5M Choke Line x 3-1/8” x 5M Kill line x 3-1/8” x 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/3000 Subsequent Tests: 250/3000 Primary closing unit: Control Technology Inc. (CTI), 6 station, 3000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: x Well control event (BOPs utilized to shut in the well to control influx of formation fluids). x 24 hours notice prior to spud. x 24 hours notice prior to testing BOPs. x 24 hours notice prior to casing running & cement operations. x Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email: jim.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (O): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email: Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Email: melvin.rixse@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 10 Milne Point Unit I-38 SB NB Producer Drilling Procedure 9.0 R/U and Preparatory Work 9.1 I-38 will utilize a newly set 20” conductor on I-Pad. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4” nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and R/U. 9.6 Rig mat footprint of rig. 9.7 MIRU Innovation. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on either hole section. 9.9 Mix spud mud for 12-1/4” surface hole section. Ensure mud temperatures are cool (<80qF). 9.10 Ensure 5” liners in mud pumps. x White Star Quattro 1300 Hp mud pumps are rated at 4097 psi, 381 gpm @ 140 spm @ 96.5% volumetric efficiency. Page 11 Milne Point Unit I-38 SB NB Producer Drilling Procedure 10.0 N/U 13-5/8” 5M Diverter System 10.1 N/U 13-5/8” CTI BOP stack in diverter configuration (Diverter Schematic attached to program). x N/U 20” x 13-5/8” DSA x N/U 13 5/8”, 5M diverter “T”. x NU Knife gate & 16” diverter line. x Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). x Diverter line must be 75 ft from nearest ignition source x Place drip berm at the end of diverter line. x Utilized extensions if needed. 10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked “warning zone” is established on each side and ahead of the vent line tip. “Warning Zone” must include: x A prohibition on vehicle parking x A prohibition on ignition sources or running equipment x A prohibition on staged equipment or materials x Restriction of traffic to essential foot or vehicle traffic only. 24 hour notice to AOGCC to witness. Page 12 Milne Point Unit I-38 SB NB Producer Drilling Procedure 10.4 Rig & Diverter Orientation: x May change on location Page 13 Milne Point Unit I-38 SB NB Producer Drilling Procedure 11.0 Drill 12-1/4” Hole Section 11.1 P/U 12-1/4” directional drilling assembly: x Ensure BHA components have been inspected previously. x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Be sure to run a UBHO sub for wireline gyro x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Drill string will be 5” 19.5# S-135. x Run a solid float in the surface hole section. 11.2 Begin drilling out from 20” conductor at reduced flow rates to avoid broaching the conductor. x Consider using a trash bit to clean out conductor to mitigate potential damage from debris in conductor. 11.3 Drill 12-1/4” hole section to section TD, in the Schrader NB sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. x Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. x Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6 deg / 100. x Hold a safety meeting with rig crews to discuss: x Conductor broaching ops and mitigation procedures. x Well control procedures and rig evacuation x Flow rates, hole cleaning, mud cooling, etc. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Keep mud as cool as possible to keep from washing out permafrost. x Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. x Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen x Slow in/out of slips and while tripping to keep swab and surge pressures low x Ensure shakers are functioning properly. Check for holes in screens on connections. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. x Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 minimum at TD (pending MW increase due to hydrates). x Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. x Be prepared for gas hydrates. In MPU they have been encountered typically around 2100- 2400’ TVD (just below permafrost). Be prepared for hydrates: Page 14 Milne Point Unit I-38 SB NB Producer Drilling Procedure x Gas hydrates can be identified by the gas detector and a decrease in MW or ECD x Monitor returns for hydrates, checking pressurized & non-pressurized scales x Do not stop to circulate out gas hydrates – this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 fph MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. x Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well. MW will not control gas hydrates, but will affect how gas breaks out at surface. x Surface Hole AC: x There are no wells with a clearance factor of <1.0 11.4 12-1/4” hole mud program summary: x Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ ppg. Depth Interval MW (ppg) Surface – Base Permafrost 8.9+ Base Permafrost - TD 9.2+ (For Hydrates if need based on offset wells) MW can be cut o nce ~500’ below hydrate zone x PVT System: PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. x Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. x Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. x Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 – 9.0 range with caustic soda. Daily additions of ALDACIDE G / X- CIDE 207 MUST be made to control bacterial action. x Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). Note: EMW needed is 8.46 ppg. DLB Page 15 Milne Point Unit I-38 SB NB Producer Drilling Procedure System Type: 8.8 – 9.2 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Section Density Viscosity Plastic Viscosity Yield Point API FL pH Temp Surface 8.8 – 9.8 75-175 20 - 40 25-45 <10 8.5 – 9.0 70 F System Formulation: Gel + FW spud mud Product Concentration Fresh Water soda Ash AQUAGEL caustic soda BARAZAN D+ BAROID 41 PAC-L /DEXTRID LT ALDACIDE G 0.905 bbl 0.5 ppb 15 - 20 ppb 0.1 ppb (8.5 – 9.0 pH) as needed as required for 8.8 – 9.2 ppg if required for <10 FL 0.1 ppb 11.5 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity. 11.6 RIH t/ bottom, proceed to BROOH t/ HWDP x Pump at full drill rate (400-600 gpm), and maximize rotation. x Pull slowly, 5 – 10 ft / minute, adjust as dictated by hole conditions x Monitor well for any signs of packing off or losses. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. x If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.7 TOOH and LD BHA 11.8 No open hole logging program planned. Note: EMW needed is 8.46 ppg. DLB Page 16 Milne Point Unit I-38 SB NB Producer Drilling Procedure 12.0 Run 9-5/8” Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 9-5/8” casing running equipment (CRT & Tongs) x Ensure 9-5/8” TXP x DS50 XO on rig floor and M/U to FOSV. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x R/U of CRT if hole conditions require. x R/U a fill up tool to fill casing while running if the CRT is not used. x Ensure all casing has been drifted to 8.75” on the location prior to running. x Top 2000’ of casing 47# drift 8.525” x Be sure to count the total # of joints on the location before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking 120’ shoe track assembly consisting of: 9-5/8” Float Shoe 1 joint – 9-5/8” TXP, 2 Centralizers 10’ from each end w/ stop rings 1 joint – 9-5/8” TXP, 1 Centralizer mid joint w/ stop ring 9-5/8” Float Collar w/ Stage Cementer Bypass Baffle ‘Top Hat’ 1 joint – 9-5/8” TXP, 1 Centralizer mid joint with stop ring 9-5/8” HES Baffle Adaptor x Ensure bypass baffle is correctly installed on top of float collar. x Ensure proper operation of float equipment while picking up. x Ensure to record S/N’s of all float equipment and stage tool components. This end up. Bypass Baffle Page 17 Milne Point Unit I-38 SB NB Producer Drilling Procedure 12.5 Float equipment and Stage tool equipment drawings: Page 18 Milne Point Unit I-38 SB NB Producer Drilling Procedure 12.6 Continue running 9-5/8” surface casing x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: x 1 centralizer every joint t/ ~ 1000’ MD from shoe x 1 centralizer every 2 joints to ~2,000’ above shoe (Top of Lowest Ugnu) x Verify depth of lowest Ugnu water sand for isolation with Geologist x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. x Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cement returns to surface. 12.7 Install the Halliburton Type H ES-II Stage tool so that it is positioned at least 100’ TVD below the permafrost (~ 2,500’ MD). (Halliburton ESIPC with packer element may be used). x Install centralizers over couplings on 5 joints below and 5 joints above stage tool. x Do not place tongs on ES cementer, this can cause damaged to the tool. x Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. x ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at ~ 2080 psi, and the tool to open at ~ 3000 psi. Reference ESIPC Procedure. 9-5/8” 40# L-80 TXP Make Up Torques: Casing OD Minimum Optimum Maximum 9-5/8” 18,860 ft-lbs 20,960 ft-lbs 23,060 ft-lbs 9-5/8” 47# L-80 TXP MUT: Casing OD Minimum Optimum Maximum 9-5/8” 21,440 ft-lbs 2,3820 ft-lbs 26,200 ft-lbs Page 19 Milne Point Unit I-38 SB NB Producer Drilling Procedure Page 20 Milne Point Unit I-38 SB NB Producer Drilling Procedure 12.8 Run 47# 9-5/8” surface casing from ES-II cementer to surface x Ensure drifted to 8.525” x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: o 1 centralizer every 3 joints to base of conductor 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. Page 21 Milne Point Unit I-38 SB NB Producer Drilling Procedure 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. Page 22 Milne Point Unit I-38 SB NB Producer Drilling Procedure 13.0 Cement 9-5/8” Surface Casing 13.1 Hold a pre-job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. x How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. x Which pumps will be utilized for displacement, and how fluid will be fed to displacement pump. x Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. x Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses x Review test reports and ensure pump times are acceptable. x Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) – HEC rep to witness. Mix and pump cement per below calculations for the 1st stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated 1st Stage Total Cement Volume: Section Calculation Vol (bbl) Vol (ft3) 12-1/4" OH x 9-5/8" Casing (5,420' - 2,500') x .0558 bpf x 1.3 = 211.8 1189.3 Total Lead 211.8 1189.3 12-1/4" OH x 9-5/8" Casing (6,420' - 5,420') x .0558 bpf x 1.3 = 72.5 407 9-5/8" Shoe Track 120' x .0758 bpf = 9.1 51.09 Total Tail 81.6 458LeadTail 394 sx 505 sx Page 23 Milne Point Unit I-38 SB NB Producer Drilling Procedure Cement Slurry Design (1st Stage Cement Job): 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets “sticky”, cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. x Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5” liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: (2500’ x .0747bpf ) + (3,800’ x .0758 bpf )= 474.78bbls 186.75 bbls + 288.04 bbls = 80 bbls of tuned spacer to be left behind stage tool, if possible have rig pumps pump spacer to reduce risk of adding any air to the system, cement falling during displacement, or issues switching pumps between rig and cement unit 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. Lead Slurry Tail Slurry Density 12.0 lb/gal 15.8 lb/gal Yield 2.35 ft3/sk 1.16 ft3/sk Mixed Water 13.92 gal/sk 4.98 gal/sk Page 24 Milne Point Unit I-38 SB NB Producer Drilling Procedure 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 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 25 Milne Point Unit I-38 SB NB Producer Drilling Procedure Second Stage Surface Cement Job: 13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. Try to maintain flow rate through stage tool until 2nd stage is ready. Hold pre-job safety meeting. x Past wells have seen pressure increase while circulating through stage tool after reduced rate 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. Estimated 2nd Stage Total Cement Volume: Section Calculation Vol (bbl) Vol (ft3) 20" Conductor x 9-5/8" Casing (110') x .26 bpf x 1 = 28.6 161 12-1/4" OH x 9-5/8" Casing (2000' - 110') x .0558 bpf x 3 = 316.4 1776.3 Total Lead 345 1937 12-1/4" OH x 9-5/8" Casing (2500' - 2000') x .0558 bpf x 2 = 55.8 314 Total Tail 55.8 314LeadTail Cement Slurry Design (2nd stage cement job): Lead Slurry Tail Slurry System Permafrost L Density 10.7 lb/gal 15.8 lb/gal Yield 4.41 ft3/sk 1.17 ft3/sk Mixed Water 22.02 gal/sk 5.08 gal/sk 270 sx 439 sx Page 26 Milne Point Unit I-38 SB NB Producer Drilling Procedure 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement calculation: 2500’ x .0758 bpf = 186.75 bbls mud 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. 13.29 Land closing plug on stage collar and pressure up to 1000 – 1500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips 13.30 Make initial cut on 9-5/8” final joint. L/D cut joint. Make final cut on 9-5/8”. Dress off stump. Install 9-5/8” wellhead. If transition nipple is welded on, allow to cool as per schedule. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface & volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to jengel@hilcorp.com and cdinger@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 27 Milne Point Unit I-38 SB NB Producer Drilling Procedure 14.0 ND Diverter, NU BOPE, & Test 14.1 ND the diverter T, knife gate, diverter line & NU 11” x 13-5/8” 5M casing spool. 