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Home My WebLink About225-032Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/26/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250826 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 24 50133206390000 214112 7/15/2025 AK E-LINE PPROF T40803 BR 11-86 50733207370000 225057 7/30/2025 AK E-LINE Hoist T40804 BR 11-86 50733207370000 225057 8/4/2025 AK E-LINE Perf T40804 BR 11-86 50733207370000 225057 8/9/2025 AK E-LINE Perf T40804 BRU 212-35T 50283200970000 198161 8/4/2025 AK E-LINE Perf T40805 BRU 212-35T 50283200970000 198161 6/28/2025 AK E-LINE Perf T40805 BRU 224-34T 50283202050000 225044 8/2/2025 AK E-LINE CBL T40806 BRU 224-34T 50283202050000 225044 8/5/2025 AK E-LINE CBL T40806 BRU 224-34T 50283202050000 225044 7/27/2025 AK E-LINE CBL T40806 BRU 224-34T 50283202050000 225044 8/2/2025 AK E-LINE Punch T40806 KTU 43-6XRD2 50133203280200 205117 7/26/2025 AK E-LINE Perf T40807 MPL-13A 50029223350100 223017 8/10/2025 READ CaliperSurvey T40808 NCIU A-21 50883201990000 224086 1/14/2025 AK E-LINE Plug/Perf T40809 ODSN-16 50703206200000 210053 8/10/2025 READ CaliperSurvey T40810 PBU 01-30A 50029216060100 225050 8/7/2025 HALLIBURTON RBT-COILFLAG T40811 PBU 06-11A 50029204280100 225042 7/13/2025 HALLIBURTON RBT-COILFLAG T40812 PBU 11-37A 50029227160100 219062 7/27/2025 HALLIBURTON RBT T40813 PBU 14-43A 50029222960100 225041 7/31/2025 HALLIBURTON RBT-COILFLAG T40814 PBU F-06B 50029200970200 225054 8/5/2025 HALLIBURTON RBT-COILFLAG T40815 PBU L1-10A 50029213400100 225032 8/1/2025 HALLIBURTON RBT-COILFLAG T40816 PCU 02A 50283200220100 224110 7/27/2025 AK E-LINE Perf T40817 SRU 241-33 50133206630000 217047 7/28/2025 AK E-LINE Perf T40818 WhiskeyGulch 1 50231200790000 221046 6/18/2025 AK E-LINE Packer T40819 Please include current contact information if different from above. T40816PBU L1-10A 50029213400100 225032 8/1/2025 HALLIBURTON RBT-COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.27 08:12:23 -08'00' David 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: 08/19/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: PBU L1-10A PTD: 225-032 API: 50-029-21340-01-00 FINAL LWD FORMATION EVALUATION + GEOSTEERING LOGS (05/28/2025 to 07/18/2025) x ROP, BaseStar and iCruise Gamma Ray, StrataStar Resistivity, ALD, CTN x 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. 225-032 T40788 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.19 12:01:56 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:Joseph Engel Cc:Joseph Lastufka Subject:RE: Return to L1-10A (PTD 225-032) Date:Tuesday, July 1, 2025 12:18:30 PM Good day Joe, You are approved to reenter the well to complete the scope on the approved PTD, no additional paperwork is required other than this notification. Please include PTD number in subject line for all well specific (PTD or Sundry) correspondence. I added it. Jack From: Joseph Engel <jengel@hilcorp.com> Sent: Monday, June 30, 2025 4:41 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: Return to L1-10A Hey Jack – we are about 10 days from rigging back up on L1-10A to resume operations and drill the production hole. Do we need to submit anything formally before we do so? Thanks. Joe Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC Office: 907.777.8395 | Cell: 805.235.6265 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 325-391 By Gavin Gluyas at 12:56 pm, Jun 27, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.06.27 12:38:30 - 08'00' Bo York (1248) 10-407 Perforating gun BHA not to exceed 500'. Ensure well is dead before breaking containment. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using attached standing orders. DSR-6/30/25A.Dewhurst 18JUL25JJL 07/21/25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.07.21 14:53:51 -08'00'07/21/25 RBDMS JSB 072425 Page 1 of 7 Post RST Extended Perforating L1-10A PTD: 225-032 Well Name:L1-10A API Number: 50-029-21340-01-00 Current Status:Operable, Offline Rig:SL, CTU, Test Unit Estimated Start Date:7/21/25 Estimated Duration:5days Reg.Approval Req’std?