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Home My WebLink About225-034David Douglas Hilcorp Alaska, LLC Sr. 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. Received By: Date: Date: 09/08/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: MPU E-48 PTD: 225-024 API: 50-029-23817-00-00 FINAL LWD FORMATION EVALUATION + GEOSTEERING LOGS (08/05/2025 to 08/21/2025) x ROP, AGR, DGR, ABG, EWR-M5, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey x Final Geosteering and EOW Report/Plots SFTP Transfer – Main Folders: FINAL LWD Subfolders: FINAL Geosteering Subfolders: Please include current contact information if different from above. 225-034 T40857 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.09 07:51:13 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT E-48 JBR 10/10/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Good test Test Results TEST DATA Rig Rep:S. Tower / J. EsmailkaOperator:Hilcorp Alaska, LLC Operator Rep:S. Heim / I. Toomey Rig Owner/Rig No.:Doyon 14 PTD#:2250340 DATE:8/25/2025 Type Operation:DRILL Annular: 250/3000Type Test:BIWKLY Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopAGE250826105811 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4 MASP: 1443 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 14 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 4 1/2x7"P #2 Rams 1 Blind P #3 Rams 1 2 7/8x5"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"P Kill Line Valves 2 3 1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3075 Pressure After Closure P1750 200 PSI Attained P38 Full Pressure Attained P175 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@1970 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P16 #1 Rams P7 #2 Rams P7 #3 Rams P7 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1       RUSH By Grace Christianson at 1:39 pm, Aug 19, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.08.19 12:29:09 - 08'00' Taylor Wellman (2143) 325-489 *MIT-IA to 3650 psi - 30 minute charted. * Approved for reverse circulating jet pump compliant with CO 808. DSR-8/19/25A.Dewhurst 19AUG25 10-407 (original completion) MGR19AUT25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.20 08:55:57 -08'00'08/20/25 RBDMS JSB 082025 Page 1 Milne Point Unit E-48 SB Producer Drilling Procedure 20.0 Run Upper Completion (Proposed additions in red and removals in red) 18.1 RU to run 4-1/2”, 12.6#, L-80 TXP tubing. x Ensure wear bushing is pulled. x Ensure 4-1/2”, L-80, 12.6#, TXP x NC50 crossover is on rig floor and M/U to FOSV. x Ensure all tubing has been drifted in the pipe shed prior to running. x Be sure to count the total # of joints in the pipe shed before running. x Keep hole covered while RU casing tools. x Record OD’s, ID’s, lengths, SN’s of all components with vendor & model info. x Monitor displacement from wellbore while RIH. 18.2 PU, MU and RH with the following 4-1/2” JP completion (confirm tally with Operations Engineer): x Bullet Seals, Baker, TXP Box Up x Mule Shoe x Locater Sub, 8.25-in OD No-Go (bottom of locater spaced out 4-ft) x Crossover 4-1/2" BTC Box x 7" TXP Pin w/ handling pup x WLEG/Mule shoe x XX Joints, 4-1/2”, 12.6#, L-80, TXP x Handling Pup, 4-1/2” TXPM Box x 4-1/2” TXP Pin x Nipple, 3.813” XN profile (3.750” no-go), 4-1/2”, TXPM (RHC plug body installed,Set Below 70 degrees) x Handling Pup, 4-1/2”, TXP Box x 4-1/2”, TXP Pin x 1 joint, 4-1/2”, 12.6#, L-80, TXP x Crossover Pup, 4-1/2” TC-II Box x 4-1/2” TXP Pin x Permanent Packer, 9-5/8” x 4-1/2”, 12.6#, L-80, TC-II (NOTE: Set Below 70 degrees) x Crossover Pup, 4-1/2”, TXP Box x 4-1/2”, TC-II Pin x 1 joint, 4-1/2”, 12.6#, L-80, TXP x Crossover, 4-1/2”, EUE 8rd Box x 4-1/2”, TXP Pin x Gauge Carrier, 4-1/2”, 12.6#, L-80, EUE 8rd i.Standard clamping of every cross collar for the first 15 joints and then every other joint to surface. Confirm with OE prior to install. Final deviation survey and DLS will dictate. x Crossover, 4-1/2”, TXP Box x 4-1/2”, EUE 8rd Pin x 1 joint, 4-1/2”, 12.6#, L-80, TXP x Pup joint, 4-1/2”, 12.6#, L-80, TXP x Sliding Sleeve, 4-1/2”, 12.6#, L-80 TXP (NOTE: Set Below 70 degrees) Page 2 Milne Point Unit E-48 SB Producer Drilling Procedure x Pup joint, 4-1/2”, 12.6#, L-80, TXP x XXX joints, 4-1/2”, 12.6#, L-80, TXP 18.3 Circulating slowly, sting the seal assembly into SLZXP seal bore to confirm space out 18.4 PU and MU the 4-1/2” tubing hanger. Make final splice of the TEC wire and ensure any unused control line ports are dummied off. 18.5 Reverse circulate the well over to KW CI brine followed by diesel freeze protect to 2,500-ft MD (3421-ft TVD) 18.6 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 18.7 Land the tubing hanger and RILDS. Lay down the landing joint. 18.8 Install 4” HP BPV. ND BOP. Install the plug off tool. 18.9 NU the tubing head adapter and NU the tree. 18.10 PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 18.11 Pull the plug off tool and BPV. 18.12 Reverse circulate the well over to corrosion inhibited source water follow by diesel freeze protect to 2,500’ MD. 18.13 Drop the ball & rod. 18.14 Pressure up on the tubing to 3,500 psi to set the packer. PT the tubing to 3,500 psi for 30 minutes. 18.15 Bleed the tubing pressure to 2,000 psi and PT the IA to 3,650 psi for 30 minutes (charted). Bleed both the IA and tubing to 0 psi. 18.16 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. (NOTE: 10-403 COP for RCJP submitted on 08 Aug 2025)(see Sundry 325-469) _____________________________________________________________________________________ Edited By: JNL 8/19/2025 PROPOSED SCHEMATIC Milne Point Unit Well: MPU E-48 Last Completed: TBD PTD: 225-034 TD =19,567’(MD) / TD =3,956’(TVD) 4 20” Orig. KB Elev.: 54.31’ / GL Elev.: 20.7’ 9-5/8” 5 4 1 6 13-3/8” 3 2 3 5 See Screen/ Solid Liner Detail PBTD =19,567’(MD) / PBTD =3,956’(TVD) 24-1/2” 5-1/2” x 4-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5 / X52 / Weld N/A Surface 145’ N/A 13-3/8” Surface 68 / L-80 / CDC 12.415” Surface 3,477’ 0.1497 9-5/8” Intermediate 40 / L-80 / TXP-BTC 8.835” Surface 8,922’ 0.0758 5-1/2” Liner 250ђ Screens 17 / L-80 / JFE Bear 4.780” 8,772’ 9,832 0.0232 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920” 9,832’ 19,567’ 0.0149 TUBING DETAIL 4-1/2" Tubing 12.6# / L-80 / TXP 3.958” Surface 8,772’ 0.0151 OPEN HOLE / CEMENT DETAIL 24”xDriven 7 yds Concrete 16" Lead –1362 sx / Tail –313 sx 12-1/4” Lead –319 sx / Tail –386 sx 8-1/2” Uncemented Screen Liner WELL INCLINATION DETAIL KOP @ 325’ 90° Hole Angle = @ 9,100’ TREE & WELLHEAD Tree Cameron 3-1/8" 5M w/ 3-1/8” 5M Cameron Wing Wellhead FMC 13-5/8” 5K w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API: 50-029-23817-00-00 Last Completed: TBD JEWELRY DETAIL No. Top MD Item ID 1 7320 Sliding Sleeve 3.813” 2 7365 Gauge Carrier 3.865” 3 8764 Seal Assembly 3.725” 4 8772 SLZXP Liner Top Packer 6.180” 5 9832 5-1/2” x 4-1/2” XO 6 19567 Shoe 5-1/2” x 4-1/2”SCREENS LINER DETAIL Size Top (MD) Top (TVD) Btm (MD) Btm (TVD) 5-1/2” 8,832’ 9,832 4-1/2” 9,832’ 19,567’ 3,956’ 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 Sean McLaughlin Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Milne Point Unit Field, Schrader Bluff Oil Pool, MPU E-48 Hilcorp Alaska, LLC Permit to Drill Number: 225-034 Surface Location: 3809' FSL, 1890' FEL, Sec. 25, T13N, R10E, UM, AK Bottomhole Location: 2534' FNL, 2630' FWL, Sec. 28, T13N, R10E, UM, AK Dear Mr. McLaughlin: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. 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, Jessie L. Chmielowski Commissioner DATED this 23rd day of May 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.23 08:51:49 -08'00' By Grace Christianson at 9:33 am, Apr 04, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.04.03 16:45:10 - 08'00' Sean McLaughlin (4311) * BOPE test to 300 psi. Annular to 2500 psi. 50-029-23817-00-00225-034 DSR-4/7/25A.Dewhurst 22MAY25 -mgr * Casing test and FIT digital data to AOGCC immediately upon completion of FIT. * 10-403 required to POP well if put on jet pump production. MGR28APR2025 GL-125=~80' -mgr' *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.23 08:52:19 -08'00' 05/23/25 05/23/25 RBDMS JSB 052725 Milne Point Unit (MPU) E-48 Drilling Program Version 1 3/27/2025 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 21-1/4” 2M Diverter System ............................................................................................ 11 11.0 Drill 16” Hole Section ............................................................................................................. 13 12.0 Run 13-3/8” Surface Casing ................................................................................................... 16 13.0 Cement 13-3/8” Surface Casing .............................................................................................. 18 14.0 N/U BOP and Test................................................................................................................... 21 15.0 Drill 12-1/4” Hole Section ....................................................................................................... 22 16.0 Run 9-5/8” Intermediate Casing ............................................................................................. 25 17.0 Cement 9-5/8” Intermediate Casing ....................................................................................... 28 18.0 Drill 8-1/2” Hole Section ......................................................................................................... 31 19.0 Run 5-1/2” x 4-1/2” Production Liner (Lower Completion) .................................................. 36 20.0 Run Upper Completion........................................................................................................... 41 21.0 RDMO ..................................................................................................................................... 43 22.0 Doyon 14 Diverter Schematic ................................................................................................. 44 23.0 Doyon 14 BOP Schematic ....................................................................................................... 45 24.0 Wellhead Schematic ................................................................................................................ 46 25.0 Days vs Depth .......................................................................................................................... 47 26.0 Formation Tops & Information.............................................................................................. 48 27.0 Anticipated Drilling Hazards ................................................................................................. 50 28.0 Doyon 14 Layout ..................................................................................................................... 54 29.0 FIT Procedure ......................................................................................................................... 56 30.0 Doyon 14 Choke Manifold Schematic .................................................................................... 57 31.0 Casing Design .......................................................................................................................... 58 32.0 12-1/4” Hole Section MASP .................................................................................................... 59 33.0 8-1/2” Hole Section MASP ...................................................................................................... 60 34.0 Spider Plot (NAD 27) (Governmental Sections) ..................................................................... 61 35.0 Surface Plat (As-Built) (NAD 27) ........................................................................................... 62 Page 2 Milne Point Unit E-48 SB Producer Drilling Procedure 1.0 Well Summary Well MPU E-48 Pad Milne Point “E” Pad Planned Completion Type Jet Pump Target Reservoir(s) Schrader Bluff NB Sand Planned Well TD, MD / TVD 19,567’ MD / 3,956’ TVD PBTD, MD / TVD 19,567’ MD / 3,956’ TVD Surface Location (Governmental) 3809' FSL, 1890' FEL, Sec 25, T13N, R10E, UM, AK Surface Location (NAD 27) X = 569254.1 Y = 6016347.2 Top of Productive Horizon (Governmental)1246' FSL, 2381' FWL, Sec 26, T13N, R10E, UM, AK TPH Location (NAD 27) X = 562990.7 Y = 6013728.7 BHL (Governmental) 2534' FNL, 2630' FWL, Sec 28, T13N, R10E, UM, AK BHL (NAD 27) X = 552667.0 Y = 6015147.9 AFE Drilling Days 25 days AFE Completion Days 4 days Maximum Anticipated Pressure (Surface) 1443 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1739 psig Work String 5” 19.5# S-135 XT-50 KB Elevation above MSL: 33.7 ft + 20.1 ft = 53.8 ft GL Elevation above MSL: 20.1 ft BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams Page 3 Milne Point Unit E-48 SB Producer Drilling Procedure 2.0 Management of Change Information Page 4 Milne Point Unit E-48 SB 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 16” 13-3/8” 12.415” 12.259” 14.375” 68 L-80 CDC 5,020 2,260 1,556 12-1/4” 9-5/8” 8.835” 8.679” 10.625” 40 L-80 BTC 5,750 3,090 916 8-1/2” 5-1/2” 4.892” 4.767” 6.050” 17 L-80 JFE Bear 7,740 6,290 397 8-1/2” 4-1/2” 3.920”3.795” 4.714” 13.5 L-80 H625 9,020 8,540 307 Tubing 4-1/2” 3.960”3.795” 4.714” 12.6 L-80 TXP 8,430 7,500 288 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 & Intermediate 5” 4.276” 3.25” 6.625” 19.5 S-135 DS50 36,100 43,100 560 5” 4.276” 3.25” 6.625” 19.5 S-135 NC50 30,730 34,136 560 Production 4” 3.34” 2.5625” 4.875” 14 S-135 XT39 18,500 22,200 403 4” 3.34” 2.5625”4.875”14 S-135 HT38 12,200 17,700 403 All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 5 Milne Point Unit E-48 SB Producer Drilling Procedure 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on WellView. x Report covers operations from 6 am to 6 am 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 Capture any out-of-scope work as NPT. 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 sean.mclaughlin@hilcorp.com, Brad.Gorham@hilcorp.com and joseph.lastufka@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 Brad.Gorham@hilcorp.com and joseph.lastufka@hilcorp.com 5.6 Casing and Cement report x Send casing and cement report for each string of casing to sean.mclaughlin@hilcorp.com, Brad.Gorham@hilcorp.com and joseph.lastufka@hilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Sean Mclaughlin 907.777.8300 907.223.6784 sean.mclaughlin@hilcorp.com Drilling Engineer Brad Gorham 907.263.3917 907.250.3209 Brad.Gorham@hilcorp.com Operations Engineer Taylor Wellman 907.777.8449 907.947.9533 twellman@hilcorp.com Geologist Katie Cunha 907.564.4786 907.802.0078 Katharine.cunha@hilcorp.com Drilling Env. Coordinator Adrian Kersten 907.564.4820 907.891.0640 Adrian.kersten@hilcorp.com Drilling Tech Joe Lastufka 907.777.8400 907.227.8496 Joseph.Lastufka@hilcorp.com _____________________________________________________________________________________ Edited By: JNL 3/25/2025 PROPOSED SCHEMATIC Milne Point Unit Well: MPU E-48 Last Completed: TBD PTD: TBD TD =19,567’(MD) / TD =3,956’(TVD) 4 20” Orig. KB Elev.: 53.8’ / GL Elev.: 20.1’ 9-5/8” 5 5 7 1 8 10 13-3/8” 6 1 2 3 9 See Screen/ Solid Liner Detail PBTD =19,567’(MD) / PBTD = 3,956’(TVD) 4 3 2 4-1/2” 5-1/2” x 4-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5 / X56 / Weld N/A Surface 125’ N/A 13-3/8” Surface 68 / L-80 / CDC 12.415” Surface 3,565’ 0.1497 9-5/8” Intermediate 40 / L-80 / TXP-BTC 8.835” Surface 8,982’ 0.0758 5-1/2” Liner 250ђ Screens 17 / L-80 / JFE Bear 4.780” 8,832’ 9,832 0.0232 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.920” 9,832’ 19,567’ 0.0149 TUBING DETAIL 4-1/2" Tubing 12.6# / L-80 / TXP 3.958” Surface 8,832’ 0.0151 OPEN HOLE / CEMENT DETAIL 42” 17 yds 16" Lead – 1359 sx / Tail – 312 sx 12-1/4” Lead – 269 sx / Tail – 379 sx 8-1/2” Uncemented Screen Liner WELL INCLINATION DETAIL KOP @ 325’ 90° Hole Angle = @ 9,100’ TREE & WELLHEAD Tree Cameron 3-1/8" 5M w/ 3-1/8” 5M Cameron Wing Wellhead FMC 13-5/8” 5K w/ (2) 2-1/16” 5K outs GENERAL WELL INFO JEWELRY DETAIL No. Top MD Item ID 1 7320 Sliding Sleeve 3.813” 2 7365 Gauge Carrier 3.865” 3 7410 X Nipple 3.813” 4 7455 Packer 3.960” 5 7500 XN Nipple 3.725” 6 8832 SLZXP Liner Top Packer 6.180” 7 9832 5-1/2” x 4-1/2” XO 8 19567 Shoe 5-1/2” x 4-1/2”SCREENS LINER DETAIL Size Top (MD) Top (TVD) Btm (MD) Btm (TVD) 5-1/2” 8,832’ 9,832 4-1/2” 9,832’ 19,567’ 3,956’ Page 7 Milne Point Unit E-48 SB Producer Drilling Procedure 7.0 Drilling / Completion Summary MPU E-48 is a grassroots producer planned to be drilled in the Schrader Bluff NB sand. E-48 is part of a multi well development program targeting the Schrader Bluff sand. The directional plan is a horizontal well with 16” surface hole with 13-3/8” surface casing set in the SV1. A 12-1/4” intermediate hole with 9-5/8” intermediate casing set into the top of the Schrader Bluff sand. An 8- 1/2” lateral section will be drilled. A production liner will be run in the open hole section. Doyon 14 will be used to drill and complete the wellbore. Drilling operations are expected to commence approximately June 1st, 2025, pending rig schedule. Surface casing will be run to ~3,565’ MD / 2,558’ TVD and cemented to surface via a single-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 be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point “B” pad G&I facility. General sequence of operations: 1. MIRU Doyon 14 to well site 2. N/U & Test 21-1/4” Diverter and 16” diverter line 3. Drill 16” surface hole to TD of surface hole section. Run and cement 13-3/8” surface casing 4. N/D diverter, N/U & test 13-5/8” x 5M BOP. 5. Drill 12-1/4” hole to TD of intermediate hole section. Run and cement 9-5/8” surface casing 6. Drill 8-1/2” lateral to well TD. 7. Run 5-1/2” x 4-1/2” production liner. 