14.2 NU 13-5/8” x 5M BOP as follows: x BOP configuration from top down: 13-5/8” x 5M annular / 13-5/8” x 5M double gate / 13- 5/8” x 5M mud cross / 13-5/8” x 5M single gate x Double gate ram should be dressed with 3-1/2” x 5” VBRs in top cavity, blind ram in bottom cavity. x Single ram can be dressed with 3-1/2” x 5” VBRs or 7-5/8” solid body rams x NU bell nipple, install flowline. x Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). x Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve 14.3 RU MPD RCD and related equipment 14.4 Run 5” BOP test plug 14.5 Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. x Test 5” test joints x Confirm test pressures with PTD x Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug x Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 14.6 RD BOP test equipment 14.7 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.8 Mix 8.9 ppg Baradrill-N fluid for production hole. 14.9 Set wearbushing in wellhead. 14.10 If needed, rack back as much 5” DP in derrick as possible to be used while drilling the hole section. 14.11 Ensure 5” liners in mud pumps. 24 hour notice to AOGCC. Page 28 Milne Point Unit I-38 SB NB Producer Drilling Procedure 15.0 Drill 8-1/2” Hole Section 15.1 MU 8.5” Cleanout BHA (Milltooth Bit & 1.22° PDM) 15.2 TIH w/ 8-1/2” cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool. 15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.4 RU and test casing to 2500 psi / 30 min. Ensure to record volume / pressure (every ¼ bbl) and plot on FIT graph. AOGCC reg is 50% of burst = 5750 / 2 = ~2875 psi, but max test pressure on the well is 2,500 psi as per AOGCC. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.5 Drill out shoe track and 20’ of new formation. 15.6 CBU and condition mud for FIT. 15.7 Conduct FIT to 12.0 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT. Document incremental volume pumped (and subsequent pressure) and volume returned. 15.8 POOH and LD cleanout BHA 15.9 PU 8-1/2” directional BHA. x Ensure BHA components have been inspected previously. x Drift and caliper all components before MU. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Ensure MWD is RU and operational. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Drill string will be 5” 19.5# S-135 DS50 & NC50. x Run a ported float in the production hole section. 15.10 8-1/2” hole section mud program summary: x Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. x Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid FIT and casing test digital data to AOGCC for review. Page 29 Milne Point Unit I-38 SB NB 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. x Rheology: Keep viscosifier additions to an absolute minimum (N-VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleaning x Run the centrifuge continuously while drilling the production hole, this will help with solids removal. x Dump and dilute as necessary to keep drilled solids to an absolute minimum. x MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, & Toolpusher office. System Type: 8.9 – 9.5 ppg Baradrill-N drilling fluid Properties: Interval Density PV YP LSYP Total Solids MBT HPHT Hardness Production 8.9-9.5 15-25 - ALAP 15 - 30 4-6 <10% <8 <11.0 <100 System Formulation: Product Concentration Water KCL KOH N-VIS DEXTRID LT BARACARB 5 BARACARB 25 BARACARB 50 BARACOR 700 BARASCAV D X-CIDE 207 0.955 bbl 11 ppb 0.1 ppb 1.0 – 1.5 ppb 5 ppb 4 ppb 4 ppb 2 ppb 1.0 ppb 0.5 ppb 0.015 ppb 15.11 TIH with 8-1/2” directional assembly to bottom Note: EMW needed=8.46 ppg. DLB Page 30 Milne Point Unit I-38 SB NB Producer Drilling Procedure 15.12 Install MPD RCD 15.13 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid 15.14 Begin drilling 8-1/2” hole section, on-bottom staging technique: x Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8K. x Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations x If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to PU off bottom and restart on bottom staging technique. If stick slip continues, consider adding .5% lubes 15.14 Drill 8-1/2” hole section to section TD per Geologist and Drilling Engineer. x Flow Rate: 350-550 GPM, target min. AV’s 200 ft/min, 385 GPM x RPM: 120+ x Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. x Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low x Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection x Monitor Torque and Drag with pumps on every 5 stands x Monitor ECD, pump pressure & hookload trends for hole cleaning indication x Surveys can be taken more frequently if deemed necessary. x Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. x Use ADR to stay in section. x Limit maximum instantaneous ROP to < 250 FPH. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. x Target ROP is as fast as we can clean the hole without having to backream connections x Schrader Bluff NB Concretions: 4-6% Historically x Anticipate similar concentrations in NE x MPD will be utilized to monitor pressure build up on connections. x 8-1/2” Lateral A/C: x J-19 is P&Ad. The only risk is damage to the bit x J-25 SB NB Producer, will be abandoned as part of the I pad redevelopment. We will SI the well and watch for magnetic interference when drilling past. 15.15 Reference: Open hole sidetracking practice: x If a known fault is coming up, put a slight “kick-off ramp” in wellbore ahead of the fault so we have a nice place to low side. x Attempt to lowside in a fast drilling interval where the wellbore is headed up. Page 31 Milne Point Unit I-38 SB NB Producer Drilling Procedure x Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for ~30 min. x Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ GPM) and rotation (120+ RPM). Pump tandem sweeps if needed x Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary x If seepage losses are seen while drilling, consider reducing MW at TD to 9.0 ppg minimum 15.17 Mix and pump 40 bbl 10 ppb SAPP pill. Line up to a closed loop system and circulate three SAP pills with 50 bbl in between. Displace out SAP pills. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. Losses during the cleanup of the wellbore are a good indication that the mud filter cake is being removed, including an increase in the loss rate. 15.18 Displace 1.5 OH + liner volume with viscosified brine. x Proposed brine blend (same as used on M-16, aiming for an 8 on the 6 RPM reading) - KCl: 7.1bbp for 2% NaCl: 60.9ppg for 9.4ppg Lotorq: 1.5% Lube 776: 1.5% Soda Ash: as needed for 9.5pH Busan 1060: 0.42ppb Flo-Vis Plus: 1.25ppb x Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if further discussion needed prior to BROOH. x Ensure fluid going in the hole has passed a production screen test (PST) x Fluid coming out does not have to pass a PST 15.19 BROOH with the drilling assembly to the 9-5/8” casing shoe x Circulate at full drill rate (less if losses are seen, 350 GPM minimum). x Rotate at maximum RPM that can be sustained. x Pulling speed 5 – 10 min/stand (slip to slip time, not including connections), adjust as dictated by hole conditions x If backreaming operations are commenced, continue backreaming to the shoe Page 32 Milne Point Unit I-38 SB NB Producer Drilling Procedure x After backreaming past any OHST, CBU and slack off past OHST point and perform survey/ABI check to ensure liner will stay in lateral and out of any plug backs. 15.20 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while BROOH. 15.21 CBU minimum two times at 9-5/8” shoe and clean casing with high vis sweeps. 15.22 Monitor well for flow/pressure build up with MPD. Increase fluid weight if necessary. x Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to determine if the well is breathing, treat all flow as an influx until proven otherwise. 15.23 Check fluid in surface casing to ensure it has passed a PST in the possum belly x This is the fluid the screens will be ran in / filled with, and needs to be clean of solids that will plug screen size x x3 350ml samples passing through the screen in the same amount of time which will indicate no plugging of the screen). Reference PST Test Procedure x 250 Coupons x Circulate and condition fluid as much as needed to pass the production screen test 15.24 POOH and LD BHA. 15.25 Continue to POOH and stand back BHA if possible. Rabbit DP on TOOH, ensure rabbit diameter is sufficient for future ball drops. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 33 Milne Point Unit I-38 SB NB Producer Drilling Procedure 16.0 Run 4-1/2” Screen Liner 16.1 Confirm VBR’s have been tested on 4-1/2” and 5” test joints to 250/3,000 psi. 16.2 Well control preparedness: In the event of an influx of formation fluids while running the 4- 1/2” production screens, the following well control response procedure will be followed: x PU & MU the 5” safety joint (with 4-1/2” crossover installed on bottom, TIW valve in open position on top, 4-1/2” handling joint above TIW). This joint shall be fully MU and available prior to running the first joint of 4-1/2” screen. x Slack off and position the 5” DP across the BOP, shut in ram or annular on 5” DP. Close TIW valve. x Proceed with well kill operations. 16.3 If an inner string is ran, Well control preparedness: In the event of an influx of formation fluids while running the 2-3/8” inner string inside the 4-1/2” production screens: x PU & MU the 5” safety joint (with 4-1/2” x 2-3/8” triple connect crossover installed on bottom, TIW valve in open position on top, 2-3/8” handling joint above TIW). MU 2-3/8” and then 4-1/2” to triple connect. x This joint shall be fully MU with crossovers prior to running the first joint of wash pipe. x Slack off and position the 5” DP across the BOP, shut in ram or annular on 5” DP. Close TIW valve. Proceed with well kill operations. 16.4 RU 4-1/2” screen running equipment. x Ensure 4-1/2” x NC-50 crossover is on rig floor and MU to FOSV. x Ensure all casing has been drifted on the deck prior to running. x Be sure to count the total # of joints on the deck before running. x Keep hole covered while RU casing tools. x Record OD’s, ID’s, lengths, SN’s of all components w/ vendor & model info. 16.5 Run 4-1/2” screen production liner – Reference screen handling and running procedure. x Use Best O Life 2000 AG thread compound. Dope pin end only with paint brush. Wipe off excess. Thread compound will plug the screens. x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Run packoff and float shoe on bottom. x 4-1/2” Screens should auto –fill, top off with completion brine if needed x Swell packers will not be required on this completion unless the well is drilled out of zone x If needed, install swell packers as per the lower completion tally. x Remove protective packaging on swell packers just prior to picking up x Do not place tongs or slips on the packer element Page 34 Milne Point Unit I-38 SB NB Producer Drilling Procedure 4-1/2”, 13.5 #, L-80, Hydril 625 Torque OD Minimum Optimum Operating Torque 4-1/2” 8,000 ft-lbs 9,600 ft-lbs 12,800 ft-lbs Page 35 Milne Point Unit I-38 SB NB Producer Drilling Procedure 16.6. Ensure to run enough liner to provide for approx 150’ overlap inside 9-5/8” casing. Ensure hanger/packer will not be set in a 9-5/8” connection. x AOGCC regulations require a minimum 100’ overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Do not place liner hanger/packer across 9-5/8” connection. 16.7. Before picking up Baker SLZXP liner hanger / packer assembly, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.8. MU Baker SLZXP liner top packer to 4-1/2” liner. 16.9. Inner string may or not be ran, depending on out of zone excursion and condition of lateral. Have 2-3/8” inner string available if needed. 16.10. Note: PU, SO, ROT and torque of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.11. RIH with liner on ALL 5” HWDP no faster than 30 ft/min – this is to prevent buckling the liner and drill string and weight transfer to get liner to bottom with minimal rotation. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. x Ensure 5” HWDP has been drifted x There is no inner string planned to be run, as opposed to previous wells. The DP should auto fill. Monitor FL and if filling is required due to losses/surging. 16.12. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + SO depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.13. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, & 20 RPM. 16.14. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.15. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.16. Rig up to pump down the work string with the rig pumps. may run Page 36 Milne Point Unit I-38 SB NB Producer Drilling Procedure 16.17. Break circulation. Begin circulating at ~1 BPM and monitor pump pressures. Do not exceed 1,600 psi while circulating. Pusher tool is set at 2,100 psi with 5% shear screws but it should be discussed before exceeding 1,600 psi. Note all losses. Confirm all pressures with Baker. 16.18. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 16.19. Shut down pumps. Drop setting ball (ball seat now located in HRDE setting tool and not at the WIV) down the workstring and pump slowly (1-2 BPM). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 16.20. Continue pressuring up to 2,700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the SZXP liner hanger/packer to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4,500 psi to release the HRDE running tool. 16.21. Bleed DP pressure to 0 psi. Pick up to expose rotating dog sub and set down 50K without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 RPM and set down 50K again. 16.22. PU to neutral weight, close BOP and test annulus to 1,500 psi for 10 minutes charted. 16.23. Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.24. PU pulling running tool free of the packer and displace with at max rate to wash the liner top. Pump sweeps as needed. 16.25. POOH. LD and inspect running tools. If setting of liner hanger/packer proceeded as planned, LD DP on the TOOH. Note: Once running tool is LD, swap to the completion AFE. 16.26. MU 3-1/2” wash tool and RIH with remaining DP out of derrick to liner top. 16.27. Wash through liner top at max rate and circulate hole clean. Pump sweeps around. Displace well to clean filtered brine after no solids are returned. 16.28. POOH and LD remaining 5” HWDP Page 37 Milne Point Unit I-38 SB NB Producer Drilling Procedure 17.0 Run 7-5/8” Tieback 17.1 RU and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie-back space out calculation. Install 7-5/8” solid body casing rams in the upper ram cavity. RU testing equipment. PT to 250/3,000 psi with 7” test joint. RD testing equipment. 17.2 RU 7-5/8” casing handling equipment. x Ensure XO to DP made up to FOSV and ready on rig floor. x Rig up computer torque monitoring service. x String should stay full while running, RU fill up line and check as appropriate. 17.3 PU 7-5/8” tieback seal assembly and set in rotary table. Ensure 7-5/8” seal assembly has (4) 1” holes above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8” x 7- 5/8” annulus. 17.4 MU first joint of 7-5/8” to seal assy. 17.6 Run 7-5/8”, 29.7#, L-80 HYD 563 tieback to position seal assembly two joints above tieback sleeve. Record PU and SO weights. 7-5/8”, 29.7#, L-80, Hyd 563 = Casing OD Torque (Min) Torque (Max) Torque (Yield) 7-5/8” 8,600 ft-lbs 15,100 ft-lbs 45,000 ft-lbs Page 38 Milne Point Unit I-38 SB NB Producer Drilling Procedure 17.7 MU 7-5/8” to DP crossover. 17.8 MU stand of DP to string, and MU top drive. 17.9 Break circulation at 1 BPM and begin lowering string. Page 39 Milne Point Unit I-38 SB NB Producer Drilling Procedure 17.10 Note seal assembly entering tieback sleeve with a pressure increase, stop pumping and bleed off pressure. Leave standpipe bleed off valve open. 17.11 Continue lowering string and land out on no-go. Set down 5 – 10K and mark the pipe as “NO- GO DEPTH”. 17.12 PU string & remove unnecessary 7-5/8” joints. 17.13 Space out with pups as needed to leave the no-go 1 ft above fully no-go position when the casing hanger is landed. Ensure one full joint is below the casing hanger. 17.14 PU and MU the 7-5/8” casing hanger. 17.15 Ensure circulation is possible through 7-5/8” string. 17.16 RU and circulation corrosion inhibited brine in the 9-5/8” x 7-5/8” annulus. 17.17 With seals stabbed into tieback sleeve, spot diesel freeze protection from 2,500’ TVD to surface in 9-5/8” x 7-5/8”annulus by reverse circulating through the holes in the seal assembly. Ensure annular pressure are limited to prevent collapse of the 7-5/8” casing (verify collapse pressure of 7-5/8” tieback seal assembly). 17.18 SO and land hanger. Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning report. 17.19 Back out the landing joint. MU packoff running tool and install packoff on bottom of landing joint. Set casing hanger packoff and RILDS. PT void to 3,000 psi for 10 minutes. 17.20 RD casing running tools. 17.21 PT 9-5/8” x 7-5/8” annulus to 1,000 psi for 30 minutes charted. Page 40 Milne Point Unit I-38 SB NB Producer Drilling Procedure 18.0 Run Upper Completion - ESP 18.1 RU spooler with ESP power cable and heat trace. 18.2 Verify the ESP components as per Centrilift. Verify that the length of the motor lead flat cable will place the splice between the discharge head and the 10’ handling pup collar. A Centrilift rep shall be on the rig floor at all times during the running of the ESP. 18.3 Makeup new ESP assembly with new motor lead extension, seal section and motor. 18.4 Run the 3-1/2” ESP Completion as noted below. The completion includes two 3/8” capillary tube from surface to the centralizer on the motor. The capillary tube will be secured to the tubing with Cannon clamps. Function test the capillary tube every ~2,000’ by pumping ~2 gallons of hydraulic oil through the check valves. Record the pressure at each testing point 18.5 M/U ESP assy and RIH to setting depth. Confirm tally with Operations Engineer i. Ensure appropriate well control crossovers on rig floor and ready. ii. Monitor displacement from wellbore while RIH. x Centrilift ESP Assembly with bottom of assembly @ predetermined depth x 10’ 3-1/2” 9.3#, L-80 Pup Joint x 1 joint 3-1/2” 9.3#, L-80 EUE 8rd tubing x 3-1/2” “XN” nipple (2.813” packing bore / 2.75” No -Go ID) x 3 joints 3-1/2” 9.3#, L-80 EUE 8rd tubing x 10’ 3-1/2” 9.3#, L-80 Pup Joint x GLM 3-1/2” x 1” GLM w/ dummy installed x 10’ 3-1/2” 9.3#, L-80 Pup Joint x 3-1/2” 9.3#, L-80 EUE 8rd tubing x 10’ 3-1/2” 9.3#, L-80 Pup Joint x GLM 3-1/2” x 1” w/ SO @ ~140’ MD x 10’ 3-1/2” 9.3#, L-80 Pup Joint x 3 joints 3-1/2” 9.3#, L-80 EUE 8rd tubing x Tubing Hanger o Check the conductivity of electric cable every 2,000’ and every new splice while running in hole. o Use Cannon clamps on every joint to secure the capillary tube. o The make up torque values for 3-1/2” L-80 9.3# EUE 8rd tubing are: Page 41 Milne Point Unit I-38 SB NB Producer Drilling Procedure Minimum: 2350 ft-lb, Optimum: 3100 ft-lb, and maximum: 3910 ft-lb. o The 3-1/2” L-80 9.3# EUE 8rd tubing performance properties are: Body Yield: 159,000#, Burst: 10,160 psi, Collapse: 10, psi. 18.6 Fill tubing while splicing cable, mid-cable splices and tubing hanger splices. After tubing is full, break circulation by pumping 10 bbls down the tubing to clear any debris. 18.7 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 18.8 MU tubing hanger and landing joint. Splice ESP power cable and terminate control lines. Test cable. Install a brass-shipping cap on the ESP penetrator. 18.9 Land tubing with extreme care to minimize damaging the ESP penetrator, pigtail and alignment pin. 18.10 RILDS and test hanger. LD landing joint. 18.11 Install BPV and N/D BOP. 18.12 N/U tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. Terminate the cap strings. 18.13 Circulate diesel freeze protection down 3-1/2” x 7-5/8” annulus (Volume should equal capacity of tubing to 2500’ + tubing annulus to 2500’). Connect IA to tree and allow diesel freeze protect to “U-tube” into position. Note – this may be done post-rig. 18.14 Pull BPV. Set TWC. Test tree to 250 psi low / 5000 psi high. Pull TWC. Set BPV. 18.15 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 18.16 RDMO Innovation Page 42 Milne Point Unit I-38 SB NB Producer Drilling Procedure 19.0 Innovation Rig Diverter Schematic Page 43 Milne Point Unit I-38 SB NB Producer Drilling Procedure 20.0 Innovation Rig BOP Schematic Page 44 Milne Point Unit I-38 SB NB Producer Drilling Procedure 21.0 Wellhead Schematic Page 45 Milne Point Unit I-38 SB NB Producer Drilling Procedure 22.0 Days Vs Depth Page 46 Milne Point Unit I-38 SB NB Producer Drilling Procedure 23.0 Formation Tops & Information Page 47 Milne Point Unit I-38 SB NB Producer Drilling Procedure 24.0 Anticipated Drilling Hazards 12-1/4” Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Gas hyrates have not been seen on Moose pad. However, be prepared for them. Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates, but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non-pressurized mud scale. The non-pressurized scale will reflect the actual mud cut weight. Add 1.0 – 2.0 ppb Lecithin to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti-Collison: There are no known wells with a clearance factory <1.0. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Well Specific A/C: x There are no wells with a clearance factor of <1.0 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 Page 48 Milne Point Unit I-38 SB NB Producer Drilling Procedure swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 49 Milne Point Unit I-38 SB NB Producer Drilling Procedure 8-1/2” Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of > 300 gpm Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a “ramp” in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed, we’ll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: Reservoir pressures are expected to be normal. Abnormal (offset injection) pressure has been seen on M- Pad. Utilize MPD to mitigate any abnormal pressure seen. Page 50 Milne Point Unit I-38 SB NB Producer Drilling Procedure Anti-Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Reference A/C report in directional plan. Well Specific AC: x J-19 is P&Ad. The only risk is damage to the bit x J-25 SB NB Producer, will be abandoned as part of the I pad redevelopment. We will SI the well and watch for magnetic interference when drilling past. Page 51 Milne Point Unit I-38 SB NB Producer Drilling Procedure 25.0 Innovation Rig Layout Page 52 Milne Point Unit I-38 SB NB Producer Drilling Procedure 26.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental volume pumped and returned during test. Page 53 Milne Point Unit I-38 SB NB Producer Drilling Procedure 27.0 Innovation Rig Choke Manifold Schematic Page 54 Milne Point Unit I-38 SB NB Producer Drilling Procedure 28.0 Casing Design 12-1/4"Mud Density:9.2 ppg 8-1/2"Mud Density:9.2 ppg Mud Density: 1328 psi (see attached MASP determination & calculation) 1328 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 1234 9-5/8"4-1/2" 06,420 03,793 6,420 17,208 3,793 4,013 6,420 10,788 40 12.6 L-80 L-80 DWC H625 256,800 135,929 256,800 135,929 916 279 3.57 2.05 1,874 1,982 3,090 8,540 1.65 4.31 1,328 1,328 5,750 9,020 4.33 6.79 Calculation & Casing Design Factors Calculation/Specification Casing OD Bottom (MD) Bottom (TVD) Top (MD) MASP: Drilling Mode MASP: Hole Size DATE: 7.6.2020 WELL: MPU I-38 Collapse Resistance w/o tension (Psi) Worst case safety factor (Burst) MASP: Production Mode Minimum Yield (psi) Weight (ppf) MASP (psi) Worst Case Safety Factor (Tension) Collapse Pressure at bottom (Psi) Worst Case Safety Factor (Collapse) Length Top (TVD) Tension at Top of Section (lbs) Grade Connection Weight w/o Bouyancy Factor (lbs) Min strength Tension (1000 lbs) DESIGN BY: Joe Engel Hole Size Casing Section Design Criteria: Hole Size 3.57 4.31 4.33 1.65 6.79 2.05 Page 55 Milne Point Unit I-38 SB NB Producer Drilling Procedure 29.0 8-1/2” Hole Section MASP MD TVD Planned Top: 6420 3793 Planned TD: 17208 4013 Anticipated Formations and Pressures: Formation TVD TVDss Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff NB Sand 3,793 3,751 1669 Oil 8.46 0.440 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date MPU L-52 8.8-9.35 Surface 3952 2017 MPU L-51 8.9-9.3 Surface 3930 2017 MPU L-53 9-9.25 Surface 3891 2017 MPU J-27 9-9.3 Surface 3666 2015 MPU J-28 9-9.3 Surface 3617 2015 MPI - 19 9 - 9.3 ppg Surface 4,079 2004 MPI - 18 9 - 10 ppg Surface 3,848 2011 MPI - 17 9 - 9.5 ppg Surface 3,864 2004 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 3793 (ft) x 0.78(psi/ft)= 2959 2959(psi) - [0.1(psi/ft)*3793(ft)]= 2580 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff NB sand) 3793 (ft) x 0.45(psi/ft)= 1707.0 psi 1707(psi) - 0.1(psi/ft)*3793(ft) 1328.0 psi Summary: 1. MASP while drilling 8-1/2" production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.1 psi/ft. 2. Maximum planned mud density for the 8-1/2" hole section is 9.5 ppg. Maximum Anticipated Surface Pressure Calculation 8-1/2" Hole Section MPU I-38 Milne Point Unit Note: 8.46 ppg EMW is pressure estimate at T.D.DLB Page 56 Milne Point Unit I-38 SB NB Producer Drilling Procedure 30.0 Spider Plot (NAD 27) (Governmental Sections) Page 57 Milne Point Unit I-38 SB NB Producer Drilling Procedure 31.0 Surface Plat (As Built) (NAD 27) 02 July, 2020 Plan: MPU I-38 wp08 Milne Point M Pt I Pad Plan: MPU I-38 MPU I-38 075015002250300037504500True Vertical Depth (1500 usft/in)-1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500Vertical Section at 16.75° (1500 usft/in)MPI-Cedar Mtn wp02 CP1MPI-Cedar Mtn wp02 CP2MPI-Cedar Mtn wp02 CP3MPI-Cedar Mtn wp05 HeelMPI-Cedar Mtn wp05 toeMPI-Cedar Mtn wp05 CP49 5/8" x 12 1/4"4 1/2" x 8 1/2"500100015002000250030003500400045005000550060006500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 130 00 135 00 14000 14500 15 000 1550 0 16000165001700017208MPU I-38 wp08Start Dir 3º/100' : 500' MD, 500'TVDStart Dir 4º/100' : 550' MD, 549.99'TVDEnd Dir : 1849.66' MD, 1689.49' TVDStart Dir 4º/100' : 2749.66' MD, 2268'TVDEnd Dir : 3229.76' MD, 2551.8' TVDStart Dir 4º/100' : 4071.86' MD, 2996.76'TVDEnd Dir : 5283.54' MD, 3557.97' TVDSTART ESP TANGENTEND ESP TANGENTStart Dir 5º/100' : 5433.54' MD, 3609.27'TVDEnd Dir : 5919.47' MD, 3726.39' TVDStartDir2º/100':6419.61'MD,3792.8'TVDEndDir:6892.56'MD,3822.24'TVDStartDir2º/100':8033.73'MD,3812.45'TVDEndDir:8286.93'MD,3810.15'TVDStartDir2º/100':9176.51'MD,3799.22'TVDEndDir:9450.87'MD,3803.02'TVDStartDir2º/100':12389.27'MD,3877.49'TVDEndDir:12718.63'MD,3885.29'TVDStartDir2º/100':15106.15'MD,3937.79'TVDEndDir:15153.27'MD,3939.15'TVDTotalDepth:17207.78'MD,4012.8'TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Pedal CurveWarning Method: Error RatioWELL DETAILS: Plan: MPU I-3832.20+N/-S +E/-WNorthingEastingLatittudeLongitude0.000.006009451.89551509.84 70° 26' 11.661 N 149° 34' 48.112 WSURVEY PROGRAMDate: 