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Joe Lastufka 907-227-8496 First Call Engineer:Michael Hibbert 907-903-5990 Second Call Engineer:Dave Bjork 907-440-0331 Current Bottom Hole Pressure:3500 psi @ 8,800’ TVD 7.7 PPGE Maximum Expected BHP:3600 psi @ 8,800 TVD 7.9 PPGE Max. Anticipated Surface Pressure:2720psi (Based on 0.1 psi/ft. gas gradient) Min ID:3.725” @ 9,910’ XN-nipple Max Angle:92° @ 13,916’ MD – 70 deg at 10,800’ MD Well History: L1-10 was originally drilled and completed in 1985 as a Lisburne well. It remained online as a fulltime producer for ~4 years. Since 1990 it has had very little on-time. It was identified as a good donor wellbore for a far up-dip gravity drainage prospect just outside the effects of the gascap water injection influence right at the base of the Ivishak sands. A ~6000’ lateral will be placed in Z1A. Depending on the MWD logs 1000’-1500’ of perforations will be shot between 13,000’ MD and 16,650’ MD. CT will deploy the perforation guns via extended perforating with a maximum gun/spacer length of 500’ per run. Objective:Perforate the toe interval of the liner post rotary sidetrack. Prepare well for production. POP well through a portable test unit to manage potential solids and confirm production rates. Procedure Slickline – 1. Pull ball and rod, RHC plug body. 2. Drift to deviation with ~3.5” sample bailer. 3. Install generic GLD. Coil – Extended Perforating 1. MIRU CTU w/ 17,000’+ of coiled tubing. MU GR/CCL tools in carrier and drift and flag pipe for perforating. a. Pull a jewelry log from PBTD to deepest GLM @ ~9600’. b. Circulate well to 1% KCL/Seawater c. Pump pipe displacement while POOH to keep well full. 2. Send Tie-In to Michael Hibbert and Chris Clinkscales. a. MWD log will be provided to correlate to. Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deploymentof Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating Page 2 of 7 Post RST Extended Perforating L1-10A PTD: 225-032 bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. At surface, prepare for deployment of TCP guns.Ensure appropriate safety joint for gun size is on location. 3. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, 8.4 ppg 1% KCl/seawater as needed. Maintain hole fill taking returns to tank until lubricator connection is re- established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 4.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. a.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 5.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 2-7/8” MaxForce Guns - Perf Interval Proposed – final interval to be selected from MWD Logs Total Gun Length Weight of Gun (lbs) 13,000’ – 16,650’ – shot in 500’ or less intervals 1,000’-1,500’ Assume 500’ of 2-7/8” MaxForce guns – 6,205 lbs 6. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 7. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 8. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 9. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 10. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 11. It is anticipated we will make 3-6 extended perforating runs to complete the initial perforation strategy. a. Repeat steps 2-10 for each perforation run. Re-run GR/CCL as needed for depth control. 12. RDMO CTU. Test Separator: 1. MIRU portable test unit and POP well to manage potential solids. 2. After well stabilizes get a 12-18 hour piggyback test. 3. RDMO. Attachments: Proposed Schematic, BOPE and rig-up diagram, Sundry Change Form Page 3 of 7 Post RST Extended Perforating L1-10A PTD: 225-032 Proposed Wellbore Schematic Page 4 of 7 Post RST Extended Perforating L1-10A PTD: 225-032 BOP Schematic Page 5 of 7 Post RST Extended Perforating L1-10A PTD: 225-032 Page 6 of 7 Post RST Extended Perforating L1-10A PTD: 225-032 Page 7 of 7 Post RST Extended Perforating L1-10A PTD: 225-032 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepare d By (Initials) HAK Appro ved By (Initial s) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 1 Dewhurst, Andrew D (OGC) From:Michael Hibbert <michael.hibbert@hilcorp.com> Sent:Friday, 18 July, 2025 12:54 To:Dewhurst, Andrew D (OGC) Cc:Lau, Jack J (OGC); Guhl, Meredith D (OGC) Subject:RE: [EXTERNAL] PBU L1-10A Perforation Sundry (325-391) Attachments:PBU L1-10A Surveys.pdf; PBU L1-10A Surveys.csv; PBU L1-10A Surveys.las; PBU L1-10A RT FE Data.las Hi Andy, Here are the logs and data you requested. Let me know if you have any other questions. Thanks, Michael Hibbert LPC Operations Engineer 1-907-903-5990 Tops: L1-10A Tops Top Name MD Top whipstock 4117 Bottom whipstock 4127 SV1 4574 UG4 5125 UG4A 5165 UG3 5413 UG1 6034 WS2 7214 WS1 7565 CM3 7948 CM2 9161 CM1 9613 THRZ 10058 Top Put River 10324 LCU 10366 TSGR 10378 TSHU 10445 TSAD 10499 Top Z3 (TCGL) 10630 Top 2C 10739 Top 2B 10854 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Fault 1 10956 Top 2A 11061 Top 1B (14N) 11280 Top 1A (13N) 11484 mid-lateral fault 14200 TD 16823 The production lateral remained in the 1A after intersecting its top until reaching TD. The mid-lateral fault o Ưset 1A against 1A. Perforation Plan We plan to perforate within the bulk section between the ‘mid-lateral fault’ at 14200 MD to PBTD, estimated at 16,698 MD. From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Monday, July 14, 2025 11:39 AM To: Michael Hibbert <michael.hibbert@hilcorp.com> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: [EXTERNAL] PBU L1-10A Perforation Sundry (325-391) Michael, We would like to review the LWD logs prior to approving the proposed perforation interval. When available after TD, would you please send me and Jack the following: x a copy of the directional survey (.txt, .xlsx, etc.) x Ʊeld copy of the LWD logs in .las format x a list of relevant formation tops in MD In that email, please include your Ʊnalized perf interval, if diƯerent than what was is included in the 403. Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT L1-10A JBR 08/20/2025 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:2 4" & 4-1/2" joints. Kill/Choke HCRs failed. Did not witness R/T after both were C/O. Chart of same sent to J. Regg. Test time reflects when I was on location. Test Results TEST DATA Rig Rep:Ethan EvansOperator:Hilcorp North Slope, LLC Operator Rep:James Lott Rig Owner/Rig No.:Hilcorp Innovation PTD#:2250320 DATE:7/10/2025 Type Operation:DRILL Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopSAM250713133926 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7 MASP: 2986 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 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 2-7/8"x5-1/2"P #2 Rams 1 Blinds P #3 Rams 1 2-7/8"x5-1/2"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"F Kill Line Valves 2 3-1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1700 200 PSI Attained P27 Full Pressure Attained P75 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2333 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P12 #1 Rams P3 #2 Rams P3 #3 Rams P3 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1         BOPE – Hilcorp Innovation Kill and Choke HCR Tests after Replacement PBU L1-10A (PTD 2250320) AOGCC Insp# bopSAM250713133926 7/10/2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.06.09 15:41:21 - 08'00' Sean McLaughlin (4311) RUSH By Grace Christianson at 3:54 pm, Jun 09, 2025 325-350 DSR-6/10/25A.Dewhurst 09JUN25 10-407 JJL 6/10/25 *If well operations are not resumed within 12 months, the operator shall immediately proceed to abandon or suspend the well. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.18 10:42:12 -08'00'06/18/25 RBDMS JSB 062325 Well: PBU L1-10A Operational Shutdown PTD: 225-032 API: 50-029-21340-01-00 Well Name:PBU L1-10A Permit to Drill:225-032 API Number:50-029-21340-01-00 Estimated Start Date:June 10, 2025 Regulatory Contact:Joseph Lastufka 907-777-8400 (O) jo4472@hilcorp.com Drilling Engineer:Joseph Engel 907-777-8395 (O) jengel@hilcorp.com Operations Engineer Michael Hibbert 907-903-5990 mi8414@hilcorp.com Brief Well Summary: PBU L1-10A intermediate hole has been drilled and casing has been ran to TD as per approved PTD. Drilling production hole for L1-10A requires offset injectors to be shut in and Hilcorp is timing that production hole during a facility shutdown that also requires those injectors to be shut in. That facility shut down is estimated to start around July 7. Due to the inherent risk in the intermediate hole with drilling through shale overburden the decision was made to start this project with enough time to be able to deal with any adverse hole conditions encountered and still start production hole during the facility shut down. Objective: With 7” intermediate casing on bottom, Hilcorp requests an ops shutdown after a successful 7” cement job to be able to return to L1-10A to drill the planned production hole as per approved PTD to coincide with offset injector shut in. A 4-1/2” killstring will be ran, and the well freeze protected. The tentative return date to L1-10A is July 8, 2025. Current Rig Operations: Circulating and conditioning mud for 7” cement job as per approved PTD Plan Forward: Cement 7” casing as per approved PTD Run 3000’ of 4-1/2” Killstring Land hanger, RILDS Install TWC, ND BOPE, NU Tree PT tubing hanger void 500/5000 psi, PT tree to 250/5000psi Freeze protect well RDMO Attachments – Proposed Wellbore Schematic BOPE Schematic Well: PBU L1-10A Operational Shutdown PTD: 225-032 API: 50-029-21340-01-00 Proposed Wellbore Schematic Well: PBU L1-10A Operational Shutdown PTD: 225-032 API: 50-029-21340-01-00 Innovation Rig BOPE Schematic 13-5/8” Annular UPR: 2-7/8” x 5-1/2” VBR Blind Rams LPR: 7” Solid Body Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer Delete this page before packaging for Commissioners CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:Joseph Engel Cc:Joseph Lastufka; Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); Roby, David S (OGC) Subject:RE: HAK PBU L1-10A (PTD: 225-032) Update Date:Monday, June 9, 2025 12:16:57 PM Thanks for the update Joe. Jack From: Joseph Engel <jengel@hilcorp.com> Sent: Friday, June 6, 2025 1:10 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: HAK PBU L1-10A (PTD: 225-032) Update Jack – Wanted to give you an update on L1-10A. Operations are progressing as planned, we TD’d the intermediate section ~ 6’ into the Sag river this morning. We look to begin running 7” casing some time tomorrow. Some background on L1-10A project, the production hole requires offset injectors to be shut in and we are timing that production hole during a facility shutdown that also requires those injectors to be shut in. That facility shut down is estimated to start around July 11. Due to the inherent risk of the intermediate hole shales we decided to start this project with enough time to be able to deal with any adverse hole conditions encountered and still start production hole during the facility shut down. If all goes well on the intermediate casing run and cement job, we will look to run a 4-1/2” killstring and have an ops shutdown until early July to return and finish the well. Rough timeline has us cementing 7” casing on Monday June 9th. I wanted to let you know that if that cement job goes well, we will be submitting a sundry for ops shutdown on L1- 10A. Give a call or text if you have any questions. Have a good weekend. -Joe Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC Office: 907.777.8395 | Cell: 805.235.6265 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:Joseph Engel Subject:RE: HAK PBU L1-10A (PTD: 225-032) 9-5/8" Casing Test & FIT Date:Friday, May 30, 2025 11:44:10 AM Attachments:PBU L1-10A 9.625 Csg test-FIT 5-29-2025.pdf Received. Thank you. Jack From: Joseph Engel <jengel@hilcorp.com> Sent: Thursday, May 29, 2025 12:00 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: HAK PBU L1-10A (PTD: 225-032) 9-5/8" Casing Test & FIT Jack – Attached is the casing test and FIT for the 9-5/8” on L1-10A. The window was milled above the