8. Run upper completion. 9. N/D BOP, N/U Tree, RDMO. Reservoir Evaluation Plan: 1. Surface Hole: No mud logging. Remote geologist. LWD: GR + Res 2. Intermediate Hole: No mud logging. Remote geologist. LWD: GR + Res 3. Production Hole: No mud logging. Remote geologist. LWD: GR + ADR (For geo-steering) Page 8 Milne Point Unit E-48 SB Producer Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that all drilling and completion operations comply with all applicable AOGCC regulations. Operations stated in this PTD application may be altered based on sound engineering judgement as wellbore conditions require, but no AOGCC regulations will be varied from without prior approval from the AOGCC. 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 Review all conditions of approval of the PTD on the 10-401 form. Ensure that the conditions of approval are captured in shift handover notes until they are executed and complied with. x BOPs shall be tested at (2) week intervals during the drilling and completion of MPU E-48. 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. x Casing pressure test criteria in 20 AAC 25.030 (e) Casing and Cementing,“A casing pressure test must be performed if BOPE is to be installed on a casing. The casing must be tested to hold a minimum surface pressure equal to 50 percent of the casing internal yield pressure. The test pressure must show stabilizing pressure and may not decline more than 10 percent within 30 minutes. The results of this test and any subsequent tests of the casing must be recorded as required by 20 AAC 25.070(1)”. AOGCC Regulation Variance Requests: None Page 9 Milne Point Unit E-48 SB Producer Drilling Procedure Summary of BOP Equipment & Notifications Hole Section Equipment Test Pressure (psi) 16”x 21-1/4” 2M Diverter w/ 16” Diverter Line Function Test Only 12-1/4” & 8-1/2” x 13-5/8” x 5M Hydril “GK” Annular BOP x 13-5/8” x 5M Hydril MPL Double Gate o Blind ram in btm cavity x Mud cross w/ 3” x 5M side outlets x 13-5/8” x 5M Hydril MPL 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: NL Shaffer, 6 station, 3000 psi, 180 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air pump, and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: x Well control event (BOP’s 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 PTD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email:jim.regg@alaska.gov Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Email:melvin.rixse@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email:Victoria.loepp@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 E-48 SB Producer Drilling Procedure 9.0 R/U and Preparatory Work 9.1 E-48 will utilize a newly set 20” conductor on E-pad. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4” nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and R/U. 9.6 Rig mat footprint of rig. 9.7 MIRU Doyon 14. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on any hole section. 9.9 Mix spud mud for 16” surface hole section. Ensure mud temperatures are cool (<80qF). Page 11 Milne Point Unit E-48 SB Producer Drilling Procedure 10.0 N/U Diverter System 10.1 N/U 21-1/4” Hydril MSP 2M Diverter System (Diverter Schematic attached to program). x N/U 20” riser to BOP Deck x N/U 20”, 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 10.2 Notify AOGCC. Function test diverter. x Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. x Ensure that the annular closes in less than 45 seconds (API Standard 64 3rd edition March 2018 section 12.6.2 for packing element ID greater than 20”) 10.3 Ensure to set up a clearly marked “warning zone” is established on each side and ahead of the vent line tip. “Warning Zone” must include: x A prohibition on vehicle parking x A prohibition on ignition sources or running equipment x A prohibition on staged equipment or materials x Restriction of traffic to essential foot or vehicle traffic only. Page 12 Milne Point Unit E-48 SB Producer Drilling Procedure 10.4 Rig & Diverter Orientation: x May change on location Page 13 Milne Point Unit E-48 SB Producer Drilling Procedure 11.0 Drill 16” Hole Section 11.1 P/U 16” 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 Use GWD until 1,700’ or MWD surveys clean up, whichever is deeper. x Ensure TF offset is measured accurately and entered correctly into the MWD software. 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 16” hole section to section TD, in the SV1. 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. If a DLS < 6 deg / 100 is measured, immediately backream stand to knock down severity. 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. Mud rheology is the primary method of transporting cuttings. x Keep mud as cool as possible to keep from washing out permafrost. x Pump at 400-600 gpm, staying between 400 and 450 gpm through the permafrost. 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, increases 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 Drill ahead using GWD. Take MWD surveys every stand drilled and swap to MWD when MWD surveys clean up or after 1,700’ MD. Page 14 Milne Point Unit E-48 SB Producer Drilling Procedure x Be ready for the dead zone around base permafrost and the formation horizons at and just below base permafrost. Can be in 100% slide and still lose angle in the dead zone. However, BHA can deflect (ie. high DLS) when drilling through formation horizons. x Gas hydrates have been seen in previous E-pad wells. Be prepared for them. In MPU they have been encountered typically around 2100’-2400’ TVD (just below permafrost). Be prepared for hydrates: 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 AC: All wells have a clearance factor greater than 1.0 in the surface interval. 16” 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+ MW can be cut once ~500’ below hydrate zone x PVT System: 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, and mud loggers office. x Rheology: MI-Gel 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: PolyPac Supreme UL should be used for filtrate control. Background LCM (10 ppb total) 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 SKREENKLEEN 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 BUSAN 1060 MUST be made to control bacterial action. Page 15 Milne Point Unit E-48 SB Producer Drilling Procedure x Casing Running:Attempt to maintain mud rheology until casing is on bottom. Reduce system YP with DESCO and SAPP as last resort for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). System Type:8.8 – 9.2 ppg Pre-Hydrated MI-Gel/freshwater spud mud Properties: Section Density Viscosity Plastic Viscosity Yield Point API FL pH Temp Surface 8.8 – 9.8 75-300 20 - 40 25-45 <10 8.5 – 9.0 70 F System Formulation:Gel + FW spud mud Product- Surface hole Size Pkg ppb or (% liquids) M-I Gel 50 lb sx 25 Soda Ash 50 lb sx 0.25 PolyPac Supreme UL 50 lb sx 0.08 Caustic Soda 50 lb sx 0.1 SCREENCLEEN 55 gal dm 0.5 11.4 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps. 11.5 RIH to bottom, proceed to BROOH to HWDP x Pump at full drill rate (400-600 gpm) and maximize rotation. x Pull slowly, 5 – 10 ft / minute. 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. 11.6 TOOH and LD BHA Page 16 Milne Point Unit E-48 SB Producer Drilling Procedure 12.0 Run 13-3/8” Surface Casing 16.1 R/U Doyon 13-3/8” casing running equipment x Ensure 13-3/8” BTC x NC50 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 12-1/4” on the location prior to running. x Note that 68# drift is 12.259” 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. 16.2 P/U shoe joint, visually verify no debris inside joint. 16.3 Continue M/U & thread locking 80’ shoe track assembly consisting of: 13-3/8” Float Shoe 1 joint – 13-3/8” BTC, 2 Centralizers 10’ from each end w/ stop rings 1 joint –13-3/8” BTC, 1 Centralizer mid joint w/ stop ring 13-3/8” Float Collar – Non-Rotating x Ensure proper operation of float equipment while picking up. x Ensure to record S/N’s of all float equipment components. 16.4 Continue running 13-3/8” surface casing x Fill casing while running using fill up line on rig floor. x Use API Modified (or an alternative compatible) thread compound. Dope pin end only w/ paint brush. x Centralization: x 1 centralizer every joint to ~ 2500’ MD from shoe x 1 centralizer every other joint to ~200’ below surface 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. Page 17 Milne Point Unit E-48 SB Producer Drilling Procedure 16.5 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.6 Slow in and out of slips. 16.7 P/U landing joint/hanger assembly 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. 16.8 Lower casing and land hanger on landing ring to confirm depth. Confirm measurements. 16.9 Have emergency slips staged in cellar along with all necessary equipment for the contingency operation. 16.10 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 18 Milne Point Unit E-48 SB Producer Drilling Procedure 13.0 Cement 13-3/8” Surface Casing 17.1 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 amount 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. 17.2 Document efficiency of all possible displacement pumps prior to cement job. 17.3 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. 17.4 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. 17.5 Fill surface cement lines with water and pressure test. 17.6 Drop first bottom plug – HEC rep to witness. Pump spacer. 17.7 Drop second bottom plug – HEC rep to witness. Mix and pump lead cement per below calculations, confirm actual cement volumes with cementer after TD is reached. 17.8 Drop third bottom plug – HEC rep to witness. Mix and pump tail cement per below calculations, confirm actual cement volumes with cementer after TD is reached. x Cement volume based on annular volume + open hole excess (250% for lead above base permafrost and 40% for all cement below base permafrost). Job will consist of lead & tail, TOC brought to surface. Page 19 Milne Point Unit E-48 SB Producer Drilling Procedure Estimated Total Cement Volume: Cement Slurry Design: 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 – HEC rep to witness, and displace cement with spud mud out of mud pits. 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. 13.11 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. 13.12 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume before consulting with Drilling Engineer. 13.13 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. Weight Yield ft3 bbls ft3 bbls ft3 bbls ft3 bbls ppg ft3/ Sack Conductor 0' - 80' 80 0.182 0% 82 14.52 0 0.00 0 0 82 14.52 32 11.0 ppg ArcticCem 2.54 Conductor to Base Permafrost 80' - 1905' 1825 0.075 250% 768 136.71 1919 341.76 0 0 2686 478.47 1058 11.0 ppg ArcticCem 2.54 Base Permafrost to Top of Tail 1905' - 3065' 1160 0.075 40% 488 86.89 195 34.76 0 0 683 121.65 269 11.0 ppg ArcticCem 2.54 1337 238.12 2114 376.52 0 0 3451 614.64 1359 11.0 ppg ArcticCem 2.54 Weight Yield ft3 bbls ft3 bbls ft3 bbls ft3 bbls ppg ft3/ Sack Top of Tail to Shoe 3065' - 3565' 500 0.075 40% 210 37.45 84 14.98 0 0 294 52.43 254 15.8 ppg HalCem 1.16 Shoe Track 3485' - 3565' 80 0.150 0% 67 11.98 0 0.00 0 0 67 11.98 58 15.8 ppg HalCem 1.16 278 49.43 84 14.98 0 0 362 64.41 312 15.8 ppg HalCem 1.16 Sacks Blend Placement bbl/ft % Excess Volume XS Volume Additional bbls Total Volume Sacks Blend bbl/ft % Excess Volume XS Volume Additional bbls Total Volume Surface Tail Total Lead Volume = 14.52 + 478.47 + 121.65 bbls = 614.64 bbls => 1,359 sx of 11.0 ppg ArcticCem @ 2.54 ft³/sk Footage Footage Lead Placement Total Tail Volume = 52.43 + 11.98 bbls = 64.41 bbls => 312 sx of 15.8 ppg HalCem @ 1.16 ft³/sk Lead Slurry Tail Slurry System ArcticCem HalCem Density 11.0 lb/gal 15.8 lb/gal Yield 2.54 ft3/sk 1.16 ft3/sk Mix Water 12.22 gal/sk 4.98 gal/sk GL - 125' - mgr ~ 521.8 bbls = (3565' - 80') * ((12.415^2)/1029.4) - mgr 12.415"Cement displacement volume RKB-Float Collar for 13-3/8"68#, ID = Page 20 Milne Point Unit E-48 SB Producer Drilling Procedure 13.14 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. 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 x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x 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 Brad.Gorham@hilcorp.com, and joseph.lastufka@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 21 Milne Point Unit E-48 SB Producer Drilling Procedure 14.0 N/U BOP and Test 14.1 N/D the diverter T, knife gate, diverter line & N/U 13-5/8” x 13-5/8” 5M wellhead. 14.2 N/U 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 9-5/8” FBR’s in top cavity,blind ram in bottom cavity. x Single ram can be dressed with 2-7/8” x 5” VBRs x N/U 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 HCR outside of the manual valve 14.3 Install BOP test plug 14.4 Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. x Test 2-7/8” x 5” rams with the 2-7/8” and 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 14.5 R/D BOP test equipment 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix LSND fluid for intermediate hole. 14.8 Set wearbushing in wellhead. 14.9 If needed, rack back as much 5” DP in derrick as possible to be used while drilling the hole section. Page 22 Milne Point Unit E-48 SB Producer Drilling Procedure 15.0 Drill 12-1/4” Hole Section 15.1 P/U 12-1/4” RSS directional BHA. 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 Ensure MWD is R/U and operational. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. x Drill string will be 5” 19.5# S-135 XT50. x Run a non-ported float in the production hole section. 15.2 TIH w/ 12-1/4” BHA to float equipment. Note depth TOC tagged on AM report. 15.3 R/U 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 = 5020 / 2 = ~2510 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. 15.4 Drill out shoe track and 20’ of new formation. 15.5 CBU and condition mud for FIT. Pump at least one high vis sweep at maximum rate to surface to clean up debris. 15.6 Conduct FIT to 12.0 ppg EMW. Chart test. Ensure test is recorded on same chart as the casing test. Document incremental volume pumped (and subsequent pressure) and volume returned. x 12.0 ppg desired to cover shoe strength for expected ECD’s. A 10.2 ppg FIT is the minimum required to drill ahead x 10.2 ppg provides >25 bbls based on 9.2 ppg MW, 8.46 ppg PP (swabbed kick at 9.2 ppg BHP) 15.7 12-1/4” hole section mud program summary: x Density: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. x Solids Concentration: Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. Page 23 Milne Point Unit E-48 SB Producer Drilling Procedure x Rheology: Keep viscosifier additions reasonably low. Utilize sweeps (weighted, high vis, tandem) to inform hole cleaning efficiency. Ensure 6 rpm is > 12. (~hole diameter) for sufficient hole cleaning x Run the centrifuge as needed while drilling the intermediate 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:LSND drilling fluid Properties: Interval Density PV YP API FL Total Solids MBT Hardness Intermediate 8.9-9.8 5-20 - ALAP 15 - 30 <8 <10% <8 <200 System Formulation: Product- Intermediate Size Pkg ppb or (% liquids) Soda Ash 50 lb sx 0.17 PowerVIS 25 lb sx 1.5 –2.0 M-I Pac UL 50 lb sx 3.0 Hydrahib/Kla-Stop 55 gal dm 1.0 –1.5 KCl 50 lb sx 10.7 SCREENKLEEN 55 gal dm 0.25 M-I Wate 50 lb sx 56 (as needed for wt) Busan 1060 55 gal dm 2.1 15.8 Displace wellbore to 8.9 ppg LSND drilling fluid 15.9 Begin drilling 12-1/4” 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 P/U off bottom and restart on bottom staging technique. If stick slip continues, consider adding 0.5% lubes 15.14 Drill 12-1/4” hole section to section TD per Geologist and Drilling Engineer. x Flow Rate: 850-1000 gpm, Target higher end of range unless limited by pump pressure or ECD concerns. Page 24 Milne Point Unit E-48 SB Producer Drilling Procedure x RPM: 120+ x Efforts should be made to minimize doglegs in the intermediate hole. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. Mud rheology is the primary method of transporting cuttings. 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 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 sands for any extended period of time. x Target ROP is as fast as we can clean the hole without having to backream connections. Hole cleaning is key. Model suggests good hole cleaning at 1000 gpm and 150 fph. x A/C: All wells have a clearance factor greater than 1.0 in this interval. 15.15 At TD, CBU (minimum 2X, more if needed) at max rate and rotation (120+ rpm). Pump tandem sweeps if needed x Rack back a stand at each bottoms up and reciprocate a full stand in between (while circulating the BU). Keep the pipe moving while pumping. x Monitor BU for increase in cuttings. Cuttings in laterals will come back in waves and not a consistent stream so circulate more if necessary 15.16 BROOH with the drilling assembly to the 13-3/8” casing shoe. x Circulate at full drill rate unless losses are seen. x Rotate at maximum rpm that can be sustained. x Target pulling speed of 5 – 10 min/std (slip to slip time, not including connections), but adjust as hole conditions dictate. Slow pulling speed when backreaming through coal depths seen when drilling. 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. x Monitor returns during the backream for increase in cuttings. Cuttings in laterals will come back in waves and not a consistent stream so circulate more if necessary. 15.17 CBU minimum two times at 13-3/8” shoe and clean casing with high vis sweeps. 15.18 Monitor well for flow. 15.19 POOH and LD BHA Page 25 Milne Point Unit E-48 SB Producer Drilling Procedure 16.0 Run 9-5/8” Intermediate Casing 16.1 R/U Doyon 9-5/8” casing running equipment x Ensure 9-5/8” TXP x NC50 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 at least 8-1/2” on the location prior to running. x Note that 40# API drift is 8.679” 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. 16.2 P/U shoe joint, visually verify no debris inside joint. 16.3 Continue M/U & thread locking 80’ 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 1 joint –9-5/8” TXP, 1 Centralizer mid joint with stop ring 16.4 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 (locked mid-joint) every joint to ~ 3,000’ MD from 9-5/8” shoe x 1 centralizer (locked mid-joint) every 2 joints to ~100’ MD below 13-3/8” shoe x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Fill casing while running using fill up line on rig floor. 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 the cement job. 9-5/8” 40# L-80 BTC Make-Up Torques - Make up to Mark 10 jts Take Average: Casing OD Optimum 9-5/8” To Mark Page 26 Milne Point Unit E-48 SB Producer Drilling Procedure Page 27 Milne Point Unit E-48 SB Producer Drilling Procedure 16.5 CBU at 13-3/8” shoe. 16.6 Continue to RIH with 9-5/8” intermediate casing to TD. Break circulation every 10 joints and wash down. Take special care when staging pumps up and down to avoid surging and breaking down the formation. 16.7 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.8 Slow in and out of slips. 16.9 P/U landing joint/hanger assembly and M/U to casing string. 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. 16.10 Lower casing and land hanger to confirm depth. Confirm measurements. 16.11 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 28 Milne Point Unit E-48 SB Producer Drilling Procedure 17.0 Cement 9-5/8” Intermediate Casing 17.1 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 amount 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. 17.2 Document efficiency of all possible displacement pumps prior to cement job. 17.3 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. 17.4 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. 17.5 Fill surface cement lines with water and pressure test. 17.6 Pump spacer. 17.7 Drop first bottom plug – HEC rep to witness. Mix and pump lead cement per below calculations, confirm actual cement volumes with cementer after TD is reached. 17.8 Drop second bottom plug – HEC rep to witness. Mix and pump tail cement per below calculations, confirm actual cement volumes with cementer after TD is reached. x Cement volume is based on annular volume + open hole excess (30%). Job will consist of tail, TOC brought to 500’ MD above the Ugnu LA3.Note: If the Ugnu LA3 is wet, TOC may be pushed deeper. If Hilcorp wants to deepen the TOC, Hilcorp will submit the LWD data to the AOGCC staff for approval. If the TOC will remain 500’ MD above the LA3, no additional approval from the AOGCC will be sought Page 29 Milne Point Unit E-48 SB Producer Drilling Procedure Estimated Total Cement Volume: Cement Slurry Design: 17.9 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, land hanger on profile, and continue with the cement job. 17.10 After pumping cement, drop top plug and displace cement with spud mud out of mud pits. x Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 17.11 Ensure rig pump is used to displace cement. 17.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. 17.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume before consulting with Drilling Engineer. 17.14 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. 17.15 While unlikely, be prepared for cement returns to surface. 17.16 Back off and LD landing joint. Install packoff and test per wellhead tech. Weight Yield ft3 bbls ft3 bbls ft3 bbls ft3 bbls ppg ft3/ Sack Lead 500' ј Ugnu LA3 to Top Tail 6432' - 7982' 1550 0.056 30% 485 86.46 146 25.94 0 0 631 112.40 269 12.0 ppg EconoCem 2.35 485 86.46 146 25.94 0 0 631 112.40 269 12.0 ppg EconoCem 2.35 Weight Yield ft3 bbls ft3 bbls ft3 bbls ft3 bbls ppg ft3/ Sack Top Tail (1000' Tail Coverage) to Shoe 7982' - 8982' 1000 0.056 30% 313 55.78 94 16.73 0 0 407 72.52 351 15.8 ppg HalCem 1.16 Shoe Track 8902' - 8982' 80 0.073 0% 33 5.86 0 0.00 0 0 33 5.86 28 15.8 ppg HalCem 1.16 346 61.64 94 16.73 0 0 440 78.37 379 15.8 ppg HalCem 1.16 Placement bbl/ft % Excess Volume XS Volume Additional bbls Total Volume Footage XS Volume Additional bbls Total Volume Intermediate 1 Sacks Blend Tail Placement bbl/ft % Excess Footage BlendSacks Total Lead Volume = 112.40 bbls => 269 sx of 12.0 ppg EconoCem @ 2.35 ft³/sk Total Tail Volume = 72.52 + 5.86 bbls = 78.37 bbls => 379 sx of 15.8 ppg HalCem @ 1.16 ft³/sk Volume Lead Slurry Tail Slurry System EconoCem HalCem Density 12.0 lb/gal 15.8 lb/gal Yield 2.35 ft3/sk 1.16 ft3/sk Mix Water 13.92 gal/sk 4.98 gal/sk Cement displacement volume: RKB-Float Collar for 9.625" 40#, ID = 8.835" 675 bbls = (8982' - 80') * ((8.835 ^2) /1029.4) - mgr Page 30 Milne Point Unit E-48 SB Producer Drilling Procedure 17.17 Freeze protect 13-3/8” x 9-5/8” casing annulus to 100’ MD below the permafrost with dead crude or diesel after cement tests indicate cement has reached 500 psi compressive strength. x Establish breakdown pressure and inject 5 bbls past breakdown to confirm annulus is clear x Ensure total injection volume injected down the annulus (including mud used to keep annulus open) does not exceed 110% of the 13-3/8” x 9-5/8” annular volume. 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 x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x 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 Brad.Gorham@hilcorp.com, and joseph.lastufka@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 31 Milne Point Unit E-48 SB Producer Drilling Procedure 18.0 Drill 8-1/2” Hole Section 18.1 P/U 8-1/2” RSS directional BHA. 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 Ensure MWD is R/U and operational. x Ensure GWD is included in the BHA 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 XT50. x Run a non-ported float in the production hole section. Schrader Bluff Bit Jetting Guidelines Formation Jetting TFA NB 6 x 14 0.902 OA 6 x 13 0.778 OB 6 x 13 0.778 18.2 TIH w/ 8-1/2” BHA to TOC above the float collar. Note depth TOC tagged on morning report. 18.3 R/U and test casing to 2500 psi / 30 min. Ensure to record volume / pressure (every ¼ bbl) and plot on FIT graph. 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. 18.4 Drill out shoe track and 20’ of new formation. 18.5 CBU and condition mud for FIT. Pump at least one high vis sweep at maximum rate to surface to clean up debris. 18.6 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. x 12.0 ppg desired to cover shoe strength for expected ECD’s. A 9.5 ppg FIT is the minimum required to drill ahead x 9.5 ppg provides >25 bbls based on 9.2ppg MW, 8.46ppg PP (swabbed kick at 9.2ppg BHP) Page 32 Milne Point Unit E-48 SB Producer Drilling Procedure 18.7 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 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:8.8 – 9.8 ppg FloPro 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 Page 33 Milne Point Unit E-48 SB Producer Drilling Procedure System Formulation: Product- production Size Pkg ppb or (% liquids) Busan 1060 55 gal dm 0.095 FLOTROL 55 lb sx 6 CONQOR 404 WH (8.5 gal/100 bbls)55 gal dm 0.2 FLO-VIS PLUS 25 lb sx 0.7 KCl 50 lb sx 10.7 SMB 50 lb sx 0.45 LOTORQ 55 gal dm 1.0 SAFE-CARB 10 (verify)50 lb sx 10 SAFE-CARB 20 (verify)50 lb sx 10 Soda Ash 50 lb sx 0.5 18.8 TIH with 8-1/2” directional assembly to bottom 18.9 Install MPD RCD 18.10 Displace wellbore to 8.9 ppg FloPro drilling fluid 18.11 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 P/U off bottom and restart on bottom staging technique. If stick slip continues, consider adding 0.5% lubes 18.15 Drill 8-1/2” hole section to section TD per Geologist and Drilling Engineer. x Flow Rate: 350-550 gpm. Target minimum of 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. Page 34 Milne Point Unit E-48 SB Producer Drilling Procedure x Limit maximum instantaneous ROP to < 200 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 (under 200 fph) without having to backream connections x Watch for higher than expected pressure. MPD will be utilized to monitor pressure build up on connections x Schrader Bluff OA Concretions: 4-6% Historically x 8-1/2” Lateral AC: x MPE-28 – is currently shut-in with two CIBP’s installed in the 7-5/8” casing at 1,500’ and 7,609’ MD. The well will remain shut-in while drilling the E-48 well. x MPG-17 – An OA and OB injector that is currently offline. The well will be shut-in while drilling the E-48 well. 18.16 Reference:Halliburton has a procedure for Schrader OH sidetracks based on lessons learned and best practices. Ensure the DD is referencing their procedure. x Patience is key! Getting kicked off too quickly might have been the cause of failed liner runs on past wells. 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 sidetrack low and right in a fast drilling interval where the wellbore is headed up. x Orient TF to low side and dig a trough with high flowrates for the first 30 feet, working string back and forth. Trough for approximately 30 minutes. x Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 18.17 At TD, CBU (minimum 3X, more if needed) at 200 ft/min AV (385+ gpm) and rotation (120+ rpm). Pump tandem sweeps if needed x Rack back a stand at each bottoms up and reciprocate a full stand in between (while circulating the BU). Keep the pipe moving while pumping. x Monitor BU for increase in cuttings. Cuttings in laterals will come back in waves and not a consistent stream so circulate more if necessary x If seepage losses are seen while drilling, consider reducing MW at TD to 9.0 ppg minimum 18.18 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. x 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. Page 35 Milne Point Unit E-48 SB Producer Drilling Procedure 18.19 Displace 1.5 OH + Liner volume with viscosified brine. x Proposed brine blend (aiming for an 8 on the 6 RPM reading) - KCl: 7.1bbp for 2% NaCl: 60.9 ppg for 9.4 ppg Lotorq: 1.5% Lube 776: 1.5% Soda Ash: as needed for 9.5pH Busan 1060: 0.42 ppb Flo-Vis Plus: 1.25 ppb x Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if further discussion needed prior to BROOH. 18.20 BROOH with the drilling assembly to the 9-5/8” casing shoe. Note: PST test is NOT required. x Circulate at full drill rate unless losses are seen (350 gpm minimum if on losses) x Rotate at maximum rpm that can be sustained. x Target pulling speed of 5 – 10 min/std (slip to slip time, not including connections), but adjust as hole conditions dictate. x When pulling across any OHST depths, turn pumps off and rotary off to minimize disturbance. Trip back in hole past OHST depth to ensure liner will stay in correct hole section, check with ABI compared to as drilled surveys 18.21 CBU minimum two times at 9-5/8” shoe and clean casing with high vis sweeps. 18.22 Monitor well for flow. Increase mud weight if necessary x Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to determine if well is breathing, treat all flow as an influx until proven otherwise x If necessary, increase MW at shoe for any higher than expected pressure seen 18.23 Pull RCD Bearing and install trip nipple. 18.24 POOH and LD BHA. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball drops. Page 36 Milne Point Unit E-48 SB Producer Drilling Procedure 19.0 Run 5-1/2” x 4-1/2” Production Liner (Lower Completion) 19.1 Well control preparedness: In the event of an influx of formation fluids while running the production liner with screens, the following well control response procedure will be followed: x With 4-1/2” joint across BOP: P/U & M/U 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 M/U and available prior to running the first joint of 4-1/2” liner. 19.2 Confirm VBR’s have been tested to cover 2-7/8” and 5” pipe sizes to 250 psi low/3000 psi high. 19.3 R/U 4-1/2” liner running equipment. x Ensure 4-1/2” Hydril 625 x NC50 crossovers are on rig floor and M/U to FOSV. x Ensure the liner 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 R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 19.4 Run 4-1/2” production liner. x Production liner will be a combination of screened and solid joints. Confirm with geologist and OE for any solid joint placement. x Use API Modified or “Best O Life 2000 AG” equivalent thread compound. Dope pin end only w/ paint brush. Wipe off excess. Thread compound can plug the screens x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Use lift nubbins and stabbing guides for the liner run. x Centralization: x 1 centralizer every joint to ~ 100’ MD from intermediate shoe x Obtain up and down weights of the liner before picking up liner hanger assembly. Record rotating torque at 10 and 20 rpm 19.5 R/U 5-1/2” liner running equipment. x Ensure 5-1/2” JFE Bear x NC50 crossovers are on rig floor and M/U to FOSV. x Ensure the liner 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 R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. Page 37 Milne Point Unit E-48 SB Producer Drilling Procedure 4-1/2” 13.5# L-80 H625 Casing OD Minimum Optimum Maximum Operating Torque 4.5” 8,000 ft-lbs 9,600 ft-lbs 12,800 ft-lbs Page 38 Milne Point Unit E-48 SB Producer Drilling Procedure 5-1/2” 17# L-80 JFE Bear Casing OD Minimum Make-up Torque Maximum Make-Up Torque Maximum Operating Torque 5.5” 6,660 ft-lbs 8,140 ft-lbs 11,100 ft-lbs Page 39 Milne Point Unit E-48 SB Producer Drilling Procedure 19.5 Ensure that the liner top packer is set ~150’ MD above the 9-5/8” shoe. x AOGCC regulations require a minimum 100’ overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Ensure hanger/packer will not be set in a 9-5/8” connection. 19.6 Before picking up Baker SLZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 19.7 M/U Baker SLZXP liner top packer to 4-1/2” liner. 19.8 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. 19.9 RIH with liner 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” DP/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. 19.10 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. 19.11 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, & 20 RPM. 19.12 If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 19.13 TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 19.14 Rig up to pump down the work string with the rig pumps. 19.15 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 19.16 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. 19.17 Shut down pumps. Drop setting ball down the workstring and pump slowly (1-2 BPM). Slow pump before the ball seats. Do not allow ball to slam into ball seat. Page 40 Milne Point Unit E-48 SB Producer Drilling Procedure 19.18 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. 19.19 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. 19.20 PU to neutral weight, close BOP and test annulus to 1,500 psi for 10 minutes charted. 19.21 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. 19.22 PU pulling running tool free of the packer and displace at max rate to wash the liner top. Pump sweeps as needed. 19.23 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. Page 41 Milne Point Unit E-48 SB Producer Drilling Procedure 20.0 Run Upper Completion 18.1 RU to run 4-1/2”, 12.6#, L-80 TXP tubing. x Ensure wear bushing is pulled. x Ensure 4-1/2”, L-80, 12.6#, TXP x NC50 crossover is on rig floor and M/U to FOSV. x Ensure all tubing has been drifted in the pipe shed prior to running. x Be sure to count the total # of joints in the pipe shed before running. x Keep hole covered while RU casing tools. x Record OD’s, ID’s, lengths, SN’s of all components with vendor & model info. x Monitor displacement from wellbore while RIH. 18.2 PU, MU and RH with the following 4-1/2” JP completion (confirm tally with Operations Engineer): x WLEG/Mule shoe x Joints, 4-1/2”, 12.6#, L-80, TXP x Handling Pup, 4-1/2” TXPM Box x 4-1/2” TXP Pin x Nipple, 3.813” XN profile (3.750” no-go), 4-1/2”, TXPM (RHC plug body installed,Set Below 70 degrees) x Handling Pup, 4-1/2”, TXP Box x 4-1/2”, TXP Pin x 1 joint, 4-1/2”, 12.6#, L-80, TXP x Crossover Pup, 4-1/2” TC-II Box x 4-1/2” TXP Pin x Permanent Packer, 9-5/8” x 4-1/2”, 12.6#, L-80, TC-II (NOTE: Set Below 70 degrees) x Crossover Pup, 4-1/2”, TXP Box x 4-1/2”, TC-II Pin x 1 joint, 4-1/2”, 12.6#, L-80, TXP x Crossover, 4-1/2”, EUE 8rd Box x 4-1/2”, TXP Pin x Gauge Carrier, 4-1/2”, 12.6#, L-80, EUE 8rd i.Standard clamping of every cross collar for the first 15 joints and then every other joint to surface. Confirm with OE prior to install. Final deviation survey and DLS will dictate. x Crossover, 4-1/2”, TXP Box x 4-1/2”, EUE 8rd Pin x 1 joint, 4-1/2”, 12.6#, L-80, TXP x Pup joint, 4-1/2”, 12.6#, L-80, TXP x Sliding Sleeve, 4-1/2”, 12.6#, L-80 TXP x Pup joint, 4-1/2”, 12.6#, L-80, TXP x XXX joints, 4-1/2”, 12.6#, L-80, TXP 18.3 PU and MU the 4-1/2” tubing hanger. Make final splice of the TEC wire and ensure any unused control line ports are dummied off. Page 42 Milne Point Unit E-48 SB Producer Drilling Procedure 18.4 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 18.5 Land the tubing hanger and RILDS. Lay down the landing joint. 18.6 Install 4” HP BPV. ND BOP. Install the plug off tool. 18.7 NU the tubing head adapter and NU the tree. 18.8 PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 18.9 Pull the plug off tool and BPV. 18.10 Reverse circulate the well over to corrosion inhibited source water follow by diesel freeze protect to 2,500’ MD. 18.11 Drop the ball & rod. 18.12 Pressure up on the tubing to 3,500 psi to set the packer. PT the tubing to 3,500 psi for 30 minutes. 18.13 Bleed the tubing pressure to 2,000 psi and PT the IA to 3,650 psi for 30 minutes (charted). Bleed both the IA and tubing to 0 psi. 18.14 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. Page 43 Milne Point Unit E-48 SB Producer Drilling Procedure 21.0 RDMO 21.1 RDMO Doyon 14 Page 44 Milne Point Unit E-48 SB Producer Drilling Procedure 22.0 Doyon 14 Diverter Schematic Page 45 Milne Point Unit E-48 SB Producer Drilling Procedure 23.0 Doyon 14 BOP Schematic Page 46 Milne Point Unit E-48 SB Producer Drilling Procedure 24.0 Wellhead Schematic 4-1/2 Page 47 Milne Point Unit E-48 SB Producer Drilling Procedure 25.0 Days vs Depth Page 48 Milne Point Unit E-48 SB Producer Drilling Procedure 26.0 Formation Tops & Information TOP NAME TVD TVDSS MD Formation Pressure EMW (FT) (FT) (FT) (psi) (ppg) SV6 1,088 1,035 1,100 479 8.46 Base Permafrost 1,781 1,728 1,905 783 8.46 SV1 2,394 2,341 3,105 1053 8.46 UG_LA3 3,755 3,701 6,920 1652 8.46 UG_MB 3,994 3,940 7,603 1757 8.46 SB_NA 4,214 4,160 8,588 1854 8.46 SB_NB 4,240 4,187 8,937 1865 8.46 Page 49 Milne Point Unit E-48 SB Producer Drilling Procedure E-Pad Data Sheet Formation Descriptions Page 50 Milne Point Unit E-48 SB Producer Drilling Procedure 27.0 Anticipated Drilling Hazards 16” 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 hydrates have been seen on E pad. Be prepared for them. Remember that hydrate gas behaves 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. 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 several wells in close proximity. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Discuss offset wellbores with production foreman and consider shutting in adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well. Well specific A/C: x There are no wells with a CF < 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 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. E-22 recorded 46 ppm in December of 2009. The next highest sample was 13.7ppm on E-03 in December 2011. Page 51 Milne Point Unit E-48 SB Producer Drilling Procedure 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 52 Milne Point Unit E-48 SB Producer Drilling Procedure 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 hydrates have been seen on E pad. While the likely depths for hydrates are in the surface interval, remain vigilant. Remember that hydrate gas behaves 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. 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 a number of wells in close proximity. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Discuss offset wellbores with production foreman and consider shutting in adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well. Well specific A/C: x There are no wells with a CF < 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 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. E-22 recorded 46 ppm in December of 2009. The next highest sample was 13.7ppm on E-03 in December 2011. x The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. Page 53 Milne Point Unit E-48 SB Producer Drilling Procedure x The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. x In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 54 Milne Point Unit E-48 SB 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 appropriately 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 are multiple planned fault crossings. 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. E-22 recorded 46 ppm in December of 2009. The next highest sample was 13.7 ppm on E-03 in December 2011. 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. 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 MPE-28 – is currently shut-in with two CIBP’s installed in the 7-5/8” casing at 1,500’ and 7,609’ MD. The well will remain shut-in while drilling the E-48 well. x MPG-17 – An OA and OB injector that is currently offline. The well will be shut-in while drilling the E-48 well. Page 55 Milne Point Unit E-48 SB Producer Drilling Procedure 28.0 Doyon 14 Layout Page 56 Milne Point Unit E-48 SB Producer Drilling Procedure 29.0 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. Page57Milne Point Unit E-48 SB ProducerDrilling Procedure30.0 Doyon 14 Choke Manifold Schematic Page 58 Milne Point Unit E-48 SB Producer Drilling Procedure 31.0 Casing Design Page 59 Milne Point Unit E-48 SB Producer Drilling Procedure 32.0 12-1/4” Hole Section MASP Page 60 Milne Point Unit E-48 SB Producer Drilling Procedure 33.0 8-1/2” Hole Section MASP Page 61 Milne Point Unit E-48 SB Producer Drilling Procedure 34.0 Spider Plot (NAD 27) (Governmental Sections) Page 62 Milne Point Unit E-48 SB Producer Drilling Procedure 35.0 Surface Plat (As-Built) (NAD 27) Standard Proposal Report 21 March, 2025 Plan: MPU E-48 wp07 Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-48 MPU E-48 -1000010002000300040005000True Vertical Depth (2000 usft/in)-1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000Vertical Section at 270.00° (2000 usft/in)MPU E-48 wp07 tgt13MPU E-48 wp01 tgt6MPU E-48 wp07 tgt12MPU E-48 wp01 tgt9MPU E-48 wp06 tgt14MPU E-48 wp01 tgt7MPU E-48 wp06 tgt15MPU E-48 wp06 tgt10MPU E-48 wp01 tgt5MPU E-48 wp01 tgt4MPU E-48 wp06 tgt09MPU E-48 wp01 tgt1MPU E-48 wp01 tgt213-3/8" x 17 1/2" Surface Casing9-5/8" x 12 1/4" Intermediate Casing5-1/2" x 8 1/2" Production Cas500100015002000250030003500400045005000550060006500700075008000850090009500100001050011000115001200012500130001350014000145001500015500160001650017000175001800018500190001950019567MPU E-48 wp07Start Dir 2º/100' : 325' MD, 325'TVDStart Dir 2.5º/100' : 600' MD, 599.58'TVDStart Dir 3º/100' : 1100' MD, 1088.44'TVDEnd Dir : 2811.6' MD, 2290.04' TVDStart Dir 4º/100' : 7339.54' MD, 3904.27'TVDEnd Dir : 8730.18' MD, 4226.36' TVDBegin GeosteeringTotal Depth : 19566.8' MD, 3955.8' TVDSV6Base PermafrostSV1UG_LA3UG_MBSB_NASB_NBHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: MPU E-4820.10+N/-S +E/-WNorthingEastingLatittudeLongitude0.000.006016347.25569254.16 70° 27' 18.0654 N 149° 26' 5.4375 WSURVEY PROGRAMDate: 2025-02-25T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool33.70 1700.00 MPU E-48 wp07 (MPU E-48) GYD_Quest GWD1700.00 3565.00 MPU E-48 wp07 (MPU E-48) 3_MWD+IFR2+MS+Sag3565.00 8982.00 MPU E-48 wp07 (MPU E-48) 3_MWD+IFR2+MS+Sag8982.00 19566.80 MPU E-48 wp07 (MPU E-48) GYD_Quest GWDFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation1088.80 1035.00 1100.37 SV61781.80 1728.00 1905.34 Base Permafrost2394.80 2341.00 3105.44 SV13754.80 3701.00 6920.28 UG_LA33993.80 3940.00 7602.95 UG_MB4213.80 4160.00 8588.46 SB_NA4240.80 4187.00 8937.17 SB_NBREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU E-48, True NorthVertical (TVD) Reference:E-48 as staked @ 53.80usftMeasured Depth Reference:E-48 as staked @ 53.80usftCalculation Method: Minimum CurvatureProject:Milne PointSite:M Pt E PadWell:Plan: MPU E-48Wellbore:MPU E-48Design:MPU E-48 wp07CASING DETAILSTVD TVDSS MD SizeName2558.40 2504.60 3564.34 13-3/8 13-3/8" x 17 1/2" Surface Casing4243.93 4190.13 8982.00 9-5/8 9-5/8" x 12 1/4" Intermediate Casing3955.80 3902.00 19566.80 5-1/2 5-1/2" x 8 1/2" Production CasingSECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 33.70 0.00 0.00 33.70 0.00 0.00 0.00 0.00 0.002 325.00 0.00 0.00 325.00 0.00 0.00 0.00 0.00 0.00 Start Dir 2º/100' : 325' MD, 325'TVD3 600.00 5.50 255.00 599.58 -3.41 -12.74 2.00 255.00 12.74 Start Dir 2.5º/100' : 600' MD, 599.58'TVD4 1100.00 17.77 240.96 1088.44 -46.82 -102.94 2.50 -20.00 102.94 Start Dir 3º/100' : 1100' MD, 1088.44'TVD5 2811.60 69.11 241.16 2290.04 -596.59 -1099.22 3.00 0.24 1099.22 End Dir : 2811.6' MD, 2290.04' TVD6 7339.54 69.11 241.16 3904.27 -2637.37 -4804.86 0.00 0.00 4804.86 Start Dir 4º/100' : 7339.54' MD, 3904.27'TVD7 8730.18 86.00 295.77 4226.36 -2650.22 -6102.07 4.00 80.18 6102.07 End Dir : 8730.18' MD, 4226.36' TVD8 8980.18 86.00 295.77 4243.80 -2541.80 -6326.66 0.00 0.00 6326.66 MPU E-48 wp01 tgt19 9311.06 96.22 295.78 4237.41 -2398.14 -6624.17 3.09 0.05 6624.1710 9325.93 96.22 295.78 4235.80 -2391.71 -6637.48 0.00 0.00 6637.48 MPU E-48 wp01 tgt211 9371.97 95.15 296.20 4231.24 -2371.63 -6678.66 2.50 158.39 6678.6612 9697.68 95.15 296.20 4202.03 -2228.39 -6969.72 0.00 0.00 6969.7213 10345.40 91.56 277.07 4163.80 -2044.34 -7586.33 3.00 -99.97 7586.33 MPU E-48 wp01 tgt414 10590.54 88.66 271.67 4163.32 -2025.67 -7830.63 2.50 -118.17 7830.6315 11125.89 88.66 271.67 4175.80 -2010.09 -8365.62 0.00 0.00 8365.62 MPU E-48 wp01 tgt516 11323.24 91.30 267.50 4175.87 -2011.53 -8562.89 2.50 -57.76 8562.8917 11988.48 91.30 267.50 4160.80 -2040.59 -9227.33 0.00 0.00 9227.33 MPU E-48 wp01 tgt618 12185.99 95.88 271.26 4148.44 -2042.74 -9424.36 3.00 39.27 9424.3619 12914.66 95.88 271.26 4073.80 -2026.77 -10149.02 0.00 0.00 10149.02 MPU E-48 wp01 tgt720 13327.86 92.68 283.27 4042.87 -1974.65 -10556.94 3.00 104.46 10556.9421 14634.19 92.68 283.27 3981.84 -1675.06 -11826.98 0.00 0.00 11826.9822 14892.45 90.00 276.00 3975.80 -1631.88 -12081.33 3.00 -110.10 12081.33 MPU E-48 wp01 tgt923 14926.75 89.09 276.48 3976.07 -1628.15 -12115.43 3.00 152.34 12115.4324 15215.75 89.09 276.48 3980.67 -1595.55 -12402.55 0.00 0.00 12402.5525 15883.10 88.85 296.50 3992.80 -1407.14 -13039.10 3.00 90.86 13039.1026 15933.10 88.85 296.50 3993.80 -1384.83 -13083.83 0.00 0.00 13083.83 MPU E-48 wp06 tgt0927 16162.17 91.74 303.09 3992.62 -1271.09 -13282.49 3.14 66.34 13282.4928 16185.81 91.74 303.09 3991.91 -1258.18 -13302.29 0.00 0.00 13302.2929 16716.92 90.00 286.50 3983.80 -1036.29 -13782.69 3.14 -95.81 13782.69 MPU E-48 wp06 tgt1030 16799.18 90.77 284.16 3983.25 -1014.54 -13862.02 3.00 -71.83 13862.0231 17156.86 90.77 284.16 3978.44 -927.08 -14208.81 0.00 0.00 14208.8132 17695.96 90.00 268.00 3974.80 -870.20 -14743.08 3.00 -92.65 14743.0833 18445.96 90.00 268.00 3974.80 -896.37 -15492.63 0.00 0.00 15492.63 MPU E-48 wp07 tgt1334 18865.68 91.97 255.14 3967.54 -957.76 -15906.86 3.10 -81.20 15906.8635 18963.22 91.97 255.14 3964.18 -982.77 -16001.08 0.00 0.00 16001.0836 19446.80 90.00 270.00 3955.80 -1045.11 -16479.16 3.10 97.40 16479.1637 19566.80 90.00 270.00 3955.80 -1045.11 -16599.16 0.00 0.00 16599.16 MPU E-48 wp06 tgt15 Total Depth : 19566.8' MD, 3955.8' TVD -8000-7000-6000-5000-4000-3000-2000-1000010002000300040005000South(-)/North(+) (2000 usft/in)-18000 -17000 -16000 -15000 -14000 -13000 -12000 -11000 -10000 -9000 -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 1000West(-)/East(+) (2000 usft/in)MPU E-48 wp01 tgt2MPU E-48 wp01 tgt1MPU E-48 wp06 tgt09MPU E-48 wp01 tgt4MPU E-48 wp01 tgt5MPU E-48 wp06 tgt10MPU E-48 wp06 tgt15MPU E-48 wp01 tgt7MPU E-48 wp06 tgt14MPU E-48 wp01 tgt9MPU E-48 wp07 tgt12MPU E-48 wp01 tgt6MPU E-48 wp07 tgt1313-3/8" x 17 1/2" Surface Casing9-5/8" x 12 1/4" Intermediate Casing5-1/2" x 8 1/2" Production Casing2505 00750100 0 12 50 1500 1 7 5 0 2 0 0 0 2 2 50 2 50 0 2 7 50 3 0 00 3 2 50 3 500 3 7 5 0 4 0 00 3956MPU E-48 wp07Start Dir 2º/100' : 325' MD, 325'TVDStart Dir 2.5º/100' : 600' MD, 599.58'TVDStart Dir 3º/100' : 1100' MD, 1088.44'TVDEnd Dir : 2811.6' MD, 2290.04' TVDStart Dir 4º/100' : 7339.54' MD, 3904.27'TVDEnd Dir : 8730.18' MD, 4226.36' TVDBegin GeosteeringTotal Depth : 19566.8' MD, 3955.8' TVDCASING DETAILSTVDTVDSS MDSize Name2558.40 2504.60 3564.34 13-3/8 13-3/8" x 17 1/2" Surface Casing4243.93 4190.13 8982.00 9-5/8 9-5/8" x 12 1/4" Intermediate Casing3955.80 3902.00 19566.80 5-1/2 5-1/2" x 8 1/2" Production CasingProject: Milne PointSite: M Pt E PadWell: Plan: MPU E-48Wellbore: MPU E-48Plan: MPU E-48 wp07WELL DETAILS: Plan: MPU E-4820.10+N/-S +E/-W Northing EastingLatittudeLongitude0.00 0.00 6016347.25 569254.16 70° 27' 18.0654 N 149° 26' 5.4375 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU E-48, True NorthVertical (TVD) Reference:E-48 as staked @ 53.80usftMeasured Depth Reference:E-48 as staked @ 53.80usftCalculation Method:Minimum Curvature Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt E Pad Standard Proposal Report Well: Wellbore: Plan: MPU E-48 MPU E-48 Survey Calculation Method:Minimum Curvature E-48 as staked @ 53.80usft Design:MPU E-48 wp07 Database:Alaska MD Reference:E-48 as staked @ 53.80usft North Reference: Well Plan: MPU E-48 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 E Pad, TR-13-10 usft Map usft usft °0.53Slot Radius:"0 6,013,798.68 569,440.72 0.00 70° 26' 52.9824 N 149° 26' 0.6546 W Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: Plan: MPU E-48 usft usft 0.00 0.00 6,016,347.25 569,254.16 20.10Wellhead Elevation:usft0.50 70° 27' 18.0654 N 149° 26' 5.4375 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU E-48 Model NameMagnetics BGGM2024 4/25/2025 13.82 80.70 57,207.86113745 Phase:Version: Audit Notes: Design MPU E-48 wp07 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:33.70 270.000.000.0033.70 3/21/2025 4:41:21PM COMPASS 5000.17 Build 04 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt E Pad Standard Proposal Report Well: Wellbore: Plan: MPU E-48 MPU E-48 Survey Calculation Method:Minimum Curvature E-48 as staked @ 53.80usft Design:MPU E-48 wp07 Database:Alaska MD Reference:E-48 as staked @ 53.80usft North Reference: Well Plan: MPU E-48 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 0.000.000.000.000.000.0033.700.000.0033.70 -20.10 0.000.000.000.000.000.00325.000.000.00325.00 271.20 255.000.002.002.00-12.74-3.41599.58255.005.50600.00 545.78 -20.00-2.812.452.50-102.94-46.821,088.44240.9617.771,100.00 1,034.64 0.240.013.003.00-1,099.22-596.592,290.04241.1669.112,811.60 2,236.24 0.000.000.000.00-4,804.86-2,637.373,904.27241.1669.117,339.54 3,850.47 80.183.931.214.00-6,102.07-2,650.224,226.36295.7786.008,730.18 4,172.56 0.000.000.000.00-6,326.66-2,541.804,243.80295.7786.008,980.18 4,190.00 0.050.003.093.09-6,624.17-2,398.144,237.41295.7896.229,311.06 4,183.61 0.000.000.000.00-6,637.48-2,391.714,235.80295.7896.229,325.93 4,182.00 158.390.92-2.322.50-6,678.66-2,371.634,231.24296.2095.159,371.97 4,177.44 0.000.000.000.00-6,969.72-2,228.394,202.03296.2095.159,697.68 4,148.23 -99.97-2.95-0.553.00-7,586.33-2,044.344,163.80277.0791.5610,345.40 4,110.00 -118.17-2.20-1.182.50-7,830.63-2,025.674,163.32271.6788.6610,590.54 4,109.52 0.000.000.000.00-8,365.62-2,010.094,175.80271.6788.6611,125.89 4,122.00 -57.76-2.111.332.50-8,562.89-2,011.534,175.87267.5091.3011,323.24 4,122.07 0.000.000.000.00-9,227.33-2,040.594,160.80267.5091.3011,988.48 4,107.00 39.271.912.323.00-9,424.36-2,042.744,148.44271.2695.8812,185.99 4,094.64 0.000.000.000.00-10,149.02-2,026.774,073.80271.2695.8812,914.66 4,020.00 104.462.91-0.773.00-10,556.94-1,974.654,042.87283.2792.6813,327.86 3,989.07 0.000.000.000.00-11,826.98-1,675.063,981.84283.2792.6814,634.19 3,928.04 -110.10-2.82-1.043.00-12,081.33-1,631.883,975.80276.0090.0014,892.45 3,922.00 152.341.39-2.663.00-12,115.43-1,628.153,976.07276.4889.0914,926.75 3,922.27 0.000.000.000.00-12,402.55-1,595.553,980.67276.4889.0915,215.75 3,926.87 90.863.00-0.043.00-13,039.10-1,407.143,992.80296.5088.8515,883.10 3,939.00 0.000.000.000.00-13,083.83-1,384.833,993.80296.5088.8515,933.10 3,940.00 66.342.881.263.14-13,282.49-1,271.093,992.62303.0991.7416,162.17 3,938.82 0.000.000.000.00-13,302.29-1,258.183,991.91303.0991.7416,185.81 3,938.11 -95.81-3.12-0.333.14-13,782.69-1,036.293,983.80286.5090.0016,716.92 3,930.00 -71.83-2.850.943.00-13,862.02-1,014.543,983.25284.1690.7716,799.18 3,929.45 0.000.000.000.00-14,208.81-927.083,978.44284.1690.7717,156.86 3,924.64 -92.65-3.00-0.143.00-14,743.08-870.203,974.80268.0090.0017,695.96 3,921.00 0.000.000.000.00-15,492.63-896.373,974.80268.0090.0018,445.96 3,921.00 -81.20-3.060.473.10-15,906.86-957.763,967.54255.1491.9718,865.68 3,913.74 0.000.000.000.00-16,001.08-982.773,964.18255.1491.9718,963.22 3,910.38 97.403.07-0.413.10-16,479.16-1,045.113,955.80270.0090.0019,446.80 3,902.00 0.000.000.000.00-16,599.16-1,045.113,955.80270.0090.0019,566.80 3,902.00 3/21/2025 4:41:21PM COMPASS 5000.17 Build 04 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt E Pad Standard Proposal Report Well: Wellbore: Plan: MPU E-48 MPU E-48 Survey Calculation Method:Minimum Curvature E-48 as staked @ 53.80usft Design:MPU E-48 wp07 Database:Alaska MD Reference:E-48 as staked @ 53.80usft North Reference: Well Plan: MPU E-48 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 20.10 Vert Section 33.70 0.00 33.70 0.00 0.000.00 569,254.166,016,347.2520.10 0.00 0.00 100.00 0.00 100.00 0.00 0.000.00 569,254.166,016,347.25-46.20 0.00 0.00 200.00 0.00 200.00 0.00 0.000.00 569,254.166,016,347.25-146.20 0.00 0.00 300.00 0.00 300.00 0.00 0.000.00 569,254.166,016,347.25-246.20 0.00 0.00 325.00 0.00 325.00 0.00 0.000.00 569,254.166,016,347.25-271.20 0.00 0.00 Start Dir 2º/100' : 325' MD, 325'TVD 400.00 1.50 399.99 -0.25 -0.95255.00 569,253.216,016,346.99-346.19 2.00 0.95 500.00 3.50 499.89 -1.38 -5.16255.00 569,249.016,016,345.82-446.09 2.00 5.16 600.00 5.50 599.58 -3.41 -12.74255.00 569,241.456,016,343.72-545.78 2.00 12.74 Start Dir 2.5º/100' : 600' MD, 599.58'TVD 700.00 7.90 698.89 -7.14 -23.77248.77 569,230.466,016,339.89-645.09 2.50 23.77 800.00 10.34 797.62 -13.36 -38.34245.44 569,215.956,016,333.53-743.82 2.50 38.34 900.00 12.81 895.58 -22.06 -56.41243.38 569,197.966,016,324.67-841.78 2.50 56.41 1,000.00 15.28 992.58 -33.22 -77.96241.98 569,176.526,016,313.31-938.78 2.50 77.96 1,100.00 17.77 1,088.44 -46.82 -102.94240.96 569,151.676,016,299.48-1,034.64 2.50 102.94 Start Dir 3º/100' : 1100' MD, 1088.44'TVD 1,100.37 17.78 1,088.80 -46.87 -103.04240.96 569,151.576,016,299.43-1,035.00 3.00 103.04 SV6 1,200.00 20.77 1,182.83 -62.82 -131.79240.99 569,122.986,016,283.21-1,129.03 3.00 131.79 1,300.00 23.77 1,275.37 -81.19 -164.93241.02 569,090.016,016,264.54-1,221.57 3.00 164.93 1,400.00 26.77 1,365.79 -101.86 -202.27241.04 569,052.876,016,243.53-1,311.99 3.00 202.27 1,500.00 29.77 1,453.85 -124.78 -243.70241.06 569,011.656,016,220.23-1,400.05 3.00 243.70 1,600.00 32.77 1,539.32 -149.88 -289.12241.07 568,966.476,016,194.70-1,485.52 3.00 289.12 1,700.00 35.77 1,621.95 -177.11 -338.40241.08 568,917.466,016,167.02-1,568.15 3.00 338.40 1,800.00 38.77 1,701.53 -206.38 -391.40241.10 568,864.746,016,137.26-1,647.73 3.00 391.40 1,900.00 41.77 1,777.82 -237.61 -447.98241.10 568,808.466,016,105.51-1,724.02 3.00 447.98 1,905.34 41.93 1,781.80 -239.33 -451.09241.10 568,805.356,016,103.76-1,728.00 3.00 451.09 Base Permafrost 2,000.00 44.77 1,850.63 -270.72 -507.98241.11 568,748.776,016,071.84-1,796.83 3.00 507.98 2,100.00 47.77 1,919.75 -305.62 -571.24241.12 568,685.846,016,036.36-1,865.95 3.00 571.24 2,200.00 50.77 1,985.00 -342.21 -637.58241.13 568,619.856,015,999.16-1,931.20 3.00 637.58 2,300.00 53.77 2,046.19 -380.39 -706.83241.13 568,550.966,015,960.34-1,992.39 3.00 706.83 2,400.00 56.77 2,103.16 -420.06 -778.79241.14 568,479.386,015,920.01-2,049.36 3.00 778.79 2,500.00 59.77 2,155.75 -461.11 -853.27241.14 568,405.296,015,878.28-2,101.95 3.00 853.27 2,600.00 62.77 2,203.82 -503.42 -930.06241.15 568,328.906,015,835.26-2,150.02 3.00 930.06 2,700.00 65.77 2,247.24 -546.88 -1,008.96241.15 568,250.426,015,791.07-2,193.44 3.00 1,008.96 2,800.00 68.77 2,285.88 -591.37 -1,089.74241.16 568,170.076,015,745.83-2,232.08 3.00 1,089.74 2,811.60 69.11 2,290.04 -596.59 -1,099.22241.16 568,160.646,015,740.52-2,236.24 3.00 1,099.22 End Dir : 2811.6' MD, 2290.04' TVD 2,900.00 69.11 2,321.56 -636.44 -1,171.56241.16 568,088.676,015,700.01-2,267.76 0.00 1,171.56 3,000.00 69.11 2,357.21 -681.51 -1,253.40241.16 568,007.266,015,654.19-2,303.41 0.00 1,253.40 3,100.00 69.11 2,392.86 -726.58 -1,335.24241.16 567,925.856,015,608.36-2,339.06 0.00 1,335.24 3,105.44 69.11 2,394.80 -729.03 -1,339.70241.16 567,921.426,015,605.87-2,341.00 0.00 1,339.70 SV1 3,200.00 69.11 2,428.51 -771.65 -1,417.08241.16 567,844.446,015,562.54-2,374.71 0.00 1,417.08 3/21/2025 4:41:21PM COMPASS 5000.17 Build 04 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt E Pad Standard Proposal Report Well: Wellbore: Plan: MPU E-48 MPU E-48 Survey Calculation Method:Minimum Curvature E-48 as staked @ 53.80usft Design:MPU E-48 wp07 Database:Alaska MD Reference:E-48 as staked @ 53.80usft North Reference: Well Plan: MPU E-48 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 -2,410.36 Vert Section 3,300.00 69.11 2,464.16 -816.72 -1,498.92241.16 567,763.046,015,516.71-2,410.36 0.00 1,498.92 3,400.00 69.11 2,499.81 -861.79 -1,580.76241.16 567,681.636,015,470.89-2,446.01 0.00 1,580.76 3,500.00 69.11 2,535.46 -906.86 -1,662.60241.16 567,600.226,015,425.06-2,481.66 0.00 1,662.60 3,564.34 69.11 2,558.40 -935.86 -1,715.26241.16 567,547.846,015,395.58-2,504.60 0.00 1,715.26 13-3/8" x 17 1/2" Surface Casing 3,600.00 69.11 2,571.11 -951.93 -1,744.44241.16 567,518.816,015,379.24-2,517.31 0.00 1,744.44 3,700.00 69.11 2,606.76 -997.00 -1,826.28241.16 567,437.406,015,333.41-2,552.96 0.00 1,826.28 3,800.00 69.11 2,642.41 -1,042.07 -1,908.12241.16 567,355.996,015,287.59-2,588.61 0.00 1,908.12 3,900.00 69.11 2,678.06 -1,087.14 -1,989.96241.16 567,274.586,015,241.76-2,624.26 0.00 1,989.96 4,000.00 69.11 2,713.71 -1,132.21 -2,071.80241.16 567,193.176,015,195.94-2,659.91 0.00 2,071.80 4,100.00 69.11 2,749.36 -1,177.28 -2,153.64241.16 567,111.766,015,150.11-2,695.56 0.00 2,153.64 4,200.00 69.11 2,785.01 -1,222.36 -2,235.48241.16 567,030.356,015,104.28-2,731.21 0.00 2,235.48 4,300.00 69.11 2,820.66 -1,267.43 -2,317.32241.16 566,948.946,015,058.46-2,766.86 0.00 2,317.32 4,400.00 69.11 2,856.31 -1,312.50 -2,399.16241.16 566,867.536,015,012.63-2,802.51 0.00 2,399.16 4,500.00 69.11 2,891.96 -1,357.57 -2,480.99241.16 566,786.136,014,966.81-2,838.16 0.00 2,480.99 4,600.00 69.11 2,927.61 -1,402.64 -2,562.83241.16 566,704.726,014,920.98-2,873.81 0.00 2,562.83 4,700.00 69.11 2,963.26 -1,447.71 -2,644.67241.16 566,623.316,014,875.16-2,909.46 0.00 2,644.67 4,800.00 69.11 2,998.92 -1,492.78 -2,726.51241.16 566,541.906,014,829.33-2,945.12 0.00 2,726.51 4,900.00 69.11 3,034.57 -1,537.85 -2,808.35241.16 566,460.496,014,783.51-2,980.77 0.00 2,808.35 5,000.00 69.11 3,070.22 -1,582.92 -2,890.19241.16 566,379.086,014,737.68-3,016.42 0.00 2,890.19 5,100.00 69.11 3,105.87 -1,627.99 -2,972.03241.16 566,297.676,014,691.86-3,052.07 0.00 2,972.03 5,200.00 69.11 3,141.52 -1,673.06 -3,053.87241.16 566,216.266,014,646.03-3,087.72 0.00 3,053.87 5,300.00 69.11 3,177.17 -1,718.13 -3,135.71241.16 566,134.856,014,600.21-3,123.37 0.00 3,135.71 5,400.00 69.11 3,212.82 -1,763.20 -3,217.55241.16 566,053.446,014,554.38-3,159.02 0.00 3,217.55 5,500.00 69.11 3,248.47 -1,808.27 -3,299.39241.16 565,972.036,014,508.56-3,194.67 0.00 3,299.39 5,600.00 69.11 3,284.12 -1,853.35 -3,381.23241.16 565,890.626,014,462.73-3,230.32 0.00 3,381.23 5,700.00 69.11 3,319.77 -1,898.42 -3,463.07241.16 565,809.216,014,416.91-3,265.97 0.00 3,463.07 5,800.00 69.11 3,355.42 -1,943.49 -3,544.91241.16 565,727.816,014,371.08-3,301.62 0.00 3,544.91 5,900.00 69.11 3,391.07 -1,988.56 -3,626.75241.16 565,646.406,014,325.26-3,337.27 0.00 3,626.75 6,000.00 69.11 3,426.72 -2,033.63 -3,708.59241.16 565,564.996,014,279.43-3,372.92 0.00 3,708.59 6,100.00 69.11 3,462.37 -2,078.70 -3,790.42241.16 565,483.586,014,233.61-3,408.57 0.00 3,790.42 6,200.00 69.11 3,498.02 -2,123.77 -3,872.26241.16 565,402.176,014,187.78-3,444.22 0.00 3,872.26 6,300.00 69.11 3,533.67 -2,168.84 -3,954.10241.16 565,320.766,014,141.96-3,479.87 0.00 3,954.10 6,400.00 69.11 3,569.32 -2,213.91 -4,035.94241.16 565,239.356,014,096.13-3,515.52 0.00 4,035.94 6,500.00 69.11 3,604.97 -2,258.98 -4,117.78241.16 565,157.946,014,050.31-3,551.17 0.00 4,117.78 6,600.00 69.11 3,640.62 -2,304.05 -4,199.62241.16 565,076.536,014,004.48-3,586.82 0.00 4,199.62 6,700.00 69.11 3,676.27 -2,349.12 -4,281.46241.16 564,995.126,013,958.66-3,622.47 0.00 4,281.46 6,800.00 69.11 3,711.92 -2,394.19 -4,363.30241.16 564,913.716,013,912.83-3,658.12 0.00 4,363.30 6,900.00 69.11 3,747.57 -2,439.26 -4,445.14241.16 564,832.306,013,867.01-3,693.77 0.00 4,445.14 6,920.28 69.11 3,754.80 -2,448.40 -4,461.73241.16 564,815.806,013,857.71-3,701.00 0.00 4,461.73 UG_LA3 7,000.00 69.11 3,783.22 -2,484.34 -4,526.98241.16 564,750.906,013,821.18-3,729.42 0.00 4,526.98 7,100.00 69.11 3,818.87 -2,529.41 -4,608.82241.16 564,669.496,013,775.35-3,765.07 0.00 4,608.82 7,200.00 69.11 3,854.52 -2,574.48 -4,690.66241.16 564,588.086,013,729.53-3,800.72 0.00 4,690.66 7,300.00 69.11 3,890.17 -2,619.55 -4,772.50241.16 564,506.676,013,683.70-3,836.37 0.00 4,772.50 3/21/2025 4:41:21PM COMPASS 5000.17 Build 04 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt E Pad Standard Proposal Report Well: Wellbore: Plan: MPU E-48 MPU E-48 Survey Calculation Method:Minimum Curvature E-48 as staked @ 53.80usft Design:MPU E-48 wp07 Database:Alaska MD Reference:E-48 as staked @ 53.80usft North Reference: Well Plan: MPU E-48 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 -3,850.47 Vert Section 7,339.54 69.11 3,904.27 -2,637.37 -4,804.86241.16 564,474.486,013,665.59-3,850.47 0.00 4,804.86 Start Dir 4º/100' : 7339.54' MD, 3904.27'TVD 7,400.00 69.55 3,925.61 -2,663.55 -4,855.00243.70 564,424.596,013,638.94-3,871.81 4.00 4,855.00 7,500.00 70.34 3,959.92 -2,702.05 -4,940.65247.87 564,339.316,013,599.65-3,906.12 4.00 4,940.65 7,600.00 71.23 3,992.85 -2,734.42 -5,029.33252.00 564,250.946,013,566.46-3,939.05 4.00 5,029.33 7,602.95 71.26 3,993.80 -2,735.29 -5,031.99252.13 564,248.296,013,565.57-3,940.00 4.00 5,031.99 UG_MB 7,700.00 72.21 4,024.23 -2,760.51 -5,120.60256.09 564,159.926,013,539.53-3,970.43 4.00 5,120.60 7,800.00 73.27 4,053.92 -2,780.17 -5,214.02260.13 564,066.706,013,519.00-4,000.12 4.00 5,214.02 7,900.00 74.41 4,081.76 -2,793.32 -5,309.14264.12 563,971.716,013,504.97-4,027.96 4.00 5,309.14 8,000.00 75.62 4,107.63 -2,799.89 -5,405.49268.07 563,875.436,013,497.51-4,053.83 4.00 5,405.49 8,100.00 76.89 4,131.40 -2,799.85 -5,502.61271.97 563,778.336,013,496.65-4,077.60 4.00 5,502.61 8,200.00 78.23 4,152.95 -2,793.20 -5,600.01275.83 563,680.886,013,502.39-4,099.15 4.00 5,600.01 8,300.00 79.61 4,172.17 -2,779.97 -5,697.23279.66 563,583.556,013,514.71-4,118.37 4.00 5,697.23 8,400.00 81.04 4,188.98 -2,760.23 -5,793.79283.45 563,486.826,013,533.55-4,135.18 4.00 5,793.79 8,500.00 82.51 4,203.28 -2,734.07 -5,889.22287.21 563,391.166,013,558.82-4,149.48 4.00 5,889.22 8,588.46 83.84 4,213.80 -2,705.68 -5,972.32290.51 563,307.816,013,586.43-4,160.00 4.00 5,972.32 SB_NA 8,600.00 84.01 4,215.02 -2,701.62 -5,983.06290.94 563,297.046,013,590.39-4,161.22 4.00 5,983.06 8,700.00 85.54 4,224.13 -2,663.04 -6,074.84294.65 563,204.916,013,628.11-4,170.33 4.00 6,074.84 8,730.18 86.00 4,226.36 -2,650.22 -6,102.07295.77 563,177.566,013,640.68-4,172.56 4.00 6,102.07 End Dir : 8730.18' MD, 4226.36' TVD 8,800.00 86.00 4,231.23 -2,619.94 -6,164.79295.77 563,114.576,013,670.37-4,177.43 0.00 6,164.79 8,900.00 86.00 4,238.21 -2,576.57 -6,254.63295.77 563,024.346,013,712.90-4,184.41 0.00 6,254.63 8,937.17 86.00 4,240.80 -2,560.45 -6,288.02295.77 562,990.806,013,728.71-4,187.00 0.00 6,288.02 SB_NB 8,980.18 86.00 4,243.80 -2,541.80 -6,326.66295.77 562,952.006,013,747.00-4,190.00 0.00 6,326.66 8,982.00 86.06 4,243.93 -2,541.01 -6,328.29295.77 562,950.356,013,747.78-4,190.13 3.09 6,328.29 9-5/8" x 12 1/4" Intermediate Casing 8,982.10 86.06 4,243.93 -2,540.96 -6,328.38295.77 562,950.266,013,747.82-4,190.13 3.09 6,328.38 Begin Geosteering 9,000.00 86.61 4,245.08 -2,533.20 -6,344.47295.77 562,934.116,013,755.43-4,191.28 3.09 6,344.47 9,100.00 89.70 4,248.29 -2,489.74 -6,434.47295.77 562,843.726,013,798.04-4,194.49 3.09 6,434.47 9,200.00 92.79 4,246.13 -2,446.28 -6,524.49295.78 562,753.316,013,840.67-4,192.33 3.09 6,524.49 9,300.00 95.87 4,238.58 -2,402.92 -6,614.27295.78 562,663.146,013,883.18-4,184.78 3.09 6,614.27 9,311.06 96.22 4,237.41 -2,398.14 -6,624.17295.78 562,653.196,013,887.87-4,183.61 3.09 6,624.17 9,325.93 96.22 4,235.80 -2,391.71 -6,637.48295.78 562,639.826,013,894.18-4,182.00 0.00 6,637.48 9,371.97 95.15 4,231.24 -2,371.63 -6,678.66296.20 562,598.466,013,913.87-4,177.44 2.50 6,678.66 9,400.00 95.15 4,228.73 -2,359.30 -6,703.71296.20 562,573.306,013,925.96-4,174.93 0.00 6,703.71 9,500.00 95.15 4,219.76 -2,315.32 -6,793.07296.20 562,483.546,013,969.11-4,165.96 0.00 6,793.07 9,600.00 95.15 4,210.79 -2,271.34 -6,882.43296.20 562,393.796,014,012.25-4,156.99 0.00 6,882.43 9,697.68 95.15 4,202.03 -2,228.39 -6,969.72296.20 562,306.116,014,054.39-4,148.23 0.00 6,969.72 9,700.00 95.13 4,201.82 -2,227.37 -6,971.79296.14 562,304.036,014,055.39-4,148.02 3.00 6,971.79 9,800.00 94.61 4,193.33 -2,185.81 -7,062.34293.17 562,213.116,014,096.10-4,139.53 3.00 7,062.34 9,900.00 94.07 4,185.76 -2,148.96 -7,154.98290.21 562,120.146,014,132.08-4,131.96 3.00 7,154.98 3/21/2025 4:41:21PM COMPASS 5000.17 Build 04 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt E Pad Standard Proposal Report Well: Wellbore: Plan: MPU E-48 MPU E-48 Survey Calculation Method:Minimum Curvature E-48 as staked @ 53.80usft Design:MPU E-48 wp07 Database:Alaska MD Reference:E-48 as staked @ 53.80usft North Reference: Well Plan: MPU E-48 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 -4,125.35 Vert Section 10,000.00 93.52 4,179.15 -2,116.92 -7,249.47287.26 562,025.376,014,163.24-4,125.35 3.00 7,249.47 10,100.00 92.96 4,173.49 -2,089.77 -7,345.53284.30 561,929.066,014,189.49-4,119.69 3.00 7,345.53 10,200.00 92.39 4,168.82 -2,067.60 -7,442.92281.35 561,831.486,014,210.76-4,115.02 3.00 7,442.92 10,300.00 91.82 4,165.14 -2,050.45 -7,541.36278.41 561,732.906,014,226.99-4,111.34 3.00 7,541.36 10,345.40 91.56 4,163.80 -2,044.34 -7,586.33277.07 561,687.886,014,232.68-4,110.00 3.00 7,586.33 10,400.00 90.92 4,162.62 -2,038.19 -7,640.56275.87 561,633.596,014,238.32-4,108.82 2.50 7,640.56 10,500.00 89.73 4,162.05 -2,029.88 -7,740.21273.66 561,533.896,014,245.70-4,108.25 2.50 7,740.21 10,590.54 88.66 4,163.32 -2,025.67 -7,830.63271.67 561,443.446,014,249.07-4,109.52 2.50 7,830.63 10,600.00 88.66 4,163.54 -2,025.40 -7,840.09271.67 561,433.986,014,249.26-4,109.74 0.00 7,840.09 10,700.00 88.66 4,165.87 -2,022.49 -7,940.02271.67 561,334.036,014,251.24-4,112.07 0.00 7,940.02 10,800.00 88.66 4,168.20 -2,019.58 -8,039.95271.67 561,234.096,014,253.22-4,114.40 0.00 8,039.95 10,900.00 88.66 4,170.53 -2,016.67 -8,139.88271.67 561,134.156,014,255.20-4,116.73 0.00 8,139.88 11,000.00 88.66 4,172.87 -2,013.76 -8,239.81271.67 561,034.206,014,257.19-4,119.07 0.00 8,239.81 11,100.00 88.66 4,175.20 -2,010.84 -8,339.74271.67 560,934.266,014,259.17-4,121.40 0.00 8,339.74 11,125.89 88.66 4,175.80 -2,010.09 -8,365.62271.67 560,908.386,014,259.68-4,122.00 0.00 8,365.62 11,200.00 89.65 4,176.89 -2,008.95 -8,439.70270.10 560,834.296,014,260.14-4,123.09 2.50 8,439.70 11,300.00 90.99 4,176.33 -2,010.61 -8,539.68267.99 560,734.356,014,257.54-4,122.53 2.50 8,539.68 11,323.24 91.30 4,175.87 -2,011.53 -8,562.89267.50 560,711.146,014,256.41-4,122.07 2.50 8,562.89 11,400.00 91.30 4,174.13 -2,014.88 -8,639.56267.50 560,634.516,014,252.34-4,120.33 0.00 8,639.56 11,500.00 91.30 4,171.86 -2,019.25 -8,739.44267.50 560,534.696,014,247.05-4,118.06 0.00 8,739.44 11,600.00 91.30 4,169.60 -2,023.62 -8,839.32267.50 560,434.876,014,241.75-4,115.80 0.00 8,839.32 11,700.00 91.30 4,167.33 -2,027.99 -8,939.20267.50 560,335.046,014,236.46-4,113.53 0.00 8,939.20 11,800.00 91.30 4,165.07 -2,032.35 -9,039.08267.50 560,235.226,014,231.16-4,111.27 0.00 9,039.08 11,900.00 91.30 4,162.80 -2,036.72 -9,138.96267.50 560,135.396,014,225.87-4,109.00 0.00 9,138.96 11,988.48 91.30 4,160.80 -2,040.59 -9,227.33267.50 560,047.076,014,221.18-4,107.00 0.00 9,227.33 12,000.00 91.57 4,160.51 -2,041.07 -9,238.84267.71 560,035.576,014,220.59-4,106.71 3.00 9,238.84 12,100.00 93.89 4,155.76 -2,043.39 -9,338.69269.62 559,935.756,014,217.34-4,101.96 3.00 9,338.69 12,185.99 95.88 4,148.44 -2,042.74 -9,424.36271.26 559,850.096,014,217.20-4,094.64 3.00 9,424.36 12,200.00 95.88 4,147.00 -2,042.43 -9,438.29271.26 559,836.166,014,217.38-4,093.20 0.00 9,438.29 12,300.00 95.88 4,136.76 -2,040.24 -9,537.74271.26 559,736.706,014,218.64-4,082.96 0.00 9,537.74 12,400.00 95.88 4,126.52 -2,038.05 -9,637.19271.26 559,637.246,014,219.91-4,072.72 0.00 9,637.19 12,500.00 95.88 4,116.27 -2,035.86 -9,736.64271.26 559,537.796,014,221.18-4,062.47 0.00 9,736.64 12,600.00 95.88 4,106.03 -2,033.66 -9,836.09271.26 559,438.336,014,222.44-4,052.23 0.00 9,836.09 12,700.00 95.88 4,095.79 -2,031.47 -9,935.54271.26 559,338.876,014,223.71-4,041.99 0.00 9,935.54 12,800.00 95.88 4,085.54 -2,029.28 -10,034.99271.26 559,239.426,014,224.98-4,031.74 0.00 10,034.99 12,900.00 95.88 4,075.30 -2,027.09 -10,134.44271.26 559,139.966,014,226.24-4,021.50 0.00 10,134.44 12,914.66 95.88 4,073.80 -2,026.77 -10,149.02271.26 559,125.386,014,226.43-4,020.00 0.00 10,149.02 13,000.00 95.23 4,065.54 -2,023.05 -10,233.87273.75 559,040.516,014,229.36-4,011.74 3.00 10,233.87 13,100.00 94.47 4,057.08 -2,014.01 -10,333.08276.66 558,941.226,014,237.48-4,003.28 3.00 10,333.08 13,200.00 93.69 4,049.97 -1,999.93 -10,431.82279.57 558,842.366,014,250.64-3,996.17 3.00 10,431.82 13,300.00 92.90 4,044.22 -1,980.85 -10,529.80282.47 558,744.226,014,268.80-3,990.42 3.00 10,529.80 13,327.86 92.68 4,042.87 -1,974.65 -10,556.94283.27 558,717.036,014,274.75-3,989.07 3.00 10,556.94 13,400.00 92.68 4,039.50 -1,958.11 -10,627.07283.27 558,646.766,014,290.64-3,985.70 0.00 10,627.07 13,500.00 92.68 4,034.82 -1,935.18 -10,724.29283.27 558,549.336,014,312.66-3,981.02 0.00 10,724.29 13,600.00 92.68 4,030.15 -1,912.24 -10,821.51283.27 558,451.916,014,334.69-3,976.35 0.00 10,821.51 3/21/2025 4:41:21PM COMPASS 5000.17 Build 04 Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt E Pad Standard Proposal Report Well: Wellbore: Plan: MPU E-48 MPU E-48 Survey Calculation Method:Minimum Curvature E-48 as staked @ 53.80usft Design:MPU E-48 wp07 Database:Alaska MD Reference:E-48 as staked @ 53.80usft North Reference: Well Plan: MPU E-48 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 -3,971.68 Vert Section 13,700.00 92.68 4,025.48 -1,889.31 -10,918.74283.27 558,354.496,014,356.72-3,971.68 0.00 10,918.74 13,800.00 92.68 4,020.81 -1,866.37 -11,015.96283.27 558,257.076,014,378.74-3,967.01 0.00 11,015.96 13,900.00 92.68 4,016.14 -1,843.44 -11,113.18283.27 558,159.646,014,400.77-3,962.34 0.00 11,113.18 14,000.00 92.68 4,011.47 -1,820.50 -11,210.40283.27 558,062.226,014,422.80-3,957.67 0.00 11,210.40 14,100.00 92.68 4,006.80 -1,797.57 -11,307.63283.27 557,964.806,014,444.83-3,953.00 0.00 11,307.63 14,200.00 92.68 4,002.12 -1,774.64 -11,404.85283.27 557,867.386,014,466.85-3,948.32 0.00 11,404.85 14,300.00 92.68 3,997.45 -1,751.70 -11,502.07283.27 557,769.966,014,488.88-3,943.65 0.00 11,502.07 14,400.00 92.68 3,992.78 -1,728.77 -11,599.29283.27 557,672.536,014,510.91-3,938.98 0.00 11,599.29 14,500.00 92.68 3,988.11 -1,705.83 -11,696.52283.27 557,575.116,014,532.94-3,934.31 0.00 11,696.52 14,600.00 92.68 3,983.44 -1,682.90 -11,793.74283.27 557,477.696,014,554.96-3,929.64 0.00 11,793.74 14,634.19 92.68 3,981.84 -1,675.06 -11,826.98283.27 557,444.386,014,562.50-3,928.04 0.00 11,826.98 14,700.00 92.00 3,979.16 -1,661.00 -11,891.21281.42 557,380.036,014,575.95-3,925.36 3.00 11,891.21 14,800.00 90.96 3,976.58 -1,643.63 -11,989.64278.60 557,281.456,014,592.41-3,922.78 3.00 11,989.64 14,892.45 90.00 3,975.80 -1,631.88 -12,081.33276.00 557,189.666,014,603.30-3,922.00 3.00 12,081.33 14,900.00 89.80 3,975.81 -1,631.08 -12,088.84276.11 557,182.156,014,604.03-3,922.01 3.00 12,088.84 14,926.75 89.09 3,976.07 -1,628.15 -12,115.43276.48 557,155.546,014,606.71-3,922.27 3.00 12,115.43 15,000.00 89.09 3,977.24 -1,619.89 -12,188.20276.48 557,082.706,014,614.30-3,923.44 0.00 12,188.20 15,100.00 89.09 3,978.83 -1,608.61 -12,287.55276.48 556,983.266,014,624.65-3,925.03 0.00 12,287.55 15,200.00 89.09 3,980.42 -1,597.33 -12,386.90276.48 556,883.816,014,635.01-3,926.62 0.00 12,386.90 15,215.75 89.09 3,980.67 -1,595.55 -12,402.55276.48 556,868.156,014,636.64-3,926.87 0.00 12,402.55 15,300.00 89.05 3,982.04 -1,584.21 -12,486.01279.01 556,784.596,014,647.21-3,928.24 3.00 12,486.01 15,400.00 89.01 3,983.73 -1,565.98 -12,584.31282.01 556,686.146,014,664.52-3,929.93 3.00 12,584.31 15,500.00 88.97 3,985.49 -1,542.63 -12,681.52285.01 556,588.736,014,686.96-3,931.69 3.00 12,681.52 15,600.00 88.94 3,987.32 -1,514.23 -12,777.37288.01 556,492.636,014,714.47-3,933.52 3.00 12,777.37 15,700.00 88.90 3,989.20 -1,480.85 -12,871.60291.01 556,398.096,014,746.97-3,935.40 3.00 12,871.60 15,800.00 88.87 3,991.14 -1,442.58 -12,963.96294.01 556,305.406,014,784.37-3,937.34 3.00 12,963.96 15,883.10 88.85 3,992.80 -1,407.14 -13,039.10296.50 556,229.946,014,819.11-3,939.00 3.00 13,039.10 15,900.00 88.85 3,993.14 -1,399.60 -13,054.22296.50 556,214.756,014,826.51-3,939.34 0.00 13,054.22 15,933.10 88.85 3,993.80 -1,384.83 -13,083.83296.50 556,185.006,014,841.00-3,940.00 0.00 13,083.83 16,000.00 89.69 3,994.65 -1,353.98 -13,143.19298.42 556,125.376,014,871.29-3,940.85 3.14 13,143.19 16,100.00 90.95 3,994.09 -1,304.20 -13,229.90301.30 556,038.216,014,920.26-3,940.29 3.14 13,229.90 16,162.17 91.74 3,992.62 -1,271.09 -13,282.49303.09 555,985.326,014,952.88-3,938.82 3.14 13,282.49 16,185.81 91.74 3,991.91 -1,258.18 -13,302.29303.09 555,965.396,014,965.60-3,938.11 0.00 13,302.29 16,200.00 91.69 3,991.48 -1,250.49 -13,314.20302.65 555,953.426,014,973.18-3,937.68 3.14 13,314.20 16,300.00 91.37 3,988.81 -1,198.89 -13,399.80299.52 555,867.356,015,023.98-3,935.01 3.14 13,399.80 16,400.00 91.05 3,986.70 -1,152.02 -13,488.10296.40 555,778.636,015,070.02-3,932.90 3.14 13,488.10 16,500.00 90.72 3,985.16 -1,110.03 -13,578.83293.27 555,687.526,015,111.16-3,931.36 3.14 13,578.83 16,600.00 90.39 3,984.20 -1,073.04 -13,671.72290.15 555,594.306,015,147.28-3,930.40 3.14 13,671.72 16,700.00 90.06 3,983.81 -1,041.17 -13,766.49287.03 555,499.246,015,178.27-3,930.01 3.14 13,766.49 16,716.92 90.00 3,983.80 -1,036.29 -13,782.69286.50 555,483.006,015,183.00-3,930.00 3.14 13,782.69 16,799.18 90.77 3,983.25 -1,014.54 -13,862.02284.16 555,403.486,015,204.00-3,929.45 3.00 13,862.02 16,900.00 90.77 3,981.89 -989.89 -13,959.77284.16 555,305.526,015,227.74-3,928.09 0.00 13,959.77 17,000.00 90.77 3,980.55 -965.44 -14,056.72284.16 555,208.356,015,251.29-3,926.75 0.00 14,056.72 17,100.00 90.77 3,979.21 -940.99 -14,153.68284.16 555,111.186,015,274.84-3,925.41 0.00 14,153.68 17,156.86 90.77 3,978.44 -927.08 -14,208.81284.16 555,055.936,015,288.23-3,924.64 0.00 14,208.81 3/21/2025 4:41:21PM COMPASS 5000.17 Build 04 Page 8 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt E Pad Standard Proposal Report Well: Wellbore: Plan: MPU E-48 MPU E-48 Survey Calculation Method:Minimum Curvature E-48 as staked @ 53.80usft Design:MPU E-48 wp07 Database:Alaska MD Reference:E-48 as staked @ 53.80usft North Reference: Well Plan: MPU E-48 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 -3,924.09 Vert Section 17,200.00 90.71 3,977.89 -917.01 -14,250.75282.86 555,013.906,015,297.91-3,924.09 3.00 14,250.75 17,300.00 90.57 3,976.77 -897.31 -14,348.77279.87 554,915.716,015,316.70-3,922.97 3.00 14,348.77 17,400.00 90.43 3,975.90 -882.76 -14,447.69276.87 554,816.666,015,330.33-3,922.10 3.00 14,447.69 17,500.00 90.28 3,975.28 -873.40 -14,547.24273.87 554,717.046,015,338.76-3,921.48 3.00 14,547.24 17,600.00 90.14 3,974.92 -869.26 -14,647.14270.88 554,617.126,015,341.97-3,921.12 3.00 14,647.14 17,695.96 90.00 3,974.80 -870.20 -14,743.08268.00 554,521.206,015,340.14-3,921.00 3.00 14,743.08 17,700.00 90.00 3,974.80 -870.34 -14,747.12268.00 554,517.166,015,339.96-3,921.00 0.00 14,747.12 17,800.00 90.00 3,974.80 -873.83 -14,847.06268.00 554,417.266,015,335.54-3,921.00 0.00 14,847.06 17,900.00 90.00 3,974.80 -877.32 -14,947.00268.00 554,317.376,015,331.12-3,921.00 0.00 14,947.00 18,000.00 90.00 3,974.80 -880.81 -15,046.94268.00 554,217.486,015,326.70-3,921.00 0.00 15,046.94 18,100.00 90.00 3,974.80 -884.30 -15,146.88268.00 554,117.596,015,322.29-3,921.00 0.00 15,146.88 18,200.00 90.00 3,974.80 -887.79 -15,246.82268.00 554,017.696,015,317.87-3,921.00 0.00 15,246.82 18,300.00 90.00 3,974.80 -891.28 -15,346.76268.00 553,917.806,015,313.45-3,921.00 0.00 15,346.76 18,400.00 90.00 3,974.80 -894.77 -15,446.70268.00 553,817.916,015,309.03-3,921.00 0.00 15,446.70 18,445.96 90.00 3,974.80 -896.37 -15,492.63268.00 553,772.006,015,307.00-3,921.00 0.00 15,492.63 18,500.00 90.26 3,974.68 -899.04 -15,546.60266.34 553,718.066,015,303.83-3,920.88 3.10 15,546.60 18,600.00 90.73 3,973.82 -908.08 -15,646.18263.28 553,618.586,015,293.87-3,920.02 3.10 15,646.18 18,700.00 91.20 3,972.13 -922.43 -15,745.11260.22 553,519.796,015,278.60-3,918.33 3.10 15,745.11 18,800.00 91.67 3,969.63 -942.04 -15,843.13257.15 553,421.976,015,258.08-3,915.83 3.10 15,843.13 18,865.68 91.97 3,967.54 -957.76 -15,906.86255.14 553,358.396,015,241.77-3,913.74 3.10 15,906.86 18,900.00 91.97 3,966.36 -966.56 -15,940.01255.14 553,325.336,015,232.66-3,912.56 0.00 15,940.01 18,963.22 91.97 3,964.18 -982.77 -16,001.08255.14 553,264.426,015,215.89-3,910.38 0.00 16,001.08 19,000.00 91.83 3,962.96 -991.85 -16,036.70256.27 553,228.896,015,206.48-3,909.16 3.10 16,036.70 19,100.00 91.42 3,960.12 -1,012.96 -16,134.39259.34 553,131.406,015,184.47-3,906.32 3.10 16,134.39 19,200.00 91.02 3,957.99 -1,028.80 -16,233.09262.42 553,032.866,015,167.71-3,904.19 3.10 16,233.09 19,300.00 90.61 3,956.58 -1,039.34 -16,332.52265.49 552,933.556,015,156.25-3,902.78 3.10 16,332.52 19,400.00 90.19 3,955.88 -1,044.52 -16,432.37268.56 552,833.766,015,150.14-3,902.08 3.10 16,432.37 19,446.80 90.00 3,955.80 -1,045.11 -16,479.16270.00 552,786.986,015,149.12-3,902.00 3.10 16,479.16 19,500.00 90.00 3,955.80 -1,045.11 -16,532.36270.00 552,733.796,015,148.62-3,902.00 0.00 16,532.36 19,566.80 90.00 3,955.80 -1,045.11 -16,599.16270.00 552,667.006,015,148.00-3,902.00 0.00 16,599.16 Total Depth : 19566.8' MD, 3955.8' TVD 3/21/2025 4:41:21PM COMPASS 5000.17 Build 04 Page 9 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt E Pad Standard Proposal Report Well: Wellbore: Plan: MPU E-48 MPU E-48 Survey Calculation Method:Minimum Curvature E-48 as staked @ 53.80usft Design:MPU E-48 wp07 Database:Alaska MD Reference:E-48 as staked @ 53.80usft North Reference: Well Plan: MPU E-48 True Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Targets Dip Angle (°) Dip Dir. (°) MPU E-48 wp07 tgt13 3,974.80 6,015,307.00 553,772.00-896.37 -15,492.630.00 0.00 - plan hits target center - Point MPU E-48 wp01 tgt6 4,160.80 6,014,221.18 560,047.07-2,040.59 -9,227.330.00 0.00 - plan hits target center - Point MPU E-48 wp07 tgt12 3,976.80 6,015,346.00 554,740.00-866.37 -14,524.210.00 0.00 - plan misses target center by 8.81usft at 17477.72usft MD (3975.40 TVD, -875.03 N, -14525.02 E) - Point MPU E-48 wp01 tgt9 3,975.80 6,014,649.43 557,201.19-1,585.86 -12,069.370.00 0.00 - plan misses target center by 47.04usft at 14886.44usft MD (3975.80 TVD, -1632.52 N, -12075.35 E) - Point MPU E-48 wp06 tgt14 3,963.80 6,015,157.00 553,093.00-1,040.07 -16,173.050.00 0.00 - plan misses target center by 20.52usft at 19142.39usft MD (3959.13 TVD, -1020.32 N, -16176.12 E) - Point MPU E-48 wp01 tgt7 4,073.80 6,014,226.43 559,125.38-2,026.77 -10,149.020.00 0.00 - plan hits target center - Point MPU E-48 wp06 tgt15 3,955.80 6,015,148.00 552,667.00-1,045.11 -16,599.160.00 0.00 - plan hits target center - Point MPU E-48 wp06 tgt10 3,983.80 6,015,183.00 555,483.00-1,036.29 -13,782.690.00 0.00 - plan hits target center - Point MPU E-48 wp01 tgt5 4,175.80 6,014,259.68 560,908.38-2,010.09 -8,365.620.00 0.00 - plan hits target center - Point MPU E-48 wp01 tgt4 4,163.80 6,014,232.68 561,687.88-2,044.34 -7,586.330.00 0.00 - plan hits target center - Point MPU E-48 wp06 tgt09 3,993.80 6,014,841.00 556,185.00-1,384.83 -13,083.830.00 0.00 - plan hits target center - Point MPU E-48 wp01 tgt1 4,243.80 6,013,747.00 562,952.00-2,541.80 -6,326.660.00 0.00 - plan hits target center - Point MPU E-48 wp01 tgt2 4,235.80 6,013,894.18 562,639.82-2,391.71 -6,637.480.00 0.00 - plan hits target center - Point Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 13-3/8" x 17 1/2" Surface Casing2,558.403,564.34 13-3/8 17-1/2 9-5/8" x 12 1/4" Intermediate Casing4,243.938,982.00 9-5/8 12-1/4 5-1/2" x 8 1/2" Production Casing3,955.8019,566.80 5-1/2 8-1/2 3/21/2025 4:41:21PM COMPASS 5000.17 Build 04 Page 10 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt E Pad Standard Proposal Report Well: Wellbore: Plan: MPU E-48 MPU E-48 Survey Calculation Method:Minimum Curvature E-48 as staked @ 53.80usft Design:MPU E-48 wp07 Database:Alaska MD Reference:E-48 as staked @ 53.80usft North Reference: Well Plan: MPU E-48 True Measured Depth (usft) Vertical Depth (usft) Dip Direction (°)Name Lithology Dip (°) Formations Vertical Depth SS 6,920.28 3,754.80 UG_LA3 8,588.46 4,213.80 SB_NA 1,905.34 1,781.80 Base Permafrost 3,105.44 2,394.80 SV1 7,602.95 3,993.80 UG_MB 1,100.37 1,088.80 SV6 8,937.17 4,240.80 SB_NB Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 325.00 325.00 0.00 0.00 Start Dir 2º/100' : 325' MD, 325'TVD 600.00 599.58 -3.41 -12.74 Start Dir 2.5º/100' : 600' MD, 599.58'TVD 1,100.00 1,088.44 -46.82 -102.94 Start Dir 3º/100' : 1100' MD, 1088.44'TVD 2,811.60 2,290.04 -596.59 -1,099.22 End Dir : 2811.6' MD, 2290.04' TVD 7,339.54 3,904.27 -2,637.37 -4,804.86 Start Dir 4º/100' : 7339.54' MD, 3904.27'TVD 8,730.18 4,226.36 -2,650.22 -6,102.07 End Dir : 8730.18' MD, 4226.36' TVD 8,982.10 4,243.93 -2,540.96 -6,328.38 Begin Geosteering 19,566.80 3,955.80 -1,045.11 -16,599.16 Total Depth : 19566.8' MD, 3955.8' TVD 3/21/2025 4:41:21PM COMPASS 5000.17 Build 04 Page 11 Clearance SummaryAnticollision Report21 March, 2025Hilcorp Alaska, LLCMilne PointM Pt E PadPlan: MPU E-48MPU E-48MPU E-48 wp07Reference Design: M Pt E Pad - Plan: MPU E-48 - MPU E-48 - MPU E-48 wp07Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Well Coordinates: 6,016,347.25 N, 569,254.16 E (70° 27' 18.07" N, 149° 26' 05.44" W)Datum Height: E-48 as staked @ 53.80usftScan Range: 0.00 to 19,566.80 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.17 Build: 04Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftNO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type:Scan Type:25.00 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU E-48 - MPU E-48 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 0.00 to 19,566.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt E Pad - Plan: MPU E-48 - MPU E-48 - MPU E-48 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningEX KAVEAR32-25KAVEAR32-25 - KAVEAR32-25 - KAVEARAK PT 32-2 132.99 801.25 115.78 782.90 7.727801.25Centre Distance Pass - KAVEAR32-25 - KAVEAR32-25 - KAVEARAK PT 32-2 133.39 850.00 115.13 830.94 7.306850.00Ellipse Separation Pass - KAVEAR32-25 - KAVEAR32-25 - KAVEARAK PT 32-2 149.95 1,075.00 126.90 1,049.77 6.5061,075.00Clearance Factor Pass - M Pt E PadMPE-02 - MPE-02 - MPE-02 256.14 766.02 246.25 764.62 25.892766.02Centre Distance Pass - MPE-02 - MPE-02 - MPE-02 256.31 800.00 246.01 796.99 24.874800.00Ellipse Separation Pass - MPE-02 - MPE-02 - MPE-02 284.50 1,100.00 270.70 1,062.38 20.6101,100.00Clearance Factor Pass - MPE-04 - MPE-04 - MPE-04 146.88 789.86 139.02 798.25 18.686789.86Centre Distance Pass - MPE-04 - MPE-04 - MPE-04 146.92 800.00 138.97 808.01 18.481800.00Ellipse Separation Pass - MPE-04 - MPE-04 - MPE-04 155.95 925.00 146.91 924.45 17.261925.00Clearance Factor Pass - MPE-05 - MPE-05 - MPE-05 93.70 650.00 87.11 657.54 14.207650.00Centre Distance Pass - MPE-05 - MPE-05 - MPE-05 93.84 675.00 87.02 682.39 13.769675.00Ellipse Separation Pass - MPE-05 - MPE-05 - MPE-05 103.07 825.00 94.94 829.58 12.676825.00Clearance Factor Pass - MPE-06 - MPE-06 - MPE-06 23.14 532.00 16.09 536.05 3.280532.00Centre Distance Pass - MPE-06 - MPE-06 - MPE-06 23.23 550.00 15.95 553.94 3.193550.00Ellipse Separation Pass - MPE-06 - MPE-06 - MPE-06 23.68 575.00 16.10 578.73 3.125575.00Clearance Factor Pass - MPE-07 - MPE-07 - MPE-07 34.87 320.43 30.37 324.63 7.743320.43Centre Distance Pass - MPE-07 - MPE-07 - MPE-07 35.31 400.00 29.86 404.17 6.475400.00Ellipse Separation Pass - MPE-07 - MPE-07 - MPE-07 43.87 625.00 35.69 628.67 5.363625.00Clearance Factor Pass - MPE-09 - MPE-09 - MPE-09 48.96 1,075.00 38.63 1,063.55 4.7361,075.00Centre Distance Pass - MPE-09 - MPE-09 - MPE-09 48.96 1,076.12 38.62 1,064.57 4.7321,076.12Clearance Factor Pass - MPE-09 - MPE-09PB1 - MPE-09PB1 48.96 1,075.00 38.63 1,063.55 4.7361,075.00Centre Distance Pass - MPE-09 - MPE-09PB1 - MPE-09PB1 48.96 1,076.12 38.62 1,064.57 4.7321,076.12Clearance Factor Pass - MPE-10 - MPE-10 - MPE-10 115.84 1,204.72 104.11 1,206.75 9.8771,204.72Ellipse Separation Pass - MPE-10 - MPE-10 - MPE-10 116.41 1,225.00 104.50 1,223.78 9.7741,225.00Clearance Factor Pass - MPE-11 - MPE-11 - MPE-11 92.86 1,154.83 81.70 1,133.44 8.3221,154.83Ellipse Separation Pass - MPE-11 - MPE-11 - MPE-11 94.71 1,200.00 83.14 1,173.51 8.1891,200.00Clearance Factor Pass - 21 March, 2025 - 16:49COMPASSPage 2 of 15 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU E-48 - MPU E-48 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 0.00 to 19,566.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt E Pad - Plan: MPU E-48 - MPU E-48 - MPU E-48 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPE-12 - MPE-12 - MPE-12 153.07 545.67 147.33 555.32 26.667545.67Centre Distance Pass - MPE-12 - MPE-12 - MPE-12 153.18 575.00 147.30 584.54 26.044575.00Ellipse Separation Pass - MPE-12 - MPE-12 - MPE-12 170.99 825.00 163.59 823.41 23.099825.00Clearance Factor Pass - MPE-13 - MPE-13 - MPE-13 61.06 1,262.05 48.82 1,236.94 4.9851,262.05Ellipse Separation Pass - MPE-13 - MPE-13 - MPE-13 61.26 1,275.00 48.88 1,248.84 4.9481,275.00Clearance Factor Pass - MPE-13 - MPE-13A - MPE-13A 61.06 1,262.05 48.82 1,236.94 4.9851,262.05Ellipse Separation Pass - MPE-13 - MPE-13A - MPE-13A 61.26 1,275.00 48.88 1,248.84 4.9481,275.00Clearance Factor Pass - MPE-13 - MPE-13APB1 - MPE-13APB1 61.06 1,262.05 48.82 1,236.94 4.9851,262.05Ellipse Separation Pass - MPE-13 - MPE-13APB1 - MPE-13APB1 61.26 1,275.00 48.88 1,248.84 4.9481,275.00Clearance Factor Pass - MPE-13 - MPE-13APB2 - MPE-13APB2 61.06 1,262.05 48.82 1,236.94 4.9851,262.05Ellipse Separation Pass - MPE-13 - MPE-13APB2 - MPE-13APB2 61.26 1,275.00 48.88 1,248.84 4.9481,275.00Clearance Factor Pass - MPE-13 - MPE-13B - MPE-13B 61.06 1,262.05 48.97 1,242.11 5.0501,262.05Ellipse Separation Pass - MPE-13 - MPE-13B - MPE-13B 61.26 1,275.00 49.03 1,254.01 5.0111,275.00Clearance Factor Pass - MPE-14 - MPE-14 - MPE-14 196.55 1,059.03 188.28 1,044.00 23.7631,059.03Centre Distance Pass - MPE-14 - MPE-14 - MPE-14 196.64 1,075.00 188.25 1,057.99 23.4371,075.00Ellipse Separation Pass - MPE-14 - MPE-14 - MPE-14 214.64 1,275.00 204.70 1,233.83 21.5951,275.00Clearance Factor Pass - MPE-14 - MPE-14A - MPE-14A 196.55 1,059.03 188.28 1,044.00 23.7641,059.03Centre Distance Pass - MPE-14 - MPE-14A - MPE-14A 196.64 1,075.00 188.25 1,057.99 23.4371,075.00Ellipse Separation Pass - MPE-14 - MPE-14A - MPE-14A 214.64 1,275.00 204.70 1,233.83 21.5951,275.00Clearance Factor Pass - MPE-14 - MPE-14APB1 - MPE-14APB1 196.55 1,059.03 188.28 1,044.00 23.7641,059.03Centre Distance Pass - MPE-14 - MPE-14APB1 - MPE-14APB1 196.64 1,075.00 188.25 1,057.99 23.4371,075.00Ellipse Separation Pass - MPE-14 - MPE-14APB1 - MPE-14APB1 214.64 1,275.00 204.70 1,233.83 21.5951,275.00Clearance Factor Pass - MPE-15 - MPE-15 - MPE-15 223.29 1,359.28 202.02 1,343.33 10.4951,359.28Centre Distance Pass - MPE-15 - MPE-15 - MPE-15 225.15 1,525.00 200.96 1,515.74 9.3081,525.00Ellipse Separation Pass - MPE-15 - MPE-15 - MPE-15 232.68 1,775.00 204.75 1,772.72 8.3301,775.00Clearance Factor Pass - MPE-16 - MPE-16 - MPE-16 62.00 409.50 57.63 410.66 14.201409.50Centre Distance Pass - MPE-16 - MPE-16 - MPE-16 62.22 450.00 57.51 451.04 13.203450.00Ellipse Separation Pass - MPE-16 - MPE-16 - MPE-16 71.17 625.00 64.94 623.97 11.428625.00Clearance Factor Pass - MPE-17 - MPE-17 - MPE-17 184.43 33.70 182.79 33.06 112.46233.70Ellipse Separation Pass - MPE-17 - MPE-17 - MPE-17 253.99 875.00 245.61 836.02 30.310875.00Clearance Factor Pass - 21 March, 2025 - 16:49COMPASSPage 3 of 15 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU E-48 - MPU E-48 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 0.00 to 19,566.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt E Pad - Plan: MPU E-48 - MPU E-48 - MPU E-48 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPE-18 - MPE-18 - MPE-18 26.42 1,489.20 15.06 1,460.87 2.3261,489.20Ellipse Separation Pass - MPE-18 - MPE-18 - MPE-18 26.88 1,500.00 15.20 1,470.32 2.3011,500.00Clearance Factor Pass - MPE-19 - MPE-19 - MPE-19 114.40 1,061.40 106.13 1,083.44 13.8291,061.40Centre Distance Pass - MPE-19 - MPE-19 - MPE-19 114.43 1,075.00 106.07 1,097.34 13.6811,075.00Ellipse Separation Pass - MPE-19 - MPE-19 - MPE-19 124.41 1,250.00 114.53 1,271.45 12.5951,250.00Clearance Factor Pass - MPE-19 - MPU E-19A - MPU E-19A 114.40 1,061.40 106.13 1,083.44 13.8291,061.40Centre Distance Pass - MPE-19 - MPU E-19A - MPU E-19A 114.43 1,075.00 106.07 1,097.34 13.6811,075.00Ellipse Separation Pass - MPE-19 - MPU E-19A - MPU E-19A 124.41 1,250.00 114.54 1,271.45 12.6081,250.00Clearance Factor Pass - MPE-20 - MPE-20 - MPE-20 132.50 1,324.98 121.43 1,308.06 11.9731,324.98Centre Distance Pass - MPE-20 - MPE-20 - MPE-20 132.69 1,350.00 121.41 1,332.62 11.7621,350.00Ellipse Separation Pass - MPE-20 - MPE-20 - MPE-20 135.95 1,425.00 124.08 1,406.02 11.4591,425.00Clearance Factor Pass - MPE-20 - MPE-20A - MPE-20A 132.50 1,324.98 121.43 1,312.81 11.9721,324.98Centre Distance Pass - MPE-20 - MPE-20A - MPE-20A 132.69 1,350.00 121.41 1,337.37 11.7611,350.00Ellipse Separation Pass - MPE-20 - MPE-20A - MPE-20A 4,199.78 10,375.00 3,769.07 9,878.00 9.75110,375.00Clearance Factor Pass - MPE-20 - MPE-20AL1 - MPE-20AL1 132.50 1,324.98 121.43 1,312.81 11.9721,324.98Centre Distance Pass - MPE-20 - MPE-20AL1 - MPE-20AL1 132.69 1,350.00 121.41 1,337.37 11.7611,350.00Ellipse Separation Pass - MPE-20 - MPE-20AL1 - MPE-20AL1 4,508.86 11,700.00 4,079.04 11,078.00 10.49011,700.00Clearance Factor Pass - MPE-20 - MPE-20AL1PB1 - MPE-20AL1PB1 132.50 1,324.98 121.43 1,312.81 11.9721,324.98Centre Distance Pass - MPE-20 - MPE-20AL1PB1 - MPE-20AL1PB1 132.69 1,350.00 121.41 1,337.37 11.7611,350.00Ellipse Separation Pass - MPE-20 - MPE-20AL1PB1 - MPE-20AL1PB1 135.95 1,425.00 124.08 1,410.77 11.4571,425.00Clearance Factor Pass - MPE-21 - MPE-21 - MPE-21 4.65 338.08 1.95 341.29 1.722338.08Centre Distance Pass - MPE-21 - MPE-21 - MPE-21 4.87 400.00 1.81 403.19 1.588400.00Clearance Factor Pass - MPE-22 - MPE-22 - MPE-22 63.06 1,243.72 51.07 1,236.80 5.2581,243.72Ellipse Separation Pass - MPE-22 - MPE-22 - MPE-22 63.14 1,250.00 51.09 1,242.35 5.2411,250.00Clearance Factor Pass - MPE-23 - MPE-23 - MPE-23 95.09 33.70 93.44 33.96 57.90233.70Centre Distance Pass - MPE-23 - MPE-23 - MPE-23 96.82 350.00 92.97 349.72 25.116350.00Ellipse Separation Pass - MPE-23 - MPE-23 - MPE-23 130.22 875.00 121.76 869.91 15.410875.00Clearance Factor Pass - MPE-24 - MPE-24 - MPE-24 201.39 200.00 199.17 203.31 90.642200.00Centre Distance Pass - MPE-24 - MPE-24 - MPE-24 201.65 275.00 198.96 276.89 74.829275.00Ellipse Separation Pass - MPE-24 - MPE-24 - MPE-24 333.84 1,700.00 317.42 1,560.99 20.3251,700.00Clearance Factor Pass - 21 March, 2025 - 16:49COMPASSPage 4 of 15 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU E-48 - MPU E-48 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 0.00 to 19,566.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt E Pad - Plan: MPU E-48 - MPU E-48 - MPU E-48 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPE-24 - MPE-24A - MPE-24A 201.39 200.00 199.28 199.91 95.334200.00Centre Distance Pass - MPE-24 - MPE-24A - MPE-24A 201.65 275.00 199.07 273.49 77.994275.00Ellipse Separation Pass - MPE-24 - MPE-24A - MPE-24A 333.84 1,700.00 317.52 1,557.59 20.4581,700.00Clearance Factor Pass - MPE-24 - MPE-24AL1 - MPE-24AL1 201.39 200.00 199.28 199.91 95.334200.00Centre Distance Pass - MPE-24 - MPE-24AL1 - MPE-24AL1 201.65 275.00 199.07 273.49 77.994275.00Ellipse Separation Pass - MPE-24 - MPE-24AL1 - MPE-24AL1 333.84 1,700.00 317.51 1,557.59 20.4431,700.00Clearance Factor Pass - MPE-25 - MPE-25 - MPE-25 86.80 1,315.05 76.37 1,276.49 8.3221,315.05Centre Distance Pass - MPE-25 - MPE-25 - MPE-25 87.12 1,350.00 76.26 1,309.88 8.0161,350.00Ellipse Separation Pass - MPE-25 - MPE-25 - MPE-25 96.09 1,500.00 82.97 1,453.76 7.3251,500.00Clearance Factor Pass - MPE-25 - MPE-25A - MPE-25A 86.80 1,315.05 76.37 1,281.44 8.3221,315.05Centre Distance Pass - MPE-25 - MPE-25A - MPE-25A 87.12 1,350.00 76.25 1,314.83 8.0151,350.00Ellipse Separation Pass - MPE-25 - MPE-25A - MPE-25A 96.09 1,500.00 82.96 1,458.71 7.3211,500.00Clearance Factor Pass - MPE-25 - MPE-25L1 - MPE-25L1 86.80 1,315.05 76.37 1,276.49 8.3221,315.05Centre Distance Pass - MPE-25 - MPE-25L1 - MPE-25L1 87.12 1,350.00 76.25 1,309.88 8.0161,350.00Ellipse Separation Pass - MPE-25 - MPE-25L1 - MPE-25L1 96.09 1,500.00 82.97 1,453.76 7.3241,500.00Clearance Factor Pass - MPE-25 - MPE-25L1PB1 - MPE-25L1PB1 86.80 1,315.05 76.37 1,276.49 8.3221,315.05Centre Distance Pass - MPE-25 - MPE-25L1PB1 - MPE-25L1PB1 87.12 1,350.00 76.25 1,309.88 8.0161,350.00Ellipse Separation Pass - MPE-25 - MPE-25L1PB1 - MPE-25L1PB1 96.09 1,500.00 82.97 1,453.76 7.3241,500.00Clearance Factor Pass - MPE-25 - MPE-25PB1 - MPE-25PB1 86.80 1,315.05 76.11 1,276.49 8.1161,315.05Centre Distance Pass - MPE-25 - MPE-25PB1 - MPE-25PB1 87.12 1,350.00 75.99 1,309.88 7.8251,350.00Ellipse Separation Pass - MPE-25 - MPE-25PB1 - MPE-25PB1 96.09 1,500.00 82.70 1,453.76 7.1791,500.00Clearance Factor Pass - MPE-25 - MPE-25PB2 - MPE-25PB2 86.80 1,315.05 76.37 1,276.49 8.3221,315.05Centre Distance Pass - MPE-25 - MPE-25PB2 - MPE-25PB2 87.12 1,350.00 76.26 1,309.88 8.0161,350.00Ellipse Separation Pass - MPE-25 - MPE-25PB2 - MPE-25PB2 96.09 1,500.00 82.97 1,453.76 7.3251,500.00Clearance Factor Pass - MPE-25 - MPE-25PB3 - MPE-25PB3 86.80 1,315.05 76.37 1,276.49 8.3221,315.05Centre Distance Pass - MPE-25 - MPE-25PB3 - MPE-25PB3 87.12 1,350.00 76.26 1,309.88 8.0161,350.00Ellipse Separation Pass - MPE-25 - MPE-25PB3 - MPE-25PB3 96.09 1,500.00 82.97 1,453.76 7.3251,500.00Clearance Factor Pass - MPE-26 - MPE-26 - MPE-26 29.07 1,403.05 17.27 1,370.25 2.4621,403.05Clearance Factor Pass - MPE-28 - MPE-28 - MPE-28211.3311,125.00-25.7911,040.760.89111,125.00Clearance FactorFAIL - MPE-28 - MPE-28 - MPE-28208.1011,261.05-24.0611,175.530.89611,261.05Centre DistanceFAIL - 21 March, 2025 - 16:49COMPASSPage 5 of 15 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU E-48 - MPU E-48 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 0.00 to 19,566.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt E Pad - Plan: MPU E-48 - MPU E-48 - MPU E-48 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPE-29 - MPE-29 - MPE-29 108.14 1,468.62 97.27 1,408.70 9.9471,468.62Centre Distance Pass - MPE-29 - MPE-29 - MPE-29 108.15 1,475.00 97.24 1,414.60 9.9141,475.00Ellipse Separation Pass - MPE-29 - MPE-29 - MPE-29 150.15 1,800.00 133.29 1,709.76 8.9081,800.00Clearance Factor Pass - MPE-29 - MPE-29PB1 - MPE-29PB1 108.14 1,468.62 97.27 1,408.70 9.9471,468.62Centre Distance Pass - MPE-29 - MPE-29PB1 - MPE-29PB1 108.15 1,475.00 97.24 1,414.60 9.9141,475.00Ellipse Separation Pass - MPE-29 - MPE-29PB1 - MPE-29PB1 150.15 1,800.00 133.29 1,709.76 8.9071,800.00Clearance Factor Pass - MPE-30 - MPE-30 - MPE-30 48.53 541.79 44.35 544.12 11.623541.79Centre Distance Pass - MPE-30 - MPE-30 - MPE-30 48.54 550.00 44.31 552.18 11.472550.00Ellipse Separation Pass - MPE-30 - MPE-30 - MPE-30 54.26 700.00 48.97 700.42 10.267700.00Clearance Factor Pass - MPE-30 - MPE-30A - MPE-30A 48.53 541.79 44.35 544.12 11.623541.79Centre Distance Pass - MPE-30 - MPE-30A - MPE-30A 48.54 550.00 44.31 552.18 11.472550.00Ellipse Separation Pass - MPE-30 - MPE-30A - MPE-30A 54.26 700.00 48.97 700.42 10.266700.00Clearance Factor Pass - MPE-30 - MPE-30AL1 - MPE-30AL1 48.53 541.79 44.35 544.12 11.623541.79Centre Distance Pass - MPE-30 - MPE-30AL1 - MPE-30AL1 48.54 550.00 44.31 552.18 11.472550.00Ellipse Separation Pass - MPE-30 - MPE-30AL1 - MPE-30AL1 54.26 700.00 48.97 700.42 10.267700.00Clearance Factor Pass - MPE-30 - MPE-30AL1PB1 - MPE-30AL1PB1 48.53 541.79 44.35 544.12 11.623541.79Centre Distance Pass - MPE-30 - MPE-30AL1PB1 - MPE-30AL1PB1 48.54 550.00 44.31 552.18 11.472550.00Ellipse Separation Pass - MPE-30 - MPE-30AL1PB1 - MPE-30AL1PB1 54.26 700.00 48.97 700.42 10.266700.00Clearance Factor Pass - MPE-30 - MPE-30APB1 - MPE-30APB1 48.53 541.79 44.35 544.12 11.623541.79Centre Distance Pass - MPE-30 - MPE-30APB1 - MPE-30APB1 48.54 550.00 44.31 552.18 11.472550.00Ellipse Separation Pass - MPE-30 - MPE-30APB1 - MPE-30APB1 54.26 700.00 48.97 700.42 10.266700.00Clearance Factor Pass - MPE-31 - MPE-31 - MPE-31 189.39 576.12 181.60 577.76 24.322576.12Centre Distance Pass - MPE-31 - MPE-31 - MPE-31 189.49 600.00 181.41 600.45 23.456600.00Ellipse Separation Pass - MPE-31 - MPE-31 - MPE-31 198.88 750.00 189.08 738.04 20.291750.00Clearance Factor Pass - MPE-31 - MPE-31PB1 - MPE-31PB1 189.39 576.12 181.60 577.76 24.322576.12Centre Distance Pass - MPE-31 - MPE-31PB1 - MPE-31PB1 189.49 600.00 181.41 600.45 23.456600.00Ellipse Separation Pass - MPE-31 - MPE-31PB1 - MPE-31PB1 198.88 750.00 189.08 738.04 20.291750.00Clearance Factor Pass - MPE-32 - MPE-32 - MPE-32 223.47 768.04 215.52 768.21 28.105768.04Centre Distance Pass - MPE-32 - MPE-32 - MPE-32 223.48 775.00 215.49 775.06 27.986775.00Ellipse Separation Pass - MPE-32 - MPE-32 - MPE-32 238.37 1,025.00 229.00 1,012.05 25.4481,025.00Clearance Factor Pass - 21 March, 2025 - 16:49COMPASSPage 6 of 15 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU E-48 - MPU E-48 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 0.00 to 19,566.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt E Pad - Plan: MPU E-48 - MPU E-48 - MPU E-48 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPE-32 - MPE-32L1 - MPE-32L1 223.47 768.04 215.52 768.21 28.105768.04Centre Distance Pass - MPE-32 - MPE-32L1 - MPE-32L1 223.48 775.00 215.49 775.06 27.985775.00Ellipse Separation Pass - MPE-32 - MPE-32L1 - MPE-32L1 238.37 1,025.00 229.00 1,012.05 25.4461,025.00Clearance Factor Pass - MPE-32 - MPE-32PB1 - MPE-32PB1 223.47 768.04 215.52 768.21 28.105768.04Centre Distance Pass - MPE-32 - MPE-32PB1 - MPE-32PB1 223.48 775.00 215.49 775.06 27.986775.00Ellipse Separation Pass - MPE-32 - MPE-32PB1 - MPE-32PB1 238.37 1,025.00 229.00 1,012.05 25.4481,025.00Clearance Factor Pass - MPU E-36 - MPU E-36 - MPU E-36 244.59 33.70 242.96 28.23 149.63833.70Centre Distance Pass - MPU E-36 - MPU E-36 - MPU E-36 245.76 350.00 241.90 343.64 63.653350.00Ellipse Separation Pass - MPU E-36 - MPU E-36 - MPU E-36 282.36 875.00 274.00 845.34 33.752875.00Clearance Factor Pass - MPU E-36 - MPU E-36PB1 - MPU E-36PB1 244.59 33.70 242.96 28.23 149.63833.70Centre Distance Pass - MPU E-36 - MPU E-36PB1 - MPU E-36PB1 245.76 350.00 241.90 343.64 63.653350.00Ellipse Separation Pass - MPU E-36 - MPU E-36PB1 - MPU E-36PB1 282.36 875.00 274.00 845.34 33.752875.00Clearance Factor Pass - MPU E-37 - MPU E-37 - MPU E-37 214.14 33.70 212.50 28.35 131.17033.70Centre Distance Pass - MPU E-37 - MPU E-37 - MPU E-37 214.15 50.00 212.44 44.36 125.43850.00Ellipse Separation Pass - MPU E-37 - MPU E-37 - MPU E-37 267.05 950.00 259.93 931.08 37.515950.00Clearance Factor Pass - MPU E-37 - MPU E-37 PB1 - MPU E-37 PB1 214.14 33.70 212.50 28.35 131.17033.70Centre Distance Pass - MPU E-37 - MPU E-37 PB1 - MPU E-37 PB1 214.15 50.00 212.44 44.36 125.43850.00Ellipse Separation Pass - MPU E-37 - MPU E-37 PB1 - MPU E-37 PB1 267.05 950.00 259.93 931.08 37.516950.00Clearance Factor Pass - MPU E-38 - MPU E-38 - MPU E-38 223.02 834.95 216.98 840.49 36.946834.95Ellipse Separation Pass - MPU E-38 - MPU E-38 - MPU E-38 7,352.55 16,325.00 7,048.79 15,570.00 24.20516,325.00Clearance Factor Pass - MPU E-38 - MPU E-38PB1 - MPU E-38PB1 223.02 834.95 216.98 840.49 36.946834.95Ellipse Separation Pass - MPU E-38 - MPU E-38PB1 - MPU E-38PB1 4,647.68 6,650.00 4,493.13 7,178.00 30.0736,650.00Clearance Factor Pass - MPU E-38 - MPU E-38PB2 - MPU E-38PB2 223.02 834.95 216.98 840.49 36.946834.95Ellipse Separation Pass - MPU E-38 - MPU E-38PB2 - MPU E-38PB2 5,648.38 10,125.00 5,436.02 10,268.00 26.59810,125.00Clearance Factor Pass - MPU E-42 - MPU E-42 - MPU E-42 157.36 159.40 155.32 154.03 77.173159.40Centre Distance Pass - MPU E-42 - MPU E-42 - MPU E-42 157.45 300.00 154.66 294.20 56.268300.00Ellipse Separation Pass - MPU E-42 - MPU E-42 - MPU E-42 1,262.35 3,500.00 1,217.31 2,834.21 28.0243,500.00Clearance Factor Pass - MPU E-42 - MPU E-42L1 - MPU E-42L1 157.36 159.40 155.32 154.03 77.173159.40Centre Distance Pass - MPU E-42 - MPU E-42L1 - MPU E-42L1 157.45 300.00 154.66 294.20 56.268300.00Ellipse Separation Pass - MPU E-42 - MPU E-42L1 - MPU E-42L1 1,262.35 3,500.00 1,217.31 2,834.21 28.0243,500.00Clearance Factor Pass - 21 March, 2025 - 16:49COMPASSPage 7 of 15 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU E-48 - MPU E-48 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 0.00 to 19,566.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt E Pad - Plan: MPU E-48 - MPU E-48 - MPU E-48 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningM Pt G PadMPG-01 - MPG-01 - MPG-01 1,423.98 14,416.51 1,269.26 3,851.87 9.20414,416.51Centre Distance Pass - MPG-01 - MPG-01 - MPG-01 1,425.17 14,475.00 1,268.53 3,845.62 9.09814,475.00Ellipse Separation Pass - MPG-01 - MPG-01 - MPG-01 1,454.91 14,725.00 1,291.95 3,820.04 8.92814,725.00Clearance Factor Pass - MPG-02 - MPG-02 - MPG-02 1,090.26 12,250.00 855.93 4,918.81 4.65312,250.00Clearance Factor Pass - MPG-02 - MPG-02 - MPG-02 1,071.35 12,425.00 845.26 4,785.81 4.73912,425.00Ellipse Separation Pass - MPG-02 - MPG-02 - MPG-02 1,064.86 12,650.00 860.49 4,552.80 5.21012,650.00Centre Distance Pass - MPG-03 - MPG-03 - MPG-03 1,472.60 11,825.00 1,208.49 5,067.74 5.57611,825.00Clearance Factor Pass - MPG-03 - MPG-03 - MPG-03 1,279.35 12,700.00 1,092.93 4,393.92 6.86312,700.00Ellipse Separation Pass - MPG-03 - MPG-03 - MPG-03 1,260.42 13,220.42 1,125.46 4,014.06 9.33913,220.42Centre Distance Pass - MPG-03 - MPG-03A - MPG-03A 1,590.63 11,550.00 1,410.48 5,329.68 8.82911,550.00Clearance Factor Pass - MPG-03 - MPG-03A - MPG-03A 1,362.98 12,850.00 1,232.07 4,299.56 10.41212,850.00Ellipse Separation Pass - MPG-03 - MPG-03A - MPG-03A 1,350.80 13,327.80 1,246.25 3,971.03 12.92113,327.80Centre Distance Pass - MPG-04 - MPG-04 - MPG-04 994.08 14,800.00 843.76 3,804.07 6.61314,800.00Clearance Factor Pass - MPG-04 - MPG-04 - MPG-04 990.67 14,850.00 841.27 3,806.34 6.63114,850.00Ellipse Separation Pass - MPG-04 - MPG-04 - MPG-04 990.37 14,869.79 841.36 3,807.20 6.64614,869.79Centre Distance Pass - MPG-05 - MPG-05 - MPG-05 565.86 15,916.42 397.69 4,158.97 3.36515,916.42Centre Distance Pass - MPG-05 - MPG-05 - MPG-05 572.33 16,000.00 388.98 4,187.45 3.12216,000.00Ellipse Separation Pass - MPG-05 - MPG-05 - MPG-05 598.06 16,100.00 401.30 4,218.30 3.03916,100.00Clearance Factor Pass - MPG-06 - MPG-06 - MPG-06 473.75 12,025.00 301.17 5,249.72 2.74512,025.00Clearance Factor Pass - MPG-06 - MPG-06 - MPG-06 471.02 12,075.00 300.07 5,213.48 2.75512,075.00Ellipse Separation Pass - MPG-06 - MPG-06 - MPG-06 469.88 12,137.02 302.61 5,167.15 2.80912,137.02Centre Distance Pass - MPG-08 - MPG-08 - MPG-08 1,637.41 16,327.53 1,516.14 3,646.26 13.50216,327.53Ellipse Separation Pass - MPG-08 - MPG-08 - MPG-08 1,641.87 16,425.00 1,519.71 3,692.48 13.44116,425.00Clearance Factor Pass - MPG-08 - MPG-08A - MPG-08A 1,607.41 16,417.25 1,476.31 3,797.32 12.26116,417.25Centre Distance Pass - MPG-08 - MPG-08A - MPG-08A 1,607.44 16,425.00 1,476.20 3,801.53 12.24816,425.00Ellipse Separation Pass - MPG-08 - MPG-08A - MPG-08A 1,699.77 16,875.00 1,556.66 4,117.91 11.87716,875.00Clearance Factor Pass - MPG-10 - MPG-10 - MPG-10 1,425.90 15,684.80 1,348.00 3,275.03 18.30315,684.80Centre Distance Pass - MPG-10 - MPG-10 - MPG-10 1,456.08 16,350.00 1,343.28 3,813.83 12.90816,350.00Ellipse Separation Pass - MPG-10 - MPG-10 - MPG-10 1,655.60 17,025.00 1,512.53 4,149.25 11.57217,025.00Clearance Factor Pass - 21 March, 2025 - 16:49COMPASSPage 8 of 15 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU E-48 - MPU E-48 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 0.00 to 19,566.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt E Pad - Plan: MPU E-48 - MPU E-48 - MPU E-48 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPG-11 - MPG-11 - MPG-11 1,394.96 10,300.00 1,109.70 6,680.48 4.89010,300.00Clearance Factor Pass - MPG-11 - MPG-11 - MPG-11 1,366.05 10,475.00 1,093.16 6,595.12 5.00610,475.00Ellipse Separation Pass - MPG-11 - MPG-11 - MPG-11 1,362.22 10,585.27 1,101.21 6,453.64 5.21910,585.27Centre Distance Pass - MPG-12 - MPG-12 - MPG-12153.5715,325.0013.864,046.571.09915,325.00Clearance FactorPass - MPG-12 - MPG-12 - MPG-12151.3615,352.2319.014,049.721.14415,352.23Centre DistancePass - MPG-14 - MPG-14 - MPG-14 883.89 17,531.48 733.83 4,869.26 5.89017,531.48Centre Distance Pass - MPG-14 - MPG-14 - MPG-14 886.00 17,600.00 730.70 4,919.49 5.70517,600.00Ellipse Separation Pass - MPG-14 - MPG-14 - MPG-14 945.75 17,925.00 770.39 5,135.39 5.39317,925.00Clearance Factor Pass - MPG-14 - MPG-14L1 - MPG-14L1 883.89 17,531.48 733.83 4,869.26 5.89017,531.48Centre Distance Pass - MPG-14 - MPG-14L1 - MPG-14L1 886.00 17,600.00 730.70 4,919.49 5.70517,600.00Ellipse Separation Pass - MPG-14 - MPG-14L1 - MPG-14L1 945.75 17,925.00 770.39 5,135.39 5.39317,925.00Clearance Factor Pass - MPG-15 - MPG-15 - MPG-15 1,798.43 16,239.07 1,712.24 2,993.55 20.86616,239.07Centre Distance Pass - MPG-15 - MPG-15 - MPG-15 1,798.47 16,250.00 1,712.19 2,997.21 20.84516,250.00Ellipse Separation Pass - MPG-15 - MPG-15 - MPG-15 2,390.43 17,675.00 2,261.69 3,553.11 18.56817,675.00Clearance Factor Pass - MPG-16 - MPG-16 - MPG-16258.8612,300.0078.065,283.121.43212,300.00Clearance FactorPass - MPG-16 - MPG-16 - MPG-16256.1712,325.0078.025,260.221.43812,325.00Ellipse SeparationPass - MPG-16 - MPG-16 - MPG-16 249.55 12,452.35 93.86 5,148.56 1.60312,452.35Centre Distance Pass - MPG-16 - MPG-16L1 - MPG-16L1258.8612,300.0078.195,283.121.43312,300.00Clearance FactorPass - MPG-16 - MPG-16L1 - MPG-16L1256.1712,325.0078.145,260.221.43912,325.00Ellipse SeparationPass - MPG-16 - MPG-16L1 - MPG-16L1 249.55 12,452.35 93.99 5,148.56 1.60412,452.35Centre Distance Pass - MPG-16 - MPG-16PB1 - MPG-16PB1258.8612,300.0078.065,283.121.43212,300.00Clearance FactorPass - MPG-16 - MPG-16PB1 - MPG-16PB1256.1712,325.0078.025,260.221.43812,325.00Ellipse SeparationPass - MPG-16 - MPG-16PB1 - MPG-16PB1 249.55 12,452.35 93.86 5,148.56 1.60312,452.35Centre Distance Pass - MPG-16 - MPG-16PB2 - MPG-16PB2258.8612,300.0078.065,283.121.43212,300.00Clearance FactorPass - MPG-16 - MPG-16PB2 - MPG-16PB2256.1712,325.0078.025,260.221.43812,325.00Ellipse SeparationPass - MPG-16 - MPG-16PB2 - MPG-16PB2 249.55 12,452.35 93.86 5,148.56 1.60312,452.35Centre Distance Pass - MPG-17 - MPG-17 - MPG-17124.2919,093.93-59.346,159.170.67719,093.93Centre DistanceFAIL - MPG-17 - MPG-17 - MPG-17132.6019,150.00-114.076,187.790.53819,150.00Clearance FactorFAIL - MPG-18 - MPG-18 - MPG-18 326.83 13,525.00 159.38 5,121.18 1.95213,525.00Clearance Factor Pass - MPG-18 - MPG-18 - MPG-18 269.67 16,589.44 156.61 8,166.60 2.38516,589.44Centre Distance Pass - 21 March, 2025 - 16:49COMPASSPage 9 of 15 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU E-48 - MPU E-48 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 0.00 to 19,566.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt E Pad - Plan: MPU E-48 - MPU E-48 - MPU E-48 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPG-18 - MPG-18 - MPG-18 274.11 16,825.00 143.67 8,411.06 2.10216,825.00Ellipse Separation Pass - MPG-18 - MPG-18L1 - MPG-18L1 227.42 16,536.25 103.54 8,096.89 1.83616,536.25Centre Distance Pass - MPG-18 - MPG-18L1 - MPG-18L1 247.29 16,975.00 102.87 8,559.29 1.71216,975.00Clearance Factor Pass - MPG-18 - MPG-18PB1 - MPG-18PB1 326.83 13,525.00 159.38 5,121.18 1.95213,525.00Clearance Factor Pass - MPG-18 - MPG-18PB1 - MPG-18PB1 324.96 13,550.00 159.24 5,139.85 1.96113,550.00Ellipse Separation Pass - MPG-18 - MPG-18PB1 - MPG-18PB1 323.59 13,596.39 162.63 5,174.84 2.01013,596.39Centre Distance Pass - MPG-19 - MPG-19 - MPG-19 1,558.03 10,775.00 1,362.93 5,942.41 7.98610,775.00Clearance Factor Pass - MPG-19 - MPG-19 - MPG-19 1,298.01 12,475.00 1,193.05 4,486.42 12.36712,475.00Ellipse Separation Pass - MPG-19 - MPG-19 - MPG-19 1,290.30 12,684.65 1,196.82 4,331.37 13.80312,684.65Centre Distance Pass - M Pt H PadMPH-13 - MPH-13A - MPH-13A 1,152.62 9,685.62 977.05 9,142.00 6.5659,685.62Centre Distance Pass - MPH-13 - MPH-13A - MPH-13A 1,175.39 10,025.00 950.05 9,142.00 5.21610,025.00Ellipse Separation Pass - MPH-13 - MPH-13A - MPH-13A 1,251.34 10,425.00 990.54 9,142.00 4.79810,425.00Clearance Factor Pass - MPH-18 - MPH-18 - MPH-18 679.49 19,475.00 397.95 8,639.00 2.41319,475.00Clearance Factor Pass - MPH-18 - MPH-18 - MPH-18 666.34 19,550.00 393.79 8,639.00 2.44519,550.00Ellipse Separation Pass - MPH-18 - MPH-18 - MPH-18 664.52 19,566.80 394.49 8,639.00 2.46119,566.80Centre Distance Pass - MPH-18 - MPH-18L1 - MPH-18L1 654.06 19,475.00 369.26 8,595.00 2.29719,475.00Clearance Factor Pass - MPH-18 - MPH-18L1 - MPH-18L1 644.99 19,525.00 365.14 8,595.00 2.30519,525.00Ellipse Separation Pass - MPH-18 - MPH-18L1 - MPH-18L1 640.31 19,566.80 366.04 8,595.00 2.33519,566.80Centre Distance Pass - MPH-18 - MPH-18L2 - MPH-18L2 633.38 19,566.80 340.11 8,630.00 2.16019,566.80Clearance Factor Pass - M Pt I PadMPI-19 - MPI-19 - MPI-19 1,662.64 19,566.80 1,538.36 7,993.52 13.37819,566.80Clearance Factor Pass - MPI-19 - MPI-19L1 - MPI-19L1 1,651.12 19,566.80 1,526.78 7,938.56 13.27919,566.80Clearance Factor Pass - MPI-19 - MPI-19PB1 - MPI-19PB1 1,658.86 19,566.80 1,518.96 7,799.00 11.85719,566.80Clearance Factor Pass - MPI-19 - MPI-19PB2 - MPI-19PB2 1,636.65 19,566.80 1,511.14 8,046.52 13.04019,566.80Clearance Factor Pass - MPU I-20 - MPU I-20 - MPU I-20 823.79 19,566.80 696.60 9,359.01 6.47719,566.80Clearance Factor Pass - MPU I-21i - MPU I-21i - MPU I-21i 1,578.50 19,566.80 1,440.30 10,602.41 11.42119,566.80Clearance Factor Pass - MPU I-27 - MPU I-27 - MPU I-27 864.93 19,566.80 737.10 9,517.35 6.76619,566.80Clearance Factor Pass - MPU I-28i - MPU I-28 - MPU I-28i 1,612.63 19,566.80 1,495.78 9,428.48 13.80119,566.80Clearance Factor Pass - 21 March, 2025 - 16:49COMPASSPage 10 of 15 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU E-48 - MPU E-48 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 0.00 to 19,566.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt E Pad - Plan: MPU E-48 - MPU E-48 - MPU E-48 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPU I-28i - MPU I-28PB1 - MPU I-28PB1 1,672.79 19,566.80 1,539.06 9,625.54 12.50819,566.80Clearance Factor Pass - MPU I-35i - MPU I-35i - MPU I-35i 951.32 19,566.80 827.77 9,129.79 7.70019,566.80Clearance Factor Pass - MPU I-36 - MPU I-36 - MPU I-36 1,912.21 19,566.80 1,793.61 9,703.86 16.12419,566.80Clearance Factor Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB1 1,931.92 19,566.80 1,805.86 9,697.87 15.32419,566.80Clearance Factor Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB2 1,912.83 19,566.80 1,792.53 9,739.48 15.90119,566.80Clearance Factor Pass - M Pt J PadMPJ-01 - MPJ-01 - MPJ-01 1,069.89 19,566.80 931.23 3,900.37 7.71619,566.80Clearance Factor Pass - MPJ-01 - MPJ-01A - MPJ-01A 1,087.60 19,566.80 959.31 3,742.06 8.47819,566.80Clearance Factor Pass - MPJ-01 - MPJ-01AL1 - MPJ-01AL1 1,087.60 19,566.80 959.40 3,742.06 8.48319,566.80Clearance Factor Pass - MPJ-02 - MPJ-02 - MPJ-02 590.26 17,000.00 376.67 5,530.69 2.76417,000.00Clearance Factor Pass - MPJ-02 - MPJ-02 - MPJ-02 578.61 17,075.00 372.05 5,482.80 2.80117,075.00Ellipse Separation Pass - MPJ-02 - MPJ-02 - MPJ-02 572.38 17,175.00 379.55 5,422.23 2.96817,175.00Centre Distance Pass - MPJ-03 - MPJ-03 - MPJ-03 2,134.48 19,566.80 2,021.21 2,703.04 18.84619,566.80Clearance Factor Pass - MPJ-04 - MPJ-04 - MPJ-04 1,971.58 18,150.00 1,809.95 3,782.87 12.19818,150.00Clearance Factor Pass - MPJ-04 - MPJ-04 - MPJ-04 1,807.85 19,100.00 1,675.61 3,295.85 13.67119,100.00Ellipse Separation Pass - MPJ-04 - MPJ-04 - MPJ-04 1,807.28 19,136.53 1,676.20 3,284.71 13.78819,136.53Centre Distance Pass - MPJ-05 - MPJ-05 - MPJ-05 320.27 19,050.00 149.48 4,182.47 1.87519,050.00Clearance Factor Pass - MPJ-05 - MPJ-05 - MPJ-05 317.99 19,075.00 148.70 4,166.86 1.87819,075.00Ellipse Separation Pass - MPJ-05 - MPJ-05 - MPJ-05 315.78 19,131.28 151.72 4,133.94 1.92519,131.28Centre Distance Pass - MPJ-06 - MPJ-06 - MPJ-06 1,191.96 19,566.80 1,091.76 3,664.84 11.89519,566.80Clearance Factor Pass - MPJ-07 - MPJ-07 - MPJ-07 1,053.03 19,400.00 865.15 3,862.315.60519,400.00Clearance Factor Pass - MPJ-07 - MPJ-07 - MPJ-07 1,052.60 19,424.60 864.88 3,856.03 5.60719,424.60Ellipse Separation Pass - MPJ-08 - MPJ-08 - MPJ-08 1,403.70 19,566.80 1,319.89 3,298.63 16.74819,566.80Clearance Factor Pass - MPJ-08 - MPJ-08A - MPJ-08A 1,403.70 19,566.80 1,319.89 3,299.4316.74819,566.80Clearance Factor Pass - MPJ-09 - MPJ-09 - MPJ-09 1,988.64 19,566.80 1,916.30 2,712.40 27.48819,566.80Clearance Factor Pass - MPJ-09 - MPJ-09A - MPJ-09A 1,988.64 19,566.80 1,916.30 2,712.67 27.48919,566.80Clearance Factor Pass - MPJ-10 - MPJ-10 - MPJ-10 1,137.03 18,800.00 926.74 4,389.73 5.40718,800.00Clearance Factor Pass - MPJ-10 - MPJ-10 - MPJ-10 1,135.49 18,850.00 925.72 4,347.68 5.41318,850.00Ellipse Separation Pass - MPJ-10 - MPJ-10 - MPJ-10 1,135.48 18,854.67 925.77 4,343.79 5.41518,854.67Centre Distance Pass - 21 March, 2025 - 16:49COMPASSPage 11 of 15 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU E-48 - MPU E-48 wp07Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usftSite NameScan Range: 0.00 to 19,566.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt E Pad - Plan: MPU E-48 - MPU E-48 - MPU E-48 wp07MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-11 - MPJ-11 - MPJ-11 1,803.61 19,566.80 1,686.91 3,069.74 15.45619,566.80Clearance Factor Pass - MPJ-12 - MPJ-12 - MPJ-12 1,092.64 19,566.80 917.98 3,780.41 6.25619,566.80Clearance Factor Pass - MPJ-13 - MPJ-13 - MPJ-13 1,378.16 18,775.00 1,221.75 3,770.69 8.81118,775.00Clearance Factor Pass - MPJ-13 - MPJ-13 - MPJ-13 1,360.99 18,975.00 1,207.61 3,702.42 8.87318,975.00Ellipse Separation Pass - MPJ-13 - MPJ-13 - MPJ-13 1,360.46 19,040.28 1,208.79 3,677.05 8.97019,040.28Centre Distance Pass - MPJ-16 - MPJ-16 - MPJ-16 1,944.83 19,566.80 1,851.32 2,934.67 20.79719,566.80Clearance Factor Pass - MPJ-18 - MPJ-18 - MPJ-18 2,068.68 19,566.80 1,990.37 2,723.81 26.41519,566.80Clearance Factor Pass - MPJ-22 - MPJ-22 - MPJ-22 2,034.99 19,566.80 1,953.20 2,980.65 24.88219,566.80Clearance Factor Pass - MPJ-22 - MPJ-22PB1 - MPJ-22PB1 2,059.99 19,566.80 1,976.04 2,814.50 24.54019,566.80Clearance Factor Pass - MPJ-25 - MPJ-25 - MPJ-25 1,516.15 19,566.80 1,434.03 3,195.89 18.46419,566.80Clearance Factor Pass - MPJ-25 - MPJ-25PB1 - MPJ-25PB1 1,516.15 19,566.80 1,434.03 3,195.89 18.46419,566.80Clearance Factor Pass - MPU J-44 - MPU J-44 - MPU J-44 2,858.58 18,500.00 2,668.29 5,199.63 15.02218,500.00Clearance Factor Pass - MPU J-44 - MPU J-44 - MPU J-44 2,135.43 19,566.80 1,994.44 3,278.18 15.14619,566.80Ellipse Separation Pass - MPU J-44 - MPU J-44 PB1 - MPU J-44 PB1 2,858.58 18,500.00 2,668.22 5,199.63 15.01618,500.00Clearance Factor Pass - MPU J-44 - MPU J-44 PB1 - MPU J-44 PB1 2,135.43 19,566.80 1,994.44 3,278.18 15.14519,566.80Ellipse Separation Pass - MPU J-45 - MPU J-45 - MPU J-45 2,046.01 17,700.00 1,844.55 5,058.94 10.15617,700.00Clearance Factor Pass - MPU J-45 - MPU J-45 - MPU J-45 1,759.32 19,150.00 1,601.00 3,629.79 11.11319,150.00Ellipse Separation Pass - MPU J-45 - MPU J-45 - MPU J-45 1,759.01 19,175.00 1,601.46 3,620.29 11.16519,175.00Centre Distance Pass - MPU J-46 - MPU J-46 - MPU J-46 846.36 19,566.80 656.80 4,433.37 4.46519,566.80Clearance Factor Pass - MPU J-47 - MPU J-47 - MPU J-47 472.33 16,130.23 320.67 7,631.87 3.11416,130.23Centre Distance Pass - MPU J-47 - MPU J-47 - MPU J-47 517.61 19,350.00 311.09 4,718.73 2.50619,350.00Clearance Factor Pass - MPU J-47 - MPU J-47 - MPU J-47 516.67 19,398.55 310.67 4,672.62 2.50819,398.55Ellipse Separation Pass - Plan: MPU J-49 - MPU J-49 - MPU J-49 wp02 935.16 10,050.00 616.01 14,324.68 2.93010,050.00Clearance Factor Pass - Plan: MPU J-49 - MPU J-49 - MPU J-49 wp02 763.40 17,425.00 552.61 6,929.70 3.62217,425.00Ellipse Separation Pass - Plan: MPU J-49 - MPU J-49 - MPU J-49 wp02 763.26 17,448.02 552.69 6,906.68 3.62517,448.02Centre Distance Pass - 21 March, 2025 - 16:49COMPASSPage 12 of 15 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU E-48 - MPU E-48 wp07Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool33.70 1,700.00 MPU E-48 wp07 GYD_Quest GWD1,700.00 3,565.00 MPU E-48 wp07 3_MWD+IFR2+MS+Sag3,565.00 8,982.00 MPU E-48 wp07 3_MWD+IFR2+MS+Sag8,982.00 19,566.80 MPU E-48 wp07 GYD_Quest GWDEllipse 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.21 March, 2025 - 16:49COMPASSPage 13 of 15 0.001.503.004.50Separation Factor1500 3000 4500 6000 7500 9000 10500 12000 13500 15000 16500 18000 19500Measured DepthMPE-06MPE-18MPE-21MPE-26MPE-28MPG-05MPG-06MPG-12MPG-16MPG-16L1MPG-17MPG-18MPG-18L1MPG-18PB1MPH-18MPH-18L1MPH-18L2MPJ-02MPJ-05MPU J-46MPU J-47MPU J-49 wp02No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: MPU E-48 NAD 1927 (NADCON CONUS)Alaska Zone 0420.10+N/-S +E/-W Northing EastingLatittudeLongitude0.000.006016347.25569254.16 70° 27' 18.0654 N149° 26' 5.4375 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU E-48, True NorthVertical (TVD) Reference:E-48 as staked @ 53.80usftMeasured Depth Reference:E-48 as staked @ 53.80usftCalculation Method: Minimum CurvatureSURVEY PROGRAMDate: 2025-02-25T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 1700.00 MPU E-48 wp07 (MPU E-48) GYD_Quest GWD1700.00 3565.00 MPU E-48 wp07 (MPU E-48) 3_MWD+IFR2+MS+Sag3565.00 8982.00 MPU E-48 wp07 (MPU E-48) 3_MWD+IFR2+MS+Sag8982.00 19566.80 MPU E-48 wp07 (MPU E-48) GYD_Quest GWD0.0035.0070.00105.00140.00175.00Centre to Centre Separation (60.00 usft/in)1500 3000 4500 6000 7500 9000 10500 12000 13500 15000 16500 18000 19500Measured DepthMPG-12MPG-17NO GLOBAL FILTER: Using user defined selection & filtering criteria33.70 To 19566.80Project: Milne PointSite: M Pt E PadWell: Plan: MPU E-48Wellbore: MPU E-48Plan: MPU E-48 wp07CASING DETAILSTVD TVDSS MD Size Name2558.40 2504.60 3564.34 13-3/8 13-3/8" x 17 1/2" Surface Casing4243.93 4190.13 8982.00 9-5/8 9-5/8" x 12 1/4" Intermediate Casing3955.80 3902.00 19566.80 5-1/2 5-1/2" x 8 1/2" Production Casing Revised 7/2022 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 Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The 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 nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot 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 this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a 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 the Operator 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 all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. MPU E-48 225-034 MILNE POINT SCHRADER BLUFF OIL WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:MILNE PT UNIT E-48Initial Class/TypeDEV / PENDGeoArea890Unit11328On/Off ShoreOnProgramDEVWell bore segAnnular DisposalPTD#:2250340Field & Pool:MILNE POINT, SCHRADER BLFF OIL - 525140NA1Permit fee attachedYesADL025518 and ADL0259062Lease number appropriateYes3Unique well name and numberYesMILNE POINT, SCHRADER BLFF OIL - 525140 - governed by CO 477, 477.0054Well located in a defined poolYes5Well located proper distance from drilling unit boundaryNA6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes20" 129.5# X-52 grouted to 125' RKB ~ 80' GL18Conductor string providedYes13-3//8" L-80 68# to BOPF, 9-5/8" L-80 40# to SB reservoir19Surface casing protects all known USDWsYesFully cemented 13-3/8" X 16" OH surface casing.20CMT vol adequate to circulate on conductor & surf csgNoTOC in Int_1 @ 500' above Ugnu LA321CMT vol adequate to tie-in long string to surf csgYes9-5/8" intermediate casing cemented above all hydrocarbon zones22CMT will cover all known productive horizonsYes3 string design23Casing designs adequate for C, T, B & permafrostYesDoyon 14 rig has adequate tankage and good trucking support24Adequate tankage or reserve pitNAThis is a grassroots well.25If a re-drill, has a 10-403 for abandonment been approvedYesHalliburton collision scan shows two offset wells in reservoir to be shut in.26Adequate wellbore separation proposedYes16" Diverter with 2 x 22.5° bends27If diverter required, does it meet regulationsYesAll fluids overbalanced to expected pore pressure.28Drilling fluid program schematic & equip list adequateYes1 annular, 3 ram stack tested to 3000 psi.29BOPEs, do they meet regulationYes1 annular, 3 ram stack tested to 3000 psi.30BOPE press rating appropriate; test to (put psig in comments)YesDoyon 14 has 14 x 3-1/8" manual gate valves, 1 x 3-1/8" manual choke and 1 x 3-1/16" remote hydraulic choke.31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownNoMonitoring still required.33Is presence of H2S gas probableNAThis well is a Oil Development well.34Mechanical condition of wells within AOR verified (For service well only)YesH2S not anticipated from drilling of offset wells; however, rig will have H2S sensors and alarms.35Permit can be issued w/o hydrogen sulfide measuresYesReservoir pressures anticipated to be normal; multiple fault crossings expected36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprADDDate22-May-25ApprMGRDate28-Apr-25ApprADDDate22-May-25AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 5/23/2025