2020-06-17T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool26.50 800.00 MPU I-38 wp08 (MPU I-38) 3_Gyro-GC_Csg800.00 6419.61 MPU I-38 wp08 (MPU I-38) 3_MWD+IFR2+MS+Sag6419.61 17207.78 MPU I-38 wp08 (MPU I-38) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSNo formation data is availableREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-38, True NorthVertical (TVD) Reference:MPU I-38 As-built RKB @ 60.30usftMeasured Depth Reference:MPU I-38 As-built RKB @ 60.30usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt I PadWell:Plan: MPU I-38Wellbore:MPU I-38Design:MPU I-38 wp08CASING DETAILSTVD TVDSS MD SizeName3792.80 3732.50 6419.61 9-5/8 9 5/8" x 12 1/4"4012.80 3952.50 17207.78 4-1/2 4 1/2" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.002 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 500' MD, 500'TVD3 550.00 1.50 210.00 549.99 -0.57 -0.33 3.00 210.00 -0.64 Start Dir 4º/100' : 550' MD, 549.99'TVD4 720.00 8.30 210.00 719.27 -13.13 -7.58 4.00 0.00 -14.765 1070.00 20.48 240.91 1058.06 -65.04 -74.06 4.00 48.00 -83.636 1849.66 50.00 260.00 1689.49 -186.23 -497.89 4.00 28.93 -321.82 End Dir : 1849.66' MD, 1689.49' TVD7 2749.66 50.00 260.00 2268.00 -305.95 -1176.86 0.00 0.00 -632.14 Start Dir 4º/100' : 2749.66' MD, 2268'TVD8 3229.76 58.10 281.60 2551.80 -296.82 -1561.20 4.00 71.82 -734.16 End Dir : 3229.76' MD, 2551.8' TVD9 4071.86 58.10 281.60 2996.76 -153.09 -2261.54 0.00 0.00 -798.36 Start Dir 4º/100' : 4071.86' MD, 2996.76'TVD10 5283.54 70.00 334.40 3557.97 503.35 -3059.55 4.00 89.25 -399.75 End Dir : 5283.54' MD, 3557.97' TVD11 5433.54 70.00 334.40 3609.27 630.47 -3120.45 0.00 0.00 -295.58 END ESP TANGENT12 5919.47 82.37 355.99 3726.39 1083.41 -3237.69 5.00 62.43 104.35 End Dir : 5919.47' MD, 3726.39' TVD13 6419.61 82.37 355.99 3792.80 1577.90 -3272.34 0.00 0.00 567.88 MPI-Cedar Mtn wp05 Heel Start Dir 2º/100' : 6419.61' MD, 3792.8'TVD14 6892.56 90.49 0.85 3822.24 2049.22 -3285.22 2.00 31.05 1015.49 End Dir : 6892.56' MD, 3822.24' TVD15 8033.73 90.49 0.85 3812.45 3190.21 -3268.19 0.00 0.00 2112.98 Start Dir 2º/100' : 8033.73' MD, 3812.45'TVD16 8273.98 90.54 5.66 3810.29 3430.00 -3254.55 2.00 89.40 2346.52 MPI-Cedar Mtn wp02 CP117 8286.93 90.70 5.46 3810.15 3442.89 -3253.29 2.00 -50.76 2359.22 End Dir : 8286.93' MD, 3810.15' TVD18 9176.51 90.70 5.46 3799.22 4328.37 -3168.66 0.00 0.00 3231.53 Start Dir 2º/100' : 9176.51' MD, 3799.22'TVD19 9342.72 88.56 8.00 3800.29 4493.40 -3149.19 2.00 130.16 3395.17 MPI-Cedar Mtn wp02 CP220 9450.87 88.55 10.16 3803.02 4600.16 -3132.12 2.00 90.35 3502.31 End Dir : 9450.87' MD, 3803.02' TVD21 12389.27 88.55 10.16 3877.49 7491.52 -2613.78 0.00 0.00 6420.38 Start Dir 2º/100' : 12389.27' MD, 3877.49'TVD22 12718.63 88.74 16.75 3885.29 7811.58 -2537.20 2.00 88.41 6748.93 MPI-Cedar Mtn wp02 CP3 End Dir : 12718.63' MD, 3885.29' TVD23 15106.15 88.74 16.75 3937.79 10097.24 -1849.29 0.00 0.00 9135.87 MPI-Cedar Mtn wp05 CP4 Start Dir 2º/100' : 15106.15' MD, 3937.79'TVD24 15153.27 87.95 17.26 3939.15 10142.29 -1835.52 2.00 147.44 9182.97 End Dir : 15153.27' MD, 3939.15' TVD25 17207.78 87.95 17.26 4012.80 12103.04 -1226.40 0.00 0.00 11236.08 MPI-Cedar Mtn wp05 toe Total Depth : 17207.78' MD, 4012.8' TVD -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 South(-)/North(+) (1500 usft/in)-6750 -6000 -5250 -4500 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 West(-)/East(+) (1500 usft/in) MPI-Cedar Mtn wp05 CP4 MPI-Cedar Mtn wp05 toe MPI-Cedar Mtn wp05 Heel MPI-Cedar Mtn wp02 CP3 MPI-Cedar Mtn wp02 CP2 MPI-Cedar Mtn wp02 CP1 9 5/8" x 12 1/4" 4 1/2" x 8 1/2" 500 1250175020002250250027503000325035003 7 5 0 4000 4013 MPU I-38 wp08 Start Dir 3º/100' : 500' MD, 500'TVD Start Dir 4º/100' : 550' MD, 549.99'TVD End Dir : 1849.66' MD, 1689.49' TVD Start Dir 4º/100' : 2749.66' MD, 2268'TVD End Dir : 3229.76' MD, 2551.8' TVD Start Dir 4º/100' : 4071.86' MD, 2996.76'TVD End Dir : 5283.54' MD, 3557.97' TVD START ESP TANGENT END ESP TANGENT Start Dir 5º/100' : 5433.54' MD, 3609.27'TVD End Dir : 5919.47' MD, 3726.39' TVD Start Dir 2º/100' : 6419.61' MD, 3792.8'TVD End Dir : 6892.56' MD, 3822.24' TVD Start Dir 2º/100' : 8033.73' MD, 3812.45'TVD End Dir : 8286.93' MD, 3810.15' TVD Start Dir 2º/100' : 9176.51' MD, 3799.22'TVD End Dir : 9450.87' MD, 3803.02' TVD Start Dir 2º/100' : 12389.27' MD, 3877.49'TVD End Dir : 12718.63' MD, 3885.29' TVD Start Dir 2º/100' : 15106.15' MD, 3937.79'TVD End Dir : 15153.27' MD, 3939.15' TVD Total Depth : 17207.78' MD, 4012.8' TVD CASING DETAILS TVD TVDSS MD Size Name 3792.80 3732.50 6419.61 9-5/8 9 5/8" x 12 1/4" 4012.80 3952.50 17207.78 4-1/2 4 1/2" x 8 1/2" Project: Milne Point Site: M Pt I Pad Well: Plan: MPU I-38 Wellbore: MPU I-38 Plan: MPU I-38 wp08 WELL DETAILS: Plan: MPU I-38 32.20 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 6009451.89 551509.84 70° 26' 11.661 N 149° 34' 48.112 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPU I-38, True North Vertical (TVD) Reference:MPU I-38 As-built RKB @ 60.30usft Measured Depth Reference:MPU I-38 As-built RKB @ 60.30usft Calculation Method:Minimum Curvature Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 As-built RKB @ 60.30usft Design:MPU I-38 wp08 Database:NORTH US + CANADA MD Reference:MPU I-38 As-built RKB @ 60.30usft North Reference: Well Plan: MPU I-38 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: From: Site Latitude: Longitude: Position Uncertainty: Northing: Easting: Grid Convergence: M Pt I Pad, TR-13-10 usft Map usft usft °0.39Slot Radius:"0 6,008,388.01 550,245.83 0.00 70° 26' 1.282 N 149° 35' 25.422 W Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: Plan: MPU I-38 usft usft 0.00 0.00 6,009,451.89 551,509.84 32.20Wellhead Elevation:33.80 usft0.50 70° 26' 11.661 N 149° 34' 48.112 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-38 Model NameMagnetics BGGM2020 8/17/2020 15.89 80.83 57,370.04649648 Phase:Version: Audit Notes: Design MPU I-38 wp08 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:26.50 16.750.000.0026.50 7/2/2020 1:56:07PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 As-built RKB @ 60.30usft Design:MPU I-38 wp08 Database:NORTH US + CANADA MD Reference:MPU I-38 As-built RKB @ 60.30usft North Reference: Well Plan: MPU I-38 True Inclination (°) Azimuth (°) +E/-W (usft) Tool Face (°) +N/-S (usft) Measured Depth (usft) Vertical Depth (usft) Dogleg Rate (°/100usft) Build Rate (°/100usft) Turn Rate (°/100usft) Plan Sections TVD System usft 0.000.000.000.000.000.0026.500.000.0026.50 -33.80 0.000.000.000.000.000.00500.000.000.00500.00 439.70 210.000.003.003.00-0.33-0.57549.99210.001.50550.00 489.69 0.000.004.004.00-7.58-13.13719.27210.008.30720.00 658.97 48.008.833.484.00-74.06-65.041,058.06240.9120.481,070.00 997.76 28.932.453.794.00-497.89-186.231,689.49260.0050.001,849.66 1,629.19 0.000.000.000.00-1,176.86-305.952,268.00260.0050.002,749.66 2,207.70 71.824.501.694.00-1,561.20-296.822,551.80281.6058.103,229.76 2,491.50 0.000.000.000.00-2,261.54-153.092,996.76281.6058.104,071.86 2,936.46 89.254.360.984.00-3,059.55503.353,557.97334.4070.005,283.54 3,497.67 0.000.000.000.00-3,120.45630.473,609.27334.4070.005,433.54 3,548.97 62.434.442.555.00-3,237.691,083.413,726.39355.9982.375,919.47 3,666.09 0.000.000.000.00-3,272.341,577.903,792.80355.9982.376,419.61 3,732.50 31.051.031.722.00-3,285.222,049.223,822.240.8590.496,892.56 3,761.94 0.000.000.000.00-3,268.193,190.213,812.450.8590.498,033.73 3,752.15 89.402.000.022.00-3,254.553,430.003,810.295.6690.548,273.98 3,749.99 -50.76-1.551.272.00-3,253.293,442.893,810.155.4690.708,286.93 3,749.85 0.000.000.000.00-3,168.664,328.373,799.225.4690.709,176.51 3,738.92 130.161.53-1.292.00-3,149.194,493.403,800.298.0088.569,342.72 3,739.99 90.352.00-0.012.00-3,132.124,600.163,803.0210.1688.559,450.87 3,742.72 0.000.000.000.00-2,613.787,491.523,877.4910.1688.5512,389.27 3,817.19 88.412.000.062.00-2,537.207,811.583,885.2916.7588.7412,718.63 3,824.99 0.000.000.000.00-1,849.2910,097.243,937.7916.7588.7415,106.15 3,877.49 147.441.08-1.692.00-1,835.5210,142.293,939.1517.2687.9515,153.27 3,878.85 0.000.000.000.00-1,226.4012,103.044,012.8017.2687.9517,207.78 3,952.50 7/2/2020 1:56:07PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 As-built RKB @ 60.30usft Design:MPU I-38 wp08 Database:NORTH US + CANADA MD Reference:MPU I-38 As-built RKB @ 60.30usft North Reference: Well Plan: MPU I-38 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS -33.80 Vert Section 26.50 0.00 26.50 0.00 0.000.00 551,509.846,009,451.89-33.80 0.00 0.00 100.00 0.00 100.00 0.00 0.000.00 551,509.846,009,451.8939.70 0.00 0.00 200.00 0.00 200.00 0.00 0.000.00 551,509.846,009,451.89139.70 0.00 0.00 300.00 0.00 300.00 0.00 0.000.00 551,509.846,009,451.89239.70 0.00 0.00 400.00 0.00 400.00 0.00 0.000.00 551,509.846,009,451.89339.70 0.00 0.00 500.00 0.00 500.00 0.00 0.000.00 551,509.846,009,451.89439.70 0.00 0.00 Start Dir 3º/100' : 500' MD, 500'TVD 550.00 1.50 549.99 -0.57 -0.33210.00 551,509.526,009,451.32489.69 3.00 -0.64 Start Dir 4º/100' : 550' MD, 549.99'TVD 600.00 3.50 599.94 -2.46 -1.42210.00 551,508.446,009,449.43539.64 4.00 -2.76 700.00 7.50 699.46 -10.75 -6.21210.00 551,503.716,009,441.09639.16 4.00 -12.09 720.00 8.30 719.27 -13.13 -7.58210.00 551,502.356,009,438.70658.97 4.00 -14.76 800.00 10.71 798.18 -23.58 -15.53222.90 551,494.476,009,428.20737.88 4.00 -27.06 900.00 14.16 895.83 -37.86 -31.55232.38 551,478.566,009,413.82835.53 4.00 -45.34 1,000.00 17.84 991.94 -53.42 -54.25238.11 551,455.966,009,398.10931.64 4.00 -66.79 1,070.00 20.48 1,058.06 -65.04 -74.06240.91 551,436.236,009,386.34997.76 4.00 -83.63 1,100.00 21.54 1,086.07 -70.14 -83.54242.49 551,426.806,009,381.181,025.77 4.00 -91.24 1,200.00 25.16 1,177.87 -86.99 -119.38246.83 551,391.086,009,364.091,117.57 4.00 -117.70 1,300.00 28.87 1,266.95 -103.56 -161.64250.13 551,348.946,009,347.221,206.65 4.00 -145.75 1,400.00 32.64 1,352.88 -119.78 -210.11252.73 551,300.586,009,330.681,292.58 4.00 -175.25 1,500.00 36.46 1,435.23 -135.56 -264.56254.84 551,246.256,009,314.521,374.93 4.00 -206.05 1,600.00 40.31 1,513.60 -150.83 -324.73256.60 551,186.196,009,298.841,453.30 4.00 -238.01 1,700.00 44.18 1,587.63 -165.51 -390.31258.10 551,120.726,009,283.711,527.33 4.00 -270.97 1,800.00 48.06 1,656.93 -179.53 -461.00259.41 551,050.146,009,269.201,596.63 4.00 -304.77 1,849.66 50.00 1,689.49 -186.23 -497.89260.00 551,013.306,009,262.241,629.19 4.00 -321.82 End Dir : 1849.66' MD, 1689.49' TVD 1,900.00 50.00 1,721.84 -192.93 -535.87260.00 550,975.376,009,255.291,661.54 0.00 -339.18 2,000.00 50.00 1,786.12 -206.23 -611.31260.00 550,900.036,009,241.461,725.82 0.00 -373.65 2,100.00 50.00 1,850.40 -219.53 -686.75260.00 550,824.696,009,227.641,790.10 0.00 -408.13 2,200.00 50.00 1,914.68 -232.83 -762.19260.00 550,749.356,009,213.821,854.38 0.00 -442.61 2,300.00 50.00 1,978.96 -246.14 -837.63260.00 550,674.016,009,200.001,918.66 0.00 -477.09 2,400.00 50.00 2,043.24 -259.44 -913.07260.00 550,598.676,009,186.181,982.94 0.00 -511.57 2,500.00 50.00 2,107.52 -272.74 -988.51260.00 550,523.336,009,172.362,047.22 0.00 -546.05 2,600.00 50.00 2,171.80 -286.04 -1,063.95260.00 550,447.996,009,158.532,111.50 0.00 -580.53 2,700.00 50.00 2,236.07 -299.34 -1,139.39260.00 550,372.656,009,144.712,175.77 0.00 -615.01 2,749.66 50.00 2,267.99 -305.95 -1,176.85260.00 550,335.246,009,137.852,207.69 0.00 -632.13 Start Dir 4º/100' : 2749.66' MD, 2268'TVD 2,800.00 50.65 2,300.13 -311.85 -1,215.14262.47 550,297.006,009,131.692,239.83 4.00 -648.82 2,900.00 52.11 2,362.57 -318.81 -1,292.92267.25 550,219.286,009,124.192,302.27 4.00 -677.90 3,000.00 53.74 2,422.88 -319.43 -1,372.66271.82 550,139.556,009,123.022,362.58 4.00 -701.47 3,100.00 55.54 2,480.76 -313.69 -1,453.98276.20 550,058.206,009,128.202,420.46 4.00 -719.41 3,200.00 57.50 2,535.94 -301.63 -1,536.48280.39 549,975.636,009,139.692,475.64 4.00 -731.64 3,229.76 58.10 2,551.80 -296.82 -1,561.20281.60 549,950.886,009,144.322,491.50 4.00 -734.16 End Dir : 3229.76' MD, 2551.8' TVD 3,300.00 58.10 2,588.91 -284.84 -1,619.61281.60 549,892.396,009,155.902,528.61 0.00 -739.52 7/2/2020 1:56:07PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 As-built RKB @ 60.30usft Design:MPU I-38 wp08 Database:NORTH US + CANADA MD Reference:MPU I-38 As-built RKB @ 60.30usft North Reference: Well Plan: MPU I-38 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 2,581.45 Vert Section 3,400.00 58.10 2,641.75 -267.77 -1,702.78281.60 549,809.126,009,172.402,581.45 0.00 -747.14 3,500.00 58.10 2,694.59 -250.70 -1,785.94281.60 549,725.846,009,188.892,634.29 0.00 -754.76 3,600.00 58.10 2,747.43 -233.63 -1,869.11281.60 549,642.576,009,205.382,687.13 0.00 -762.39 3,700.00 58.10 2,800.27 -216.56 -1,952.28281.60 549,559.296,009,221.872,739.97 0.00 -770.01 3,800.00 58.10 2,853.11 -199.49 -2,035.44281.60 549,476.026,009,238.362,792.81 0.00 -777.64 3,900.00 58.10 2,905.95 -182.43 -2,118.61281.60 549,392.756,009,254.862,845.65 0.00 -785.26 4,000.00 58.10 2,958.79 -165.36 -2,201.78281.60 549,309.476,009,271.352,898.49 0.00 -792.88 4,071.86 58.10 2,996.76 -153.09 -2,261.54281.60 549,249.636,009,283.202,936.46 0.00 -798.36 Start Dir 4º/100' : 4071.86' MD, 2996.76'TVD 4,100.00 58.12 3,011.63 -148.02 -2,284.89282.92 549,226.256,009,288.112,951.33 4.00 -800.23 4,200.00 58.31 3,064.32 -125.63 -2,366.85287.62 549,144.146,009,309.933,004.02 4.00 -802.42 4,300.00 58.67 3,116.60 -96.53 -2,446.95292.30 549,063.856,009,338.473,056.30 4.00 -797.64 4,400.00 59.20 3,168.22 -60.86 -2,524.79296.93 548,985.776,009,373.603,107.92 4.00 -785.92 4,500.00 59.89 3,218.93 -18.80 -2,599.99301.50 548,910.296,009,415.143,158.63 4.00 -767.31 4,600.00 60.73 3,268.48 29.45 -2,672.19306.00 548,837.776,009,462.893,208.18 4.00 -741.91 4,700.00 61.73 3,316.62 83.66 -2,741.03310.42 548,768.566,009,516.613,256.32 4.00 -709.84 4,800.00 62.86 3,363.14 143.57 -2,806.18314.75 548,703.016,009,576.063,302.84 4.00 -671.26 4,900.00 64.12 3,407.78 208.87 -2,867.32318.99 548,641.426,009,640.933,347.48 4.00 -626.34 5,000.00 65.51 3,450.35 279.25 -2,924.15323.14 548,584.116,009,710.913,390.05 4.00 -575.33 5,100.00 67.00 3,490.63 354.37 -2,976.40327.20 548,531.356,009,785.673,430.33 4.00 -518.45 5,200.00 68.60 3,528.43 433.87 -3,023.82331.16 548,483.396,009,864.823,468.13 4.00 -455.99 5,283.54 70.00 3,557.97 503.35 -3,059.55334.40 548,447.196,009,934.053,497.67 4.00 -399.75 End Dir : 5283.54' MD, 3557.97' TVD 5,284.00 70.00 3,558.12 503.74 -3,059.73334.40 548,447.006,009,934.443,497.82 0.01 -399.43 START ESP TANGENT 5,300.00 70.00 3,563.60 517.30 -3,066.23334.40 548,440.416,009,947.953,503.30 0.00 -388.32 5,400.00 70.00 3,597.80 602.05 -3,106.83334.40 548,399.236,010,032.413,537.50 0.00 -318.88 5,433.00 70.00 3,609.08 630.01 -3,120.23334.40 548,385.646,010,060.283,548.78 0.00 -295.96 END ESP TANGENT 5,433.54 70.00 3,609.27 630.47 -3,120.45334.40 548,385.416,010,060.733,548.97 0.00 -295.58 Start Dir 5º/100' : 5433.54' MD, 3609.27'TVD 5,500.00 71.56 3,631.15 687.77 -3,146.01337.50 548,359.466,010,117.853,570.85 5.00 -248.08 5,600.00 74.01 3,660.75 777.38 -3,178.98342.07 548,325.886,010,207.233,600.45 5.00 -171.77 5,700.00 76.55 3,686.17 870.46 -3,205.12346.52 548,299.096,010,300.113,625.87 5.00 -90.17 5,800.00 79.17 3,707.21 966.30 -3,224.25350.88 548,279.316,010,395.813,646.91 5.00 -3.91 5,900.00 81.84 3,723.72 1,064.17 -3,236.21355.17 548,266.676,010,493.583,663.42 5.00 86.36 5,919.47 82.37 3,726.39 1,083.40 -3,237.69355.99 548,265.066,010,512.803,666.09 5.00 104.34 End Dir : 5919.47' MD, 3726.39' TVD 6,000.00 82.37 3,737.08 1,163.02 -3,243.27355.99 548,258.936,010,592.373,676.78 0.00 178.98 6,100.00 82.37 3,750.36 1,261.89 -3,250.20355.99 548,251.326,010,691.193,690.06 0.00 271.66 6,200.00 82.37 3,763.64 1,360.77 -3,257.13355.99 548,243.716,010,790.003,703.34 0.00 364.34 6,300.00 82.37 3,776.92 1,459.64 -3,264.05355.99 548,236.106,010,888.813,716.62 0.00 457.02 6,400.00 82.37 3,790.20 1,558.51 -3,270.98355.99 548,228.496,010,987.623,729.90 0.00 549.70 6,419.61 82.37 3,792.80 1,577.90 -3,272.34355.99 548,227.006,011,007.003,732.50 0.00 567.88 Start Dir 2º/100' : 6419.61' MD, 3792.8'TVD - 9 5/8" x 12 1/4" 7/2/2020 1:56:07PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 As-built RKB @ 60.30usft Design:MPU I-38 wp08 Database:NORTH US + CANADA MD Reference:MPU I-38 As-built RKB @ 60.30usft North Reference: Well Plan: MPU I-38 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 3,742.22 Vert Section 6,500.00 83.75 3,802.52 1,657.54 -3,277.33356.83 548,221.456,011,086.603,742.22 2.00 642.70 6,600.00 85.46 3,811.92 1,756.99 -3,281.95357.86 548,216.156,011,186.003,751.62 2.00 736.59 6,700.00 87.18 3,818.33 1,856.74 -3,284.78358.88 548,212.636,011,285.723,758.03 2.00 831.29 6,800.00 88.90 3,821.75 1,956.67 -3,285.84359.91 548,210.896,011,385.633,761.45 2.00 926.68 6,892.56 90.49 3,822.24 2,049.22 -3,285.220.85 548,210.866,011,478.173,761.94 2.00 1,015.48 End Dir : 6892.56' MD, 3822.24' TVD 6,900.00 90.49 3,822.18 2,056.66 -3,285.110.85 548,210.926,011,485.613,761.88 0.00 1,022.64 7,000.00 90.49 3,821.32 2,156.64 -3,283.620.85 548,211.736,011,585.603,761.02 0.00 1,118.81 7,100.00 90.49 3,820.46 2,256.63 -3,282.120.85 548,212.536,011,685.583,760.16 0.00 1,214.99 7,200.00 90.49 3,819.60 2,356.61 -3,280.630.85 548,213.336,011,785.563,759.30 0.00 1,311.16 7,300.00 90.49 3,818.75 2,456.60 -3,279.140.85 548,214.136,011,885.553,758.45 0.00 1,407.33 7,400.00 90.49 3,817.89 2,556.58 -3,277.650.85 548,214.936,011,985.533,757.59 0.00 1,503.51 7,500.00 90.49 3,817.03 2,656.57 -3,276.160.85 548,215.736,012,085.513,756.73 0.00 1,599.68 7,600.00 90.49 3,816.17 2,756.55 -3,274.660.85 548,216.536,012,185.503,755.87 0.00 1,695.85 7,700.00 90.49 3,815.32 2,856.54 -3,273.170.85 548,217.346,012,285.483,755.02 0.00 1,792.02 7,800.00 90.49 3,814.46 2,956.52 -3,271.680.85 548,218.146,012,385.463,754.16 0.00 1,888.20 7,900.00 90.49 3,813.60 3,056.51 -3,270.190.85 548,218.946,012,485.453,753.30 0.00 1,984.37 8,000.00 90.49 3,812.74 3,156.49 -3,268.700.85 548,219.746,012,585.433,752.44 0.00 2,080.54 8,033.73 90.49 3,812.45 3,190.22 -3,268.190.85 548,220.016,012,619.153,752.15 0.00 2,112.98 Start Dir 2º/100' : 8033.73' MD, 3812.45'TVD 8,100.00 90.51 3,811.88 3,256.46 -3,266.442.18 548,221.316,012,685.403,751.58 2.00 2,176.92 8,200.00 90.53 3,810.98 3,356.30 -3,260.894.18 548,226.176,012,785.263,750.68 2.00 2,274.12 8,273.98 90.54 3,810.29 3,430.00 -3,254.555.66 548,232.006,012,859.003,749.99 2.00 2,346.52 8,286.93 90.70 3,810.15 3,442.89 -3,253.295.46 548,233.176,012,871.903,749.85 2.00 2,359.23 End Dir : 8286.93' MD, 3810.15' TVD 8,300.00 90.70 3,809.99 3,455.90 -3,252.055.46 548,234.326,012,884.913,749.69 0.00 2,372.04 8,400.00 90.70 3,808.76 3,555.44 -3,242.535.46 548,243.146,012,984.513,748.46 0.00 2,470.10 8,500.00 90.70 3,807.53 3,654.98 -3,233.025.46 548,251.976,013,084.103,747.23 0.00 2,568.16 8,600.00 90.70 3,806.30 3,754.52 -3,223.515.46 548,260.796,013,183.693,746.00 0.00 2,666.21 8,700.00 90.70 3,805.08 3,854.05 -3,213.995.46 548,269.626,013,283.283,744.78 0.00 2,764.27 8,800.00 90.70 3,803.85 3,953.59 -3,204.485.46 548,278.446,013,382.883,743.55 0.00 2,862.33 8,900.00 90.70 3,802.62 4,053.13 -3,194.975.46 548,287.276,013,482.473,742.32 0.00 2,960.39 9,000.00 90.70 3,801.39 4,152.67 -3,185.455.46 548,296.096,013,582.063,741.09 0.00 3,058.44 9,100.00 90.70 3,800.16 4,252.21 -3,175.945.46 548,304.926,013,681.653,739.86 0.00 3,156.50 9,176.51 90.70 3,799.22 4,328.37 -3,168.665.46 548,311.676,013,757.853,738.92 0.00 3,231.52 Start Dir 2º/100' : 9176.51' MD, 3799.22'TVD 9,200.00 90.40 3,799.00 4,351.74 -3,166.355.82 548,313.826,013,781.243,738.70 2.00 3,254.57 9,300.00 89.11 3,799.42 4,451.08 -3,154.897.35 548,324.596,013,880.643,739.12 2.00 3,353.00 9,342.72 88.56 3,800.29 4,493.40 -3,149.198.00 548,330.006,013,923.003,739.99 2.00 3,395.17 9,400.00 88.55 3,801.73 4,550.03 -3,140.659.15 548,338.146,013,979.683,741.43 2.00 3,451.85 9,450.87 88.55 3,803.02 4,600.16 -3,132.1210.16 548,346.336,014,029.863,742.72 2.00 3,502.31 End Dir : 9450.87' MD, 3803.02' TVD 9,500.00 88.55 3,804.26 4,648.50 -3,123.4610.16 548,354.666,014,078.263,743.96 0.00 3,551.11 9,600.00 88.55 3,806.80 4,746.90 -3,105.8210.16 548,371.626,014,176.773,746.50 0.00 3,650.41 9,700.00 88.55 3,809.33 4,845.30 -3,088.1810.16 548,388.576,014,275.283,749.03 0.00 3,749.72 7/2/2020 1:56:07PM COMPASS 5000.15 Build 91E Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 As-built RKB @ 60.30usft Design:MPU I-38 wp08 Database:NORTH US + CANADA MD Reference:MPU I-38 As-built RKB @ 60.30usft North Reference: Well Plan: MPU I-38 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 3,751.57 Vert Section 9,800.00 88.55 3,811.87 4,943.70 -3,070.5410.16 548,405.536,014,373.793,751.57 0.00 3,849.03 9,900.00 88.55 3,814.40 5,042.10 -3,052.9010.16 548,422.496,014,472.303,754.10 0.00 3,948.34 10,000.00 88.55 3,816.94 5,140.50 -3,035.2610.16 548,439.456,014,570.813,756.64 0.00 4,047.65 10,100.00 88.55 3,819.47 5,238.90 -3,017.6210.16 548,456.416,014,669.323,759.17 0.00 4,146.95 10,200.00 88.55 3,822.00 5,337.30 -2,999.9810.16 548,473.376,014,767.823,761.70 0.00 4,246.26 10,300.00 88.55 3,824.54 5,435.70 -2,982.3310.16 548,490.336,014,866.333,764.24 0.00 4,345.57 10,400.00 88.55 3,827.07 5,534.10 -2,964.6910.16 548,507.286,014,964.843,766.77 0.00 4,444.88 10,500.00 88.55 3,829.61 5,632.50 -2,947.0510.16 548,524.246,015,063.353,769.31 0.00 4,544.19 10,600.00 88.55 3,832.14 5,730.89 -2,929.4110.16 548,541.206,015,161.863,771.84 0.00 4,643.49 10,700.00 88.55 3,834.68 5,829.29 -2,911.7710.16 548,558.166,015,260.373,774.38 0.00 4,742.80 10,800.00 88.55 3,837.21 5,927.69 -2,894.1310.16 548,575.126,015,358.883,776.91 0.00 4,842.11 10,900.00 88.55 3,839.74 6,026.09 -2,876.4910.16 548,592.086,015,457.393,779.44 0.00 4,941.42 11,000.00 88.55 3,842.28 6,124.49 -2,858.8510.16 548,609.046,015,555.903,781.98 0.00 5,040.73 11,100.00 88.55 3,844.81 6,222.89 -2,841.2110.16 548,625.996,015,654.413,784.51 0.00 5,140.03 11,200.00 88.55 3,847.35 6,321.29 -2,823.5710.16 548,642.956,015,752.923,787.05 0.00 5,239.34 11,300.00 88.55 3,849.88 6,419.69 -2,805.9310.16 548,659.916,015,851.423,789.58 0.00 5,338.65 11,400.00 88.55 3,852.42 6,518.09 -2,788.2910.16 548,676.876,015,949.933,792.12 0.00 5,437.96 11,500.00 88.55 3,854.95 6,616.49 -2,770.6510.16 548,693.836,016,048.443,794.65 0.00 5,537.27 11,600.00 88.55 3,857.48 6,714.89 -2,753.0110.16 548,710.796,016,146.953,797.18 0.00 5,636.57 11,700.00 88.55 3,860.02 6,813.29 -2,735.3710.16 548,727.756,016,245.463,799.72 0.00 5,735.88 11,800.00 88.55 3,862.55 6,911.68 -2,717.7310.16 548,744.706,016,343.973,802.25 0.00 5,835.19 11,900.00 88.55 3,865.09 7,010.08 -2,700.0910.16 548,761.666,016,442.483,804.79 0.00 5,934.50 12,000.00 88.55 3,867.62 7,108.48 -2,682.4510.16 548,778.626,016,540.993,807.32 0.00 6,033.81 12,100.00 88.55 3,870.16 7,206.88 -2,664.8110.16 548,795.586,016,639.503,809.86 0.00 6,133.12 12,200.00 88.55 3,872.69 7,305.28 -2,647.1710.16 548,812.546,016,738.013,812.39 0.00 6,232.42 12,300.00 88.55 3,875.22 7,403.68 -2,629.5310.16 548,829.506,016,836.523,814.92 0.00 6,331.73 12,389.27 88.55 3,877.49 7,491.52 -2,613.7810.16 548,844.646,016,924.463,817.19 0.00 6,420.38 Start Dir 2º/100' : 12389.27' MD, 3877.49'TVD 12,400.00 88.55 3,877.76 7,502.08 -2,611.8710.38 548,846.486,016,935.023,817.46 2.00 6,431.04 12,500.00 88.61 3,880.23 7,600.08 -2,592.1512.38 548,865.526,017,033.153,819.93 2.00 6,530.57 12,600.00 88.67 3,882.61 7,697.33 -2,569.0214.38 548,887.976,017,130.553,822.31 2.00 6,630.36 12,700.00 88.73 3,884.88 7,793.72 -2,542.5116.38 548,913.816,017,227.113,824.58 2.00 6,730.30 12,718.63 88.74 3,885.29 7,811.57 -2,537.2016.75 548,919.006,017,245.003,824.99 2.00 6,748.93 End Dir : 12718.63' MD, 3885.29' TVD 12,800.00 88.74 3,887.08 7,889.47 -2,513.7616.75 548,941.906,017,323.053,826.78 0.00 6,830.28 12,900.00 88.74 3,889.28 7,985.21 -2,484.9416.75 548,970.056,017,418.973,828.98 0.00 6,930.25 13,000.00 88.74 3,891.48 8,080.94 -2,456.1316.75 548,998.206,017,514.893,831.18 0.00 7,030.23 13,100.00 88.74 3,893.68 8,176.67 -2,427.3216.75 549,026.356,017,610.813,833.38 0.00 7,130.20 13,200.00 88.74 3,895.87 8,272.41 -2,398.5016.75 549,054.506,017,706.733,835.57 0.00 7,230.18 13,300.00 88.74 3,898.07 8,368.14 -2,369.6916.75 549,082.646,017,802.653,837.77 0.00 7,330.16 13,400.00 88.74 3,900.27 8,463.88 -2,340.8816.75 549,110.796,017,898.583,839.97 0.00 7,430.13 13,500.00 88.74 3,902.47 8,559.61 -2,312.0716.75 549,138.946,017,994.503,842.17 0.00 7,530.11 13,600.00 88.74 3,904.67 8,655.34 -2,283.2516.75 549,167.096,018,090.423,844.37 0.00 7,630.08 13,700.00 88.74 3,906.87 8,751.08 -2,254.4416.75 549,195.246,018,186.343,846.57 0.00 7,730.06 13,800.00 88.74 3,909.07 8,846.81 -2,225.6316.75 549,223.386,018,282.263,848.77 0.00 7,830.04 7/2/2020 1:56:07PM COMPASS 5000.15 Build 91E Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 As-built RKB @ 60.30usft Design:MPU I-38 wp08 Database:NORTH US + CANADA MD Reference:MPU I-38 As-built RKB @ 60.30usft North Reference: Well Plan: MPU I-38 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 3,850.97 Vert Section 13,900.00 88.74 3,911.27 8,942.55 -2,196.8216.75 549,251.536,018,378.183,850.97 0.00 7,930.01 14,000.00 88.74 3,913.47 9,038.28 -2,168.0016.75 549,279.686,018,474.103,853.17 0.00 8,029.99 14,100.00 88.74 3,915.67 9,134.01 -2,139.1916.75 549,307.836,018,570.033,855.37 0.00 8,129.96 14,200.00 88.74 3,917.86 9,229.75 -2,110.3816.75 549,335.986,018,665.953,857.56 0.00 8,229.94 14,300.00 88.74 3,920.06 9,325.48 -2,081.5716.75 549,364.126,018,761.873,859.76 0.00 8,329.91 14,400.00 88.74 3,922.26 9,421.22 -2,052.7516.75 549,392.276,018,857.793,861.96 0.00 8,429.89 14,500.00 88.74 3,924.46 9,516.95 -2,023.9416.75 549,420.426,018,953.713,864.16 0.00 8,529.87 14,600.00 88.74 3,926.66 9,612.68 -1,995.1316.75 549,448.576,019,049.633,866.36 0.00 8,629.84 14,700.00 88.74 3,928.86 9,708.42 -1,966.3116.75 549,476.726,019,145.553,868.56 0.00 8,729.82 14,800.00 88.74 3,931.06 9,804.15 -1,937.5016.75 549,504.866,019,241.483,870.76 0.00 8,829.79 14,900.00 88.74 3,933.26 9,899.89 -1,908.6916.75 549,533.016,019,337.403,872.96 0.00 8,929.77 15,000.00 88.74 3,935.46 9,995.62 -1,879.8816.75 549,561.166,019,433.323,875.16 0.00 9,029.75 15,106.15 88.74 3,937.79 10,097.24 -1,849.2916.75 549,591.046,019,535.143,877.49 0.00 9,135.87 Start Dir 2º/100' : 15106.15' MD, 3937.79'TVD 15,153.27 87.95 3,939.15 10,142.28 -1,835.5217.26 549,604.506,019,580.273,878.85 2.00 9,182.97 End Dir : 15153.27' MD, 3939.15' TVD 15,200.00 87.95 3,940.83 10,186.88 -1,821.6617.26 549,618.046,019,624.963,880.53 0.00 9,229.67 15,300.00 87.95 3,944.41 10,282.32 -1,792.0217.26 549,647.036,019,720.593,884.11 0.00 9,329.60 15,400.00 87.95 3,948.00 10,377.75 -1,762.3717.26 549,676.016,019,816.223,887.70 0.00 9,429.53 15,500.00 87.95 3,951.58 10,473.19 -1,732.7217.26 549,705.006,019,911.853,891.28 0.00 9,529.46 15,600.00 87.95 3,955.17 10,568.63 -1,703.0717.26 549,733.986,020,007.483,894.87 0.00 9,629.39 15,700.00 87.95 3,958.75 10,664.06 -1,673.4317.26 549,762.976,020,103.113,898.45 0.00 9,729.33 15,800.00 87.95 3,962.34 10,759.50 -1,643.7817.26 549,791.956,020,198.743,902.04 0.00 9,829.26 15,900.00 87.95 3,965.92 10,854.94 -1,614.1317.26 549,820.946,020,294.373,905.62 0.00 9,929.19 16,000.00 87.95 3,969.51 10,950.37 -1,584.4817.26 549,849.926,020,390.003,909.21 0.00 10,029.12 16,100.00 87.95 3,973.09 11,045.81 -1,554.8417.26 549,878.916,020,485.633,912.79 0.00 10,129.05 16,200.00 87.95 3,976.67 11,141.25 -1,525.1917.26 549,907.896,020,581.263,916.37 0.00 10,228.98 16,300.00 87.95 3,980.26 11,236.68 -1,495.5417.26 549,936.886,020,676.893,919.96 0.00 10,328.92 16,400.00 87.95 3,983.84 11,332.12 -1,465.8917.26 549,965.866,020,772.523,923.54 0.00 10,428.85 16,500.00 87.95 3,987.43 11,427.56 -1,436.2417.26 549,994.856,020,868.153,927.13 0.00 10,528.78 16,600.00 87.95 3,991.01 11,522.99 -1,406.6017.26 550,023.836,020,963.783,930.71 0.00 10,628.71 16,700.00 87.95 3,994.60 11,618.43 -1,376.9517.26 550,052.826,021,059.413,934.30 0.00 10,728.64 16,800.00 87.95 3,998.18 11,713.87 -1,347.3017.26 550,081.806,021,155.043,937.88 0.00 10,828.58 16,900.00 87.95 4,001.77 11,809.30 -1,317.6517.26 550,110.796,021,250.673,941.47 0.00 10,928.51 17,000.00 87.95 4,005.35 11,904.74 -1,288.0117.26 550,139.776,021,346.303,945.05 0.00 11,028.44 17,100.00 87.95 4,008.94 12,000.18 -1,258.3617.26 550,168.766,021,441.933,948.64 0.00 11,128.37 17,207.78 87.95 4,012.80 12,103.04 -1,226.4017.26 550,200.006,021,545.003,952.50 0.00 11,236.08 Total Depth : 17207.78' MD, 4012.8' TVD - 4 1/2" x 8 1/2" 7/2/2020 1:56:07PM COMPASS 5000.15 Build 91E Page 8 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 As-built RKB @ 60.30usft Design:MPU I-38 wp08 Database:NORTH US + CANADA MD Reference:MPU I-38 As-built RKB @ 60.30usft North Reference: Well Plan: MPU I-38 True Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Tar gets Dip Angle (°) Dip Dir. (°) MPI-Cedar Mtn wp05 CP4 3,937.79 6,019,426.08 549,559.049,988.39 -1,882.050.00 0.00 -plan misses target center by 2.50usft at 14992.51usft MD (3935.29 TVD, 9988.45 N, -1882.03 E) - Point MPI-Cedar Mtn wp02 CP2 3,800.29 6,013,923.00 548,330.004,493.40 -3,149.190.00 0.00 -plan hits target center - Point MPI-Cedar Mtn wp05 Heel 3,792.80 6,011,007.00 548,227.001,577.90 -3,272.340.00 0.00 -plan hits target center - Circle (radius 30.00) MPI-Cedar Mtn wp05 toe 4,012.80 6,021,545.00 550,200.0012,103.04 -1,226.400.00 0.00 -plan hits target center - Point MPI-Cedar Mtn wp02 CP1 3,810.29 6,012,859.00 548,232.003,430.00 -3,254.550.00 0.00 -plan hits target center - Point MPI-Cedar Mtn wp02 CP3 3,885.29 6,017,245.00 548,919.007,811.58 -2,537.200.00 0.00 -plan hits target center - Point Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 4 1/2" x 8 1/2"4,012.8017,207.78 4-1/2 8-1/2 9 5/8" x 12 1/4"3,792.806,419.61 9-5/8 12-1/4 7/2/2020 1:56:07PM COMPASS 5000.15 Build 91E Page 9 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-38 MPU I-38 Survey Calculation Method:Minimum Curvature MPU I-38 As-built RKB @ 60.30usft Design:MPU I-38 wp08 Database:NORTH US + CANADA MD Reference:MPU I-38 As-built RKB @ 60.30usft North Reference: Well Plan: MPU I-38 True Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 500.00 500.00 0.00 0.00 Start Dir 3º/100' : 500' MD, 500'TVD 550.00 549.99 -0.57 -0.33 Start Dir 4º/100' : 550' MD, 549.99'TVD 1,849.66 1,689.49 -186.23 -497.89 End Dir : 1849.66' MD, 1689.49' TVD 2,749.66 2,267.99 -305.95 -1,176.85 Start Dir 4º/100' : 2749.66' MD, 2268'TVD 3,229.76 2,551.80 -296.82 -1,561.20 End Dir : 3229.76' MD, 2551.8' TVD 4,071.86 2,996.76 -153.09 -2,261.54 Start Dir 4º/100' : 4071.86' MD, 2996.76'TVD 5,283.54 3,557.97 503.35 -3,059.55 End Dir : 5283.54' MD, 3557.97' TVD 5,284.00 3,558.12 503.74 -3,059.73 START ESP TANGENT 5,433.00 3,609.08 630.01 -3,120.23 END ESP TANGENT 5,433.54 3,609.27 630.47 -3,120.45 Start Dir 5º/100' : 5433.54' MD, 3609.27'TVD 5,919.47 3,726.39 1,083.40 -3,237.69 End Dir : 5919.47' MD, 3726.39' TVD 6,419.61 3,792.80 1,577.90 -3,272.34 Start Dir 2º/100' : 6419.61' MD, 3792.8'TVD 6,892.56 3,822.24 2,049.22 -3,285.22 End Dir : 6892.56' MD, 3822.24' TVD 8,033.73 3,812.45 3,190.22 -3,268.19 Start Dir 2º/100' : 8033.73' MD, 3812.45'TVD 8,286.93 3,810.15 3,442.89 -3,253.29 End Dir : 8286.93' MD, 3810.15' TVD 9,176.51 3,799.22 4,328.37 -3,168.66 Start Dir 2º/100' : 9176.51' MD, 3799.22'TVD 9,450.87 3,803.02 4,600.16 -3,132.12 End Dir : 9450.87' MD, 3803.02' TVD 12,389.27 3,877.49 7,491.52 -2,613.78 Start Dir 2º/100' : 12389.27' MD, 3877.49'TVD 12,718.63 3,885.29 7,811.57 -2,537.20 End Dir : 12718.63' MD, 3885.29' TVD 15,106.15 3,937.79 10,097.24 -1,849.29 Start Dir 2º/100' : 15106.15' MD, 3937.79'TVD 15,153.27 3,939.15 10,142.28 -1,835.52 End Dir : 15153.27' MD, 3939.15' TVD 17,207.78 4,012.80 12,103.04 -1,226.40 Total Depth : 17207.78' MD, 4012.8' TVD 7/2/2020 1:56:07PM COMPASS 5000.15 Build 91E Page 10 02 July, 2020Milne PointM Pt I PadPlan: MPU I-38MPU I-38MPU I-38 wp08Reference Design: M Pt I Pad - Plan: MPU I-38 - MPU I-38 - MPU I-38 wp08Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Well Coordinates: 6,009,451.89 N, 551,509.84 E (70° 26' 11.66" N, 149° 34' 48.11" W)Datum Height: MPU I-38 As-built RKB @ 60.30usftScan Range: 26.50 to 6,419.61 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.15 Build: 91EScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftNO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type:Scan Type:25.00 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-38 - MPU I-38 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 26.50 to 6,419.61 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-38 - MPU I-38 - MPU I-38 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningEX WSAK-25WSAK-25 - WSAK-25 - WSAK-25790.21 6,051.50 704.91 4,333.70 9.2646,051.50Clearance Factor Pass - WSAK-25 - WSAK-25 - WSAK-25782.00 6,151.50 698.28 4,316.39 9.3416,151.50Ellipse Separation Pass - WSAK-25 - WSAK-25 - WSAK-25781.82 6,168.55 698.38 4,313.36 9.3696,168.55Centre Distance Pass - M Pt I PadMPI-01 - MPI-01 - MPI-01165.47 26.50 163.90 36.20 105.41126.50Centre Distance Pass - MPI-01 - MPI-01 - MPI-01166.79 301.50 163.73 309.99 54.482301.50Ellipse Separation Pass - MPI-01 - MPI-01 - MPI-01207.63 776.50 200.99 758.19 31.259776.50Clearance Factor Pass - MPI-02 - MPI-02 - MPI-02105.30 339.22 101.95 348.92 31.451339.22Centre Distance Pass - MPI-02 - MPI-02 - MPI-02105.51 426.50 101.51 435.40 26.377426.50Ellipse Separation Pass - MPI-02 - MPI-02 - MPI-02125.83 701.50 119.74 700.00 20.652701.50Clearance Factor Pass - MPI-03 - MPI-03 - MPI-0345.43 26.50 43.86 36.20 28.93826.50Centre Distance Pass - MPI-03 - MPI-03 - MPI-0345.46 51.50 43.82 61.08 27.72551.50Ellipse Separation Pass - MPI-03 - MPI-03 - MPI-0353.95 576.50 48.79 583.21 10.447576.50Clearance Factor Pass - MPI-04 - MPI-04 - MPI-0412.96 524.82 8.18 534.59 2.714524.82Centre Distance Pass - MPI-04 - MPI-04 - MPI-0412.96 526.50 8.17 536.26 2.707526.50Ellipse Separation Pass - MPI-04 - MPI-04 - MPI-0413.19 551.50 8.20 561.11 2.645551.50Clearance Factor Pass - MPI-04 - MPI-04A - MPI-04A12.96 524.82 8.18 534.59 2.714524.82Centre Distance Pass - MPI-04 - MPI-04A - MPI-04A12.96 526.50 8.17 536.26 2.707526.50Ellipse Separation Pass - MPI-04 - MPI-04A - MPI-04A13.19 551.50 8.20 561.11 2.645551.50Clearance Factor Pass - MPI-04 - MPI-04AL1 - MPI-04AL112.96 524.82 8.18 534.59 2.714524.82Centre Distance Pass - MPI-04 - MPI-04AL1 - MPI-04AL112.96 526.50 8.17 536.26 2.707526.50Ellipse Separation Pass - MPI-04 - MPI-04AL1 - MPI-04AL113.19 551.50 8.20 561.11 2.645551.50Clearance Factor Pass - MPI-04 - MPI-04APB1 - MPI-04APB112.96 524.82 8.18 534.59 2.714524.82Centre Distance Pass - MPI-04 - MPI-04APB1 - MPI-04APB112.96 526.50 8.17 536.26 2.707526.50Ellipse Separation Pass - MPI-04 - MPI-04APB1 - MPI-04APB113.19 551.50 8.20 561.11 2.645551.50Clearance Factor Pass - MPI-04 - MPI-04PB1 - MPI-04PB112.96 524.82 8.18 534.59 2.714524.82Centre Distance Pass - MPI-04 - MPI-04PB1 - MPI-04PB112.96 526.50 8.17 536.26 2.707526.50Ellipse Separation Pass - 02 July, 2020-14:02COMPASSPage 2 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-38 - MPU I-38 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 26.50 to 6,419.61 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-38 - MPU I-38 - MPU I-38 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-04 - MPI-04PB1 - MPI-04PB113.19 551.50 8.20 561.11 2.645551.50Clearance Factor Pass - MPI-05 - MPI-05 - MPI-0575.07 501.50 71.32 505.22 20.024501.50Centre Distance Pass - MPI-05 - MPI-05 - MPI-0575.15 526.50 71.26 530.20 19.282526.50Ellipse Separation Pass - MPI-05 - MPI-05 - MPI-0584.56 726.50 79.44 728.44 16.500726.50Clearance Factor Pass - MPI-06 - MPI-06 - MPI-0614.59 419.13 10.66 422.95 3.710419.13Centre Distance Pass - MPI-06 - MPI-06 - MPI-0614.93 551.50 9.98 555.29 3.017551.50Ellipse Separation Pass - MPI-06 - MPI-06 - MPI-0616.05 626.50 10.52 630.28 2.901626.50Clearance Factor Pass - MPI-07 - MPI-07 - MPI-0731.47 805.59 25.65 807.78 5.406805.59Ellipse Separation Pass - MPI-07 - MPI-07 - MPI-0731.71 826.50 25.79 828.16 5.354826.50Clearance Factor Pass - MPI-08 - MPI-08 - MPI-0875.50 101.50 73.34 105.04 35.076101.50Centre Distance Pass - MPI-08 - MPI-08 - MPI-0879.27 903.79 73.06 898.33 12.756903.79Ellipse Separation Pass - MPI-08 - MPI-08 - MPI-08696.95 6,401.50 511.69 5,624.37 3.7626,401.50Clearance Factor Pass - MPI-09 - MPI-09 - MPI-09134.56 172.77 132.13 174.72 55.471172.77Centre Distance Pass - MPI-09 - MPI-09 - MPI-09135.14 276.50 131.63 276.93 38.478276.50Ellipse Separation Pass - MPI-09 - MPI-09 - MPI-09143.76 551.50 138.14 545.19 25.581551.50Clearance Factor Pass - MPI-10 - MPI-10 - MPI-10192.10 3,326.50 90.50 3,643.09 1.8913,326.50Clearance Factor Pass - MPI-10 - MPI-10 - MPI-10190.18 3,351.50 89.80 3,664.67 1.8953,351.50Ellipse Separation Pass - MPI-10 - MPI-10 - MPI-10187.62 3,428.61 91.81 3,732.06 1.9583,428.61Centre Distance Pass - MPI-11 - MPI-11 - MPI-1192.96 1,627.48 75.48 1,573.73 5.3191,627.48Centre Distance Pass - MPI-11 - MPI-11 - MPI-11120.41 2,826.50 49.30 2,795.69 1.6932,826.50Clearance Factor Pass - MPI-11 - MPI-11L1 - MPI-11L192.96 1,627.48 75.48 1,573.73 5.3191,627.48Centre Distance Pass - MPI-11 - MPI-11L1 - MPI-11L1120.41 2,826.50 49.30 2,795.69 1.6932,826.50Clearance Factor Pass - MPI-12 - MPI-12 - MPI-12128.06 872.43 122.39 861.45 22.597872.43Centre Distance Pass - MPI-12 - MPI-12 - MPI-12128.06 876.50 122.38 865.16 22.519876.50Ellipse Separation Pass - MPI-12 - MPI-12 - MPI-12741.27 3,876.50 617.25 3,826.72 5.9773,876.50Clearance Factor Pass - MPI-12 - MPI-12L1 - MPI-12L1128.06 872.43 122.39 861.45 22.597872.43Centre Distance Pass - MPI-12 - MPI-12L1 - MPI-12L1128.06 876.50 122.38 865.16 22.519876.50Ellipse Separation Pass - MPI-12 - MPI-12L1 - MPI-12L1741.27 3,876.50 617.25 3,826.72 5.9773,876.50Clearance Factor Pass - MPI-12 - MPI-12PB1 - MPI-12PB1128.06 872.43 122.39 861.45 22.597872.43Centre Distance Pass - MPI-12 - MPI-12PB1 - MPI-12PB1128.06 876.50122.38 865.16 22.519876.50Ellipse Separation Pass - MPI-12 - MPI-12PB1 - MPI-12PB1741.27 3,876.50 616.97 3,826.72 5.9633,876.50Clearance Factor Pass - 02 July, 2020-14:02COMPASSPage 3 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-38 - MPU I-38 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 26.50 to 6,419.61 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-38 - MPU I-38 - MPU I-38 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-13 - MPI-13 - MPI-13164.06 265.13 161.96 268.96 78.074265.13Centre Distance Pass - MPI-13 - MPI-13 - MPI-13164.25 326.50 161.80 329.18 67.112326.50Ellipse Separation Pass - MPI-13 - MPI-13 - MPI-13327.16 2,926.50 255.04 2,822.25 4.5362,926.50Clearance Factor Pass - MPI-14 - MPI-14 - MPI-14194.08 259.57 190.89 267.43 60.935259.57Centre Distance Pass - MPI-14 - MPI-14 - MPI-14194.30 301.50 190.68 307.30 53.660301.50Ellipse Separation Pass - MPI-14 - MPI-14 - MPI-14422.49 3,976.50 313.25 3,806.25 3.8683,976.50Clearance Factor Pass - MPI-14 - MPI-14L1 - MPI-14L1194.08 259.57 190.89 267.43 60.935259.57Centre Distance Pass - MPI-14 - MPI-14L1 - MPI-14L1194.30 301.50 190.68 307.30 53.660301.50Ellipse Separation Pass - MPI-14 - MPI-14L1 - MPI-14L1422.49 3,976.50 313.38 3,806.25 3.8723,976.50Clearance Factor Pass - MPI-14 - MPI-14L2 - MPI-14L2194.08 259.57 190.89 267.43 60.935259.57Centre Distance Pass - MPI-14 - MPI-14L2 - MPI-14L2194.30 301.50 190.68 307.30 53.660301.50Ellipse Separation Pass - MPI-14 - MPI-14L2 - MPI-14L2422.49 3,976.50 313.41 3,806.25 3.8733,976.50Clearance Factor Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB1194.08 259.57 190.89 267.43 60.935259.57Centre Distance Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB1194.30 301.50 190.68 307.30 53.660301.50Ellipse Separation Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB1422.49 3,976.50 313.12 3,806.25 3.8633,976.50Clearance Factor Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB2194.08 259.57 190.89 267.43 60.935259.57Centre Distance Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB2194.30 301.50 190.68 307.30 53.660301.50Ellipse Separation Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB2422.49 3,976.50 313.12 3,806.25 3.8633,976.50Clearance Factor Pass - MPI-14 - MPI-14PB1 - MPI-14PB1194.08 259.57 190.89 267.43 60.935259.57Centre Distance Pass - MPI-14 - MPI-14PB1 - MPI-14PB1194.30 301.50 190.68 307.30 53.660301.50Ellipse Separation Pass - MPI-14 - MPI-14PB1 - MPI-14PB1422.49 3,976.50 313.25 3,806.25 3.8683,976.50Clearance Factor Pass - MPI-14 - MPI-14PB2 - MPI-14PB2194.08 259.57 190.89 267.43 60.935259.57Centre Distance Pass - MPI-14 - MPI-14PB2 - MPI-14PB2194.30 301.50 190.68 307.30 53.660301.50Ellipse Separation Pass - MPI-14 - MPI-14PB2 - MPI-14PB2422.49 3,976.50 313.25 3,806.25 3.8683,976.50Clearance Factor Pass - MPI-15 - MPI-15 - MPI-15220.01 26.50 218.16 28.70 118.97626.50Centre Distance Pass - MPI-15 - MPI-15 - MPI-15220.31 326.50 217.26 327.91 72.101326.50Ellipse Separation Pass - MPI-15 - MPI-15 - MPI-15261.02 826.50 255.47 801.11 47.023826.50Clearance Factor Pass - MPI-15 - MPI-15L1 - MPI-15L1220.01 26.50 218.16 28.70 118.97626.50Centre Distance Pass - MPI-15 - MPI-15L1 - MPI-15L1220.31 326.50 217.26 327.91 72.101326.50Ellipse Separation Pass - MPI-15 - MPI-15L1 - MPI-15L1261.02 826.50255.47 801.11 47.024826.50Clearance Factor Pass - 02 July, 2020-14:02COMPASSPage 4 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-38 - MPU I-38 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 26.50 to 6,419.61 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-38 - MPU I-38 - MPU I-38 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-15 - MPI-15PB1 - MPI-15PB1220.01 26.50 218.16 28.70 118.97626.50Centre Distance Pass - MPI-15 - MPI-15PB1 - MPI-15PB1220.31 326.50 217.26 327.91 72.101326.50Ellipse Separation Pass - MPI-15 - MPI-15PB1 - MPI-15PB1261.02 826.50 255.47 801.11 47.023826.50Clearance Factor Pass - MPI-16 - MPI-16 - MPI-16249.09 349.48 245.48 358.04 68.957349.48Centre Distance Pass - MPI-16 - MPI-16 - MPI-16249.17 376.50 245.36 383.77 65.326376.50Ellipse Separation Pass - MPI-16 - MPI-16 - MPI-16939.87 3,101.50 888.75 3,164.14 18.3843,101.50Clearance Factor Pass - MPI-17 - MPI-17 - MPI-17221.48 5,270.11 106.82 6,496.48 1.9325,270.11Centre Distance Pass - MPI-17 - MPI-17 - MPI-17258.535,426.5053.766,584.091.2635,426.50Clearance FactorPass - MPI-17 - MPI-17L1 - MPI-17L1273.02 660.44 266.65 681.36 42.886660.44Centre Distance Pass - MPI-17 - MPI-17L1 - MPI-17L1394.82 5,551.50 257.00 6,596.34 2.8655,551.50Ellipse Separation Pass - MPI-17 - MPI-17L1 - MPI-17L1452.10 5,676.50 280.05 6,668.48 2.6285,676.50Clearance Factor Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1273.02 660.44 266.65 681.36 42.886660.44Centre Distance Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1394.82 5,551.50 256.87 6,596.34 2.8625,551.50Ellipse Separation Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1452.10 5,676.50 279.92 6,668.48 2.6265,676.50Clearance Factor Pass - MPI-17 - MPI-17L2 - MPI-17L2273.02 660.44 266.65 681.36 42.886660.44Ellipse Separation Pass - MPI-17 - MPI-17L2 - MPI-17L2460.80 5,526.50 286.83 6,601.45 2.6495,526.50Clearance Factor Pass - MPI-19 - MPI-19L1 - MPI-19L1340.27 26.50 338.43 34.30 184.53526.50Centre Distance Pass - MPI-19 - MPI-19L1 - MPI-19L1343.45 576.50 338.15 590.65 64.850576.50Ellipse Separation Pass - MPI-19 - MPI-19L1 - MPI-19L1400.75 1,026.50 392.20 1,035.06 46.8831,026.50Clearance Factor Pass - MPU I-36 - MPU I-36 - MPU I-36173.24 597.91 169.24 603.36 43.280597.91Centre Distance Pass - MPU I-36 - MPU I-36 - MPU I-36173.24 601.50 169.22 606.95 43.088601.50Ellipse Separation Pass - MPU I-36 - MPU I-36 - MPU I-36192.00 926.50 186.41 945.16 34.388926.50Clearance Factor Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB1173.24 597.91 169.24 603.36 43.280597.91Centre Distance Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB1173.24 601.50 169.22 606.95 43.088601.50Ellipse Separation Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB1192.00 926.50 186.41 945.16 34.388926.50Clearance Factor Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB2173.24 597.91 169.24 603.36 43.280597.91Centre Distance Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB2173.24 601.50 169.22 606.95 43.088601.50Ellipse Separation Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB2192.00 926.50 186.41 945.16 34.388926.50Clearance Factor Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21 wp08258.31 574.07 254.33 580.06 64.913574.07Centre Distance Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21 wp08258.31 576.50 254.32 582.48 64.716576.50Ellipse Separation Pass - 02 July, 2020-14:02COMPASSPage 5 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-38 - MPU I-38 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 26.50 to 6,419.61 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-38 - MPU I-38 - MPU I-38 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningPlan: MPU I-21i - MPU I-21 - MPU I-21 wp08490.19 1,701.50 480.68 1,814.03 51.5781,701.50Clearance Factor Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03137.47 879.41 131.97 904.94 24.998879.41Ellipse Separation Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03141.07 976.50 135.23 1,001.44 24.167976.50Clearance Factor Pass - Plan: MPU I-23 - MPU I-23 - MPU I-23 wp0390.41 525.01 86.70 526.27 24.367525.01Centre Distance Pass - Plan: MPU I-23 - MPU I-23 - MPU I-23 wp0390.47 551.50 86.63 552.99 23.552551.50Ellipse Separation Pass - Plan: MPU I-23 - MPU I-23 - MPU I-23 wp03903.27 6,419.61 822.61 5,778.03 11.1996,419.61Clearance Factor Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp0225.73 494.72 22.11 496.12 7.115494.72Centre Distance Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp0225.74 501.50 22.08 502.83 7.046501.50Ellipse Separation Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp02257.84 4,851.50 174.89 4,700.00 3.1084,851.50Clearance Factor Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03228.96 564.16 225.02 568.39 58.135564.16Centre Distance Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03229.01 576.50 225.01 580.09 57.262576.50Ellipse Separation Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03390.98 1,576.50 382.30 1,698.61 45.0411,576.50Clearance Factor Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp03190.08 1,076.50 182.72 1,130.42 25.8391,076.50Ellipse Separation Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp03319.46 2,076.50 304.00 2,232.75 20.6742,076.50Clearance Factor Pass - Plan: MPU I-30i - MPU I-30 - MPU I-30 wp0380.89 1,785.87 63.18 1,843.80 4.5671,785.87Centre Distance Pass - Plan: MPU I-30i - MPU I-30 - MPU I-30 wp0380.96 1,801.50 63.02 1,859.32 4.5121,801.50Ellipse Separation Pass - Plan: MPU I-30i - MPU I-30 - MPU I-30 wp0382.36 1,851.50 63.79 1,908.80 4.4361,851.50Clearance Factor Pass - Plan: MPU I-31 - MPU I-31 - MPU I-31 wp0330.15 321.59 27.40 322.30 10.941321.59Centre Distance Pass - Plan: MPU I-31 - MPU I-31 - MPU I-31 wp0330.29 376.50 27.28 377.10 10.066376.50Ellipse Separation Pass - Plan: MPU I-31 - MPU I-31 - MPU I-31 wp03197.00 4,826.50 108.15 4,735.98 2.2174,826.50Clearance Factor Pass - Rig: MPU I-37i - MPU I-37i - MPU I-37i55.38 595.90 51.34 598.87 13.718595.90Centre Distance Pass - Rig: MPU I-37i - MPU I-37i - MPU I-37i55.39 601.50 51.32 604.55 13.623601.50Ellipse Separation Pass - Rig: MPU I-37i - MPU I-37i - MPU I-37i611.00 3,701.50 561.15 3,686.43 12.2563,701.50Clearance Factor Pass - Rig: MPU I-37i - MPU I-37i - MPU I-37 wp0753.26 628.82 49.01 632.67 12.525628.82Ellipse Separation Pass - Rig: MPU I-37i - MPU I-37i - MPU I-37 wp0755.50 701.50 50.87 704.65 11.980701.50Clearance Factor Pass - M Pt J Pad02 July, 2020-14:02COMPASSPage 6 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-38 - MPU I-38 wp08Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool26.50 800.00 MPU I-38 wp08 3_Gyro-GC_Csg800.00 6,419.61 MPU I-38 wp08 3_MWD+IFR2+MS+Sag6,419.61 17,207.78 MPU I-38 wp08 3_MWD+IFR2+MS+SagEllipse error terms are correlated across survey tool tie-on points.Separation is the actual distance between ellipsoids.Calculated ellipses incorporate surface errors.Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).Distance Between centres is the straight line distance between wellbore centres.All station coordinates were calculated using the Minimum Curvature method.02 July, 2020-14:02COMPASSPage 7 of 9 0.001.002.003.004.00Separation Factor0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650Measured Depth (700 usft/in)No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU I-38 NAD 1927 (NADCON CONUS)Alaska Zone 0432.20+N/-S +E/-W Northing Easting Latittude Longitude0.000.006009451.89551509.8470° 26' 11.661 N149° 34' 48.112 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-38, True NorthVertical (TVD) Reference:MPU I-38 As-built RKB @ 60.30usftMeasured Depth Reference:MPU I-38 As-built RKB @ 60.30usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-06-17T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 800.00 MPU I-38 wp08 (MPU I-38) 3_Gyro-GC_Csg800.00 6419.61 MPU I-38 wp08 (MPU I-38) 3_MWD+IFR2+MS+Sag6419.61 17207.78 MPU I-38 wp08 (MPU I-38) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650Measured Depth (700 usft/in)MPI-02MPI-03MPI-04MPI-05MPI-06MPI-07MPI-08MPI-11MPI-11MPU I-23 wp03MPU I-24 wp02MPU I-30 wp03MPU I-30 wp03MPU I-31 wp03MPU I-31 wp03MPU I-37iNO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 17207.78Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-38Wellbore: MPU I-38Plan: MPU I-38 wp08Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3792.80 3732.50 6419.61 9-5/8 9 5/8" x 12 1/4"4012.80 3952.50 17207.78 4-1/2 4 1/2" x 8 1/2" 02 July, 2020Milne PointM Pt I PadPlan: MPU I-38MPU I-38MPU I-38 wp08Reference Design: M Pt I Pad - Plan: MPU I-38 - MPU I-38 - MPU I-38 wp08Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Well Coordinates: 6,009,451.89 N, 551,509.84 E (70° 26' 11.66" N, 149° 34' 48.11" W)Datum Height: MPU I-38 As-built RKB @ 60.30usftScan Range: 6,419.61 to 17,207.78 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.15 Build: 91EScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftNO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type:Scan Type:25.00 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-38 - MPU I-38 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 6,419.61 to 17,207.78 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-38 - MPU I-38 - MPU I-38 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningEX WSAK-25WSAK-25 - WSAK-25 - WSAK-25819.55 6,419.61 738.94 4,264.85 10.1676,419.61Clearance Factor Pass - M Pt I PadMPI-08 - MPI-08 - MPI-08689.71 6,419.61 506.45 5,632.10 3.7646,419.61Clearance Factor Pass - MPI-08 - MPI-08 - MPI-08636.20 6,594.61 482.37 5,702.36 4.1366,594.61Ellipse Separation Pass - MPI-08 - MPI-08 - MPI-08619.09 6,753.36 501.68 5,757.02 5.2736,753.36Centre Distance Pass - MPI-09 - MPI-09 - MPI-09680.54 8,169.61 449.53 6,854.90 2.9468,169.61Clearance Factor Pass - MPI-09 - MPI-09 - MPI-09604.02 8,394.61 416.82 6,993.24 3.2278,394.61Ellipse Separation Pass - MPI-09 - MPI-09 - MPI-09574.14 8,629.37 453.49 7,133.80 4.7598,629.37Centre Distance Pass - MPI-12 - MPI-12 - MPI-121,413.36 6,419.61 1,239.41 5,329.67 8.1256,419.61Clearance Factor Pass - MPI-12 - MPI-12L1 - MPI-12L11,413.36 6,419.61 1,239.41 5,329.67 8.1256,419.61Clearance Factor Pass - MPI-12 - MPI-12PB1 - MPI-12PB11,413.36 6,419.61 1,239.04 5,329.67 8.1086,419.61Clearance Factor Pass - MPI-14 - MPI-14 - MPI-141,212.54 6,419.61 1,031.80 6,524.52 6.7096,419.61Ellipse Separation Pass - MPI-14 - MPI-14 - MPI-141,294.64 6,644.61 1,100.70 6,711.99 6.6766,644.61Clearance Factor Pass - MPI-14 - MPI-14L1 - MPI-14L11,212.54 6,419.61 1,031.93 6,524.52 6.7146,419.61Ellipse Separation Pass - MPI-14 - MPI-14L1 - MPI-14L11,294.64 6,644.61 1,100.83 6,711.99 6.6806,644.61Clearance Factor Pass - MPI-14 - MPI-14L2 - MPI-14L21,212.54 6,419.61 1,031.95 6,524.52 6.7146,419.61Ellipse Separation Pass - MPI-14 - MPI-14L2 - MPI-14L21,294.64 6,644.61 1,100.85 6,711.99 6.6816,644.61Clearance Factor Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB11,212.54 6,419.61 1,031.67 6,524.52 6.7046,419.61Ellipse Separation Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB11,294.64 6,644.61 1,100.57 6,711.99 6.6716,644.61Clearance Factor Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB21,212.54 6,419.61 1,031.67 6,524.52 6.7046,419.61Ellipse Separation Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB21,294.64 6,644.61 1,100.57 6,711.99 6.6716,644.61Clearance Factor Pass - MPI-14 - MPI-14PB1 - MPI-14PB11,212.54 6,419.61 1,031.80 6,524.52 6.7096,419.61Ellipse Separation Pass - MPI-14 - MPI-14PB1 - MPI-14PB11,294.64 6,644.61 1,100.70 6,711.99 6.6766,644.61Clearance Factor Pass - MPI-14 - MPI-14PB2 - MPI-14PB21,212.54 6,419.61 1,031.80 6,524.52 6.7096,419.61Ellipse Separation Pass - MPI-14 - MPI-14PB2 - MPI-14PB21,294.64 6,644.61 1,100.70 6,711.99 6.6766,644.61Clearance Factor Pass - MPI-17 - MPI-17 - MPI-171,120.09 6,419.61 856.35 6,919.63 4.2476,419.61Clearance Factor Pass - MPI-17 - MPI-17L1 - MPI-17L11,079.90 6,419.61 859.19 6,875.68 4.8936,419.61Clearance Factor Pass - 02 July, 2020-14:03COMPASSPage 2 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-38 - MPU I-38 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 6,419.61 to 17,207.78 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-38 - MPU I-38 - MPU I-38 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-17 - MPI-17L1PB1 - MPI-17L1PB11,079.90 6,419.61 859.06 6,875.68 4.8906,419.61Clearance Factor Pass - MPI-17 - MPI-17L2 - MPI-17L21,208.08 6,419.61 985.18 6,861.96 5.4206,419.61Clearance Factor Pass - MPI-19 - MPI-19L1 - MPI-19L1145.51 13,046.76 64.94 11,783.72 1.80613,046.76Centre Distance Pass - MPI-19 - MPI-19L1 - MPI-19L1175.1513,144.6136.1211,775.191.26013,144.61Ellipse SeparationPass - MPI-19 - MPI-19L1 - MPI-19L1190.1313,169.6138.6011,772.871.25513,169.61Clearance FactorPass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp031,210.69 15,469.61 955.37 14,570.85 4.74215,469.61Clearance Factor Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp031,203.82 15,569.61 951.19 14,570.85 4.76515,569.61Ellipse Separation Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp031,203.36 15,602.59 951.93 14,570.85 4.78615,602.59Centre Distance Pass - Plan: MPU I-23 - MPU I-23 - MPU I-23 wp03578.18 14,944.61 352.45 13,959.78 2.56114,944.61Clearance Factor Pass - Plan: MPU I-23 - MPU I-23 - MPU I-23 wp03576.76 14,969.61 352.11 13,969.24 2.56714,969.61Ellipse Separation Pass - Plan: MPU I-23 - MPU I-23 - MPU I-23 wp03576.33 14,991.83 353.72 13,969.24 2.58914,991.83Centre Distance Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp02221.78 6,419.61 168.01 6,247.71 4.1256,419.61Centre Distance Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp02307.4415,544.61100.5015,402.751.48615,544.61Ellipse SeparationPass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp02311.7115,569.61100.8615,402.751.47815,569.61Clearance FactorPass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp031,052.34 17,044.61 757.28 16,125.49 3.56617,044.61Clearance Factor Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp031,049.45 17,094.61 756.02 16,125.49 3.57617,094.61Ellipse Separation Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp031,048.85 17,130.28 756.92 16,125.49 3.59317,130.28Centre Distance Pass - Plan: MPU I-30i - MPU I-30 - MPU I-30 wp03426.56 17,019.61 150.53 16,452.75 1.54517,019.61Clearance Factor Pass - Plan: MPU I-30i - MPU I-30 - MPU I-30 wp03425.12 17,056.31 151.88 16,463.76 1.55617,056.31Centre Distance Pass - Plan: MPU I-31 - MPU I-31 - MPU I-31 wp03228.38 12,686.65 84.73 13,013.36 1.59012,686.65Centre Distance Pass - Plan: MPU I-31 - MPU I-31 - MPU I-31 wp03257.3815,419.6136.9215,729.831.16715,419.61Clearance FactorPass - Rig: MPU I-37i - MPU I-37i - MPU I-37i1,192.42 6,419.61 1,158.96 5,021.33 35.6366,419.61Ellipse Separation Pass - Rig: MPU I-37i - MPU I-37i - MPU I-37i1,495.51 6,944.61 1,442.99 5,021.33 28.4736,944.61Clearance Factor Pass - Rig: MPU I-37i - MPU I-37i - MPU I-37 wp07803.68 17,169.61 510.87 15,963.78 2.74517,169.61Clearance Factor Pass - Rig: MPU I-37i - MPU I-37i - MPU I-37 wp07803.66 17,175.16 511.20 15,963.78 2.74817,175.16Centre Distance Pass - M Pt J PadMPJ-08 - MPJ-08 - MPJ-08787.26 15,994.61 442.58 8,593.00 2.28415,994.61Clearance Factor Pass - MPJ-08 - MPJ-08 - MPJ-08774.50 16,069.61 437.78 8,593.00 2.30016,069.61Ellipse Separation Pass - MPJ-08 - MPJ-08 - MPJ-08768.62 16,164.88 446.18 8,593.00 2.38416,164.88Centre Distance Pass - MPJ-08 - MPJ-08A - MPJ-08A220.43 12,910.28 163.10 6,988.58 3.84512,910.28Centre Distance Pass - 02 July, 2020-14:03COMPASSPage 3 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-38 - MPU I-38 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 6,419.61 to 17,207.78 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-38 - MPU I-38 - MPU I-38 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-08 - MPJ-08A - MPJ-08A257.83 13,044.61 133.75 6,976.97 2.07813,044.61Ellipse Separation Pass - MPJ-08 - MPJ-08A - MPJ-08A286.85 13,094.61 141.80 6,972.95 1.97813,094.61Clearance Factor Pass - MPJ-09 - MPJ-09 - MPJ-09869.86 12,594.61 662.41 5,842.44 4.19312,594.61Clearance Factor Pass - MPJ-09 - MPJ-09 - MPJ-09806.22 12,869.61 627.49 6,004.71 4.51112,869.61Ellipse Separation Pass - MPJ-09 - MPJ-09 - MPJ-09794.31 13,042.94 640.23 6,104.18 5.15513,042.94Centre Distance Pass - MPJ-09 - MPJ-09A - MPJ-09A146.19 12,747.99 88.41 6,478.49 2.53012,747.99Centre Distance Pass - MPJ-09 - MPJ-09A - MPJ-09A188.0012,869.6147.076,452.141.33412,869.61Clearance FactorPass - MPJ-15 - MPJ-15 - MPJ-15561.12 15,019.61 266.69 7,005.30 1.90615,019.61Clearance Factor Pass - MPJ-15 - MPJ-15 - MPJ-15536.02 15,119.61 260.60 7,073.86 1.94615,119.61Ellipse Separation Pass - MPJ-15 - MPJ-15 - MPJ-15515.27 15,285.57 280.72 7,145.00 2.19715,285.57Centre Distance Pass - MPJ-17 - MPJ-17 - MPJ-17395.82 10,862.75 322.48 5,569.32 5.39710,862.75Centre Distance Pass - MPJ-17 - MPJ-17 - MPJ-17435.53 11,044.61 299.37 5,577.38 3.19911,044.61Ellipse Separation Pass - MPJ-17 - MPJ-17 - MPJ-17516.32 11,194.61 333.06 5,584.42 2.81711,194.61Clearance Factor Pass - MPJ-18 - MPJ-18 - MPJ-18307.13 13,612.30 207.24 6,489.56 3.07513,612.30Centre Distance Pass - MPJ-18 - MPJ-18 - MPJ-18362.83 13,844.61 126.74 6,621.16 1.53713,844.61Ellipse Separation Pass - MPJ-18 - MPJ-18 - MPJ-18399.40 13,919.61 134.56 6,662.34 1.50813,919.61Clearance Factor Pass - MPJ-19 - MPJ-19 - MPJ-1997.6011,905.9428.465,894.001.41211,905.94Centre DistancePass - MPJ-19 - MPJ-19 - MPJ-19113.8811,969.61-4.255,918.500.96411,969.61Clearance FactorFAIL - MPJ-19 - MPJ-19 - MPJ-19127.2911,994.61-4.455,928.170.96611,994.61Ellipse SeparationFAIL - MPJ-19 - MPJ-19A - MPJ-19A665.69 11,394.61 535.19 5,587.15 5.10111,394.61Clearance Factor Pass - MPJ-19 - MPJ-19A - MPJ-19A605.67 11,644.61 500.92 5,660.70 5.78211,644.61Ellipse Separation Pass - MPJ-19 - MPJ-19A - MPJ-19A604.33 11,686.81 502.44 5,673.18 5.93111,686.81Centre Distance Pass - MPJ-20 - MPJ-20 - MPJ-201,284.89 9,219.61 1,107.02 5,522.95 7.2249,219.61Clearance Factor Pass - MPJ-20 - MPJ-20 - MPJ-20971.72 9,919.61 897.07 5,460.36 13.0179,919.61Ellipse Separation Pass - MPJ-20 - MPJ-20 - MPJ-20959.37 10,074.86 902.65 5,444.71 16.91510,074.86Centre Distance Pass - MPJ-20 - MPJ-20A - MPJ-20A1,284.89 9,219.61 1,104.63 5,522.95 7.1289,219.61Clearance Factor Pass - MPJ-20 - MPJ-20A - MPJ-20A971.72 9,919.61 896.50 5,460.36 12.9199,919.61Ellipse SeparationPass - MPJ-20 - MPJ-20A - MPJ-20A959.37 10,074.86 902.60 5,444.71 16.90010,074.86Centre Distance Pass - MPJ-21 - MPJ-21 - MPJ-21262.07 9,267.01 164.00 5,906.37 2.6729,267.01Centre Distance Pass - MPJ-21 - MPJ-21 - MPJ-21279.29 9,369.61 143.54 5,890.37 2.0579,369.61Ellipse Separation Pass - 02 July, 2020-14:03COMPASSPage 4 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-38 - MPU I-38 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 6,419.61 to 17,207.78 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-38 - MPU I-38 - MPU I-38 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-21 - MPJ-21 - MPJ-21310.90 9,444.61 151.26 5,878.09 1.9489,444.61Clearance Factor Pass - MPJ-22 - MPJ-22 - MPJ-22777.19 10,219.61 621.25 5,753.98 4.98410,219.61Clearance Factor Pass - MPJ-22 - MPJ-22 - MPJ-22640.42 10,569.61 542.38 5,760.00 6.53310,569.61Ellipse Separation Pass - MPJ-22 - MPJ-22 - MPJ-22632.24 10,671.64 546.61 5,760.00 7.38410,671.64Centre Distance Pass - MPJ-23 - MPJ-23 - MPJ-231,304.61 9,719.61 1,124.83 5,282.59 7.2579,719.61Clearance Factor Pass - MPJ-23 - MPJ-23 - MPJ-23966.06 10,469.61 890.11 5,185.70 12.71810,469.61Ellipse Separation Pass - MPJ-23 - MPJ-23 - MPJ-23955.25 10,614.98 894.85 5,168.59 15.81610,614.98Centre Distance Pass - MPJ-23 - MPJ-23A - MPJ-23A1,304.61 9,719.61 1,118.12 5,290.09 6.9969,719.61Clearance Factor Pass - MPJ-23 - MPJ-23A - MPJ-23A966.06 10,469.61 888.62 5,193.20 12.47410,469.61Ellipse Separation Pass - MPJ-23 - MPJ-23A - MPJ-23A955.25 10,614.98 894.69 5,176.09 15.77210,614.98Centre Distance Pass - MPJ-23 - MPJ-23L1 - MPJ-23L11,304.61 9,719.61 1,124.83 5,282.59 7.2579,719.61Clearance Factor Pass - MPJ-23 - MPJ-23L1 - MPJ-23L1966.06 10,469.61 890.11 5,185.70 12.71810,469.61Ellipse Separation Pass - MPJ-23 - MPJ-23L1 - MPJ-23L1955.25 10,614.98 894.85 5,168.59 15.81610,614.98Centre Distance Pass - MPJ-24 - MPJ-24A - MPJ-24A976.92 11,803.07 910.66 5,188.18 14.74411,803.07Centre Distance Pass - MPJ-24 - MPJ-24A - MPJ-24A994.82 11,994.61 901.80 5,227.84 10.69511,994.61Ellipse Separation Pass - MPJ-24 - MPJ-24A - MPJ-24A1,312.38 12,694.61 1,105.35 5,382.14 6.33912,694.61Clearance Factor Pass - MPJ-24 - MPJ-24L1 - MPJ-24L1976.92 11,803.07 910.68 5,191.89 14.74811,803.07Centre Distance Pass - MPJ-24 - MPJ-24L1 - MPJ-24L1994.82 11,994.61 902.58 5,231.55 10.78511,994.61Ellipse Separation Pass - MPJ-24 - MPJ-24L1 - MPJ-24L11,312.38 12,694.61 1,108.48 5,385.85 6.43712,694.61Clearance Factor Pass - MPJ-24 - MPJ-24L1PB1 - MPJ-24L1PB1976.92 11,803.07 910.68 5,191.89 14.74711,803.07Centre Distance Pass - MPJ-24 - MPJ-24L1PB1 - MPJ-24L1PB1994.82 11,994.61 902.52 5,231.55 10.77811,994.61Ellipse Separation Pass - MPJ-24 - MPJ-24L1PB1 - MPJ-24L1PB11,312.38 12,694.61 1,108.24 5,385.85 6.42912,694.61Clearance Factor Pass - MPJ-24 - MPJ-24L1PB2 - MPJ-24L1PB2976.92 11,803.07 910.68 5,191.89 14.74811,803.07Centre Distance Pass - MPJ-24 - MPJ-24L1PB2 - MPJ-24L1PB2994.82 11,994.61 902.58 5,231.55 10.78611,994.61Ellipse Separation Pass - MPJ-24 - MPJ-24L1PB2 - MPJ-24L1PB21,312.38 12,694.61 1,108.49 5,385.85 6.43712,694.61Clearance Factor Pass - MPJ-24 - MPU J-24 - MPJ-24976.92 11,803.07 910.68 5,191.89 14.74811,803.07Centre Distance Pass - MPJ-24 - MPU J-24 - MPJ-24994.82 11,994.61 902.58 5,231.55 10.78611,994.61Ellipse Separation Pass - MPJ-24 - MPU J-24 - MPJ-241,312.38 12,694.61 1,108.49 5,385.85 6.43712,694.61Clearance Factor Pass - MPJ-25 - MPJ-25 - MPJ-2523.0112,232.19-30.546,492.720.43012,232.19Centre DistanceFAIL - MPJ-25 - MPJ-25 - MPJ-2526.1012,244.61-96.526,494.290.21312,244.61Clearance FactorFAIL - MPJ-25 - MPJ-25 - MPJ-2543.6712,269.61-153.086,497.570.22212,269.61Ellipse SeparationFAIL - 02 July, 2020-14:03COMPASSPage 5 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-38 - MPU I-38 wp08Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 6,419.61 to 17,207.78 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-38 - MPU I-38 - MPU I-38 wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-26 - MPJ-26 - MPJ-26298.31 9,419.61 135.11 6,027.86 1.8289,419.61Clearance Factor Pass - MPJ-26 - MPJ-26 - MPJ-26213.02 9,638.00 166.79 5,959.81 4.6079,638.00Centre Distance Pass - MPJ-26 - MPJ-26 - MPJ-26260.14 9,794.61 123.19 5,909.72 1.8999,794.61Ellipse Separation Pass - MPJ-26 - MPJ-26L1 - MPJ-26L1222.49 9,600.11 177.51 5,938.68 4.9479,600.11Centre Distance Pass - MPJ-26 - MPJ-26L1 - MPJ-26L1255.91 9,744.61 141.94 5,869.04 2.2459,744.61Ellipse Separation Pass - MPJ-26 - MPJ-26L1 - MPJ-26L1308.91 9,844.61 159.55 5,825.03 2.0689,844.61Clearance Factor Pass - MPJ-26 - MPJ-26L2 - MPJ-26L2162.25 9,688.69 118.11 5,898.51 3.6769,688.69Centre Distance Pass - MPJ-26 - MPJ-26L2 - MPJ-26L2206.329,819.6168.495,867.911.4979,819.61Ellipse SeparationPass - MPJ-26 - MPJ-26L2 - MPJ-26L2222.189,844.6172.505,862.111.4849,844.61Clearance FactorPass - MPJ-26 - MPJ-26PB1 - MPJ-26PB1298.31 9,419.61 135.11 6,027.86 1.8289,419.61Clearance Factor Pass - MPJ-26 - MPJ-26PB1 - MPJ-26PB1213.02 9,638.00 166.79 5,959.81 4.6079,638.00Centre Distance Pass - MPJ-26 - MPJ-26PB1 - MPJ-26PB1260.14 9,794.61 123.19 5,909.72 1.8999,794.61Ellipse Separation Pass - MPJ-26 - MPJ-26PB2 - MPJ-26PB2298.31 9,419.61 135.11 6,027.86 1.8289,419.61Clearance Factor Pass - MPJ-26 - MPJ-26PB2 - MPJ-26PB2213.02 9,638.00 166.79 5,959.81 4.6079,638.00Centre Distance Pass - MPJ-26 - MPJ-26PB2 - MPJ-26PB2260.14 9,794.61 123.19 5,909.72 1.8999,794.61Ellipse Separation Pass - MPJ-27 - MPJ-27 - MPJ-271,056.48 10,974.08 1,000.09 5,468.11 18.73410,974.08Centre Distance Pass - MPJ-27 - MPJ-27 - MPJ-271,056.68 10,994.61 999.89 5,469.05 18.60710,994.61Ellipse Separation Pass - MPJ-27 - MPJ-27 - MPJ-271,368.38 11,844.61 1,243.30 5,510.10 10.94011,844.61Clearance Factor Pass - MPJ-28 - MPJ-28 - MPJ-281,408.31 8,969.61 1,293.35 5,630.65 12.2508,969.61Clearance Factor Pass - MPJ-28 - MPJ-28 - MPJ-281,068.00 9,844.61 1,016.90 5,543.02 20.9029,844.61Ellipse Separation Pass - MPJ-28 - MPJ-28 - MPJ-281,067.66 9,871.85 1,017.26 5,539.42 21.1859,871.85Centre Distance Pass - 02 July, 2020-14:03COMPASSPage 6 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-38 - MPU I-38 wp08Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool26.50 800.00 MPU I-38 wp08 3_Gyro-GC_Csg800.00 6,419.61 MPU I-38 wp08 3_MWD+IFR2+MS+Sag6,419.61 17,207.78 MPU I-38 wp08 3_MWD+IFR2+MS+SagEllipse error terms are correlated across survey tool tie-on points.Separation is the actual distance between ellipsoids.Calculated ellipses incorporate surface errors.Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).Distance Between centres is the straight line distance between wellbore centres.All station coordinates were calculated using the Minimum Curvature method.02 July, 2020-14:03COMPASSPage 7 of 9 0.001.002.003.004.00Separation Factor6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 13200 13800 14400 15000 15600 16200 16800 17400 18000Measured Depth (1200 usft/in)MPI-19L1MPJ-09AMPJ-18MPJ-19MPJ-21MPJ-25MPJ-26No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU I-38 NAD 1927 (NADCON CONUS)Alaska Zone 0432.20+N/-S +E/-W Northing Easting Latittude Longitude0.000.006009451.89551509.8470° 26' 11.661 N149° 34' 48.112 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-38, True NorthVertical (TVD) Reference:MPU I-38 As-built RKB @ 60.30usftMeasured Depth Reference:MPU I-38 As-built RKB @ 60.30usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-06-17T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 800.00 MPU I-38 wp08 (MPU I-38) 3_Gyro-GC_Csg800.00 6419.61 MPU I-38 wp08 (MPU I-38) 3_MWD+IFR2+MS+Sag6419.61 17207.78 MPU I-38 wp08 (MPU I-38) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 13200 13800 14400 15000 15600 16200 16800 17400 18000Measured Depth (1200 usft/in)NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 17207.78Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-38Wellbore: MPU I-38Plan: MPU I-38 wp08Ladder / S.F. Plots2 of 2CASING DETAILSTVD TVDSS MD Size Name3792.80 3732.50 6419.61 9-5/8 9 5/8" x 12 1/4"4012.80 3952.50 17207.78 4-1/2 4 1/2" x 8 1/2" Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. MPU I-38 220-057 X Milne Point Unit Schrader Bluff Oil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dts 7/9/2020JLC 7/10/2020