TOC of the 9-5/8”, and open to formation. We attempted to get a 12.0 ppg EMW FIT twice, with pressure gain between strokes slowly decreasing and a higher pressure on the second test before stopping to pump, which is indicative of an FIT open to permeable formations. See example chart below. The second test we got an EMW of 11.8 PPG EMW. We did not want to continue pumping and risk creating a leak off to have to manage while drilling the intermediate hole. As per the approved PTD, we will be utilizing the 13-3/8” surface casing FIT of 12.5 to drill ahead. Screenshot attached below for reference. Thanks. Joe Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC Office: 907.777.8395 | Cell: 805.235.6265 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. Ifyou are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictlyprohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, oruse of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipientshould carry out such virus and other checks as it considers appropriate. CASING AND LEAK-OFF FRACTURE TESTS Well Name:PPB E L 1-10A Date:5/29/2025 Csg Size/Wt/Grade:9.625" 47# L -80 Supervisor:Mo n tag u e/Menapac e Csg Setting Depth:4,112 TMD 4021 TVD Mud Weight:9.6 ppg LOT / FIT Press =461 psi LOT / FIT =11.80 ppg Hole Depth =4147 md Fluid Pumped=2.0 Bbls Volume Back =1.6 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here HHere Here HHere ->00 ->10 205 ->4 123 ->20 452 ->8 228 ->30 762 ->12 304 ->40 982 ->16 361 ->50 1258 ->20 404 ->60 1544 ->24 432 ->70 1833 ->28 452 ->80 2263 ->32 461 ->90 2565 -> ->93 2634 -> -> -> -> -> -> -> -> Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0 461 ->0 2630 ->0.5 405 ->1 2615 ->0.75 396 ->5 2605 ->1 390 ->10 2594 ->1.5 379 ->15 2568 ->2 371 ->30 2558 ->3 357 -> ->4 345 -> ->5 334 -> ->6 325 -> ->7 315 -> ->8 307 -> ->9 300 -> ->10 292 -> 0 4 8 12 16 20 24 28 32 10 20 30 40 50 60 70 80 90 93 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 102030405060708090100Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 461 405396390379371357345334325315307300292 26302615 2605 2594 2568 2558 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 5 10 15 20 25 30Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA 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: Prudhoe Bay Unit Field, Prudhoe Oil, PBU L1-10A Hilcorp Alaska, LLC Permit to Drill Number: 225-032 Surface Location: 2437' FSL, 2634' FEL, Sec. 01, T11N, R14E, UM, AK Bottomhole Location: 1944' FNL, 590' FEL, Sec. 10, T1N, R14E, 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 13th day of May 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.13 13:57:49 -08'00' 8-1/2"x9-7/8" By Grace Christianson at 7:43 am, Apr 03, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.04.02 16:13:12 - 08'00' Sean McLaughlin (4311) DSR-4/7/25JJL 4/21/25 225-032 50-029-21340-01-00 *AOGCC Witnessed BOP Test to 3500 psi, Annular to 2500 psi. *Email digital data of casing test, cementing summary, and FIT to AOGCC upon completion of FIT SFD 5/13/2025*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.13 13:58:03 -08'00' 05/13/25 05/13/25 RBDMS JSB 051525 02 April 2025 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill Hilcorp North Slope, LLC L1-10A Dear Sir/Madam, Hilcorp North Slope, LLC hereby applies for a Permit to Drill an onshore development well from the Drillsite L1 in Prudhoe Bay, Alaska. L1-10A is planned to be a horizontal producer targeting the Ivishak sands. The parent bore, L1-10 will be reservoir abandoned on a prior sundry. The approximate spud date is anticipated to be May 15th, 2025, pending rig schedule. The Innovation rig will be used to drill this well. The directional plan is two-hole section sidetrack. An 8-1/2” x 9-7/8” intermediate hole exiting the 9-5/8” casing at ~4117’ MD drilled into the top of the Sag River, with 7” casing ran and cemented. A 6-1/8” lateral will be drilled in the Ivishak. A 4-1/2” cemented liner will be run in the open hole section, followed by 4-1/2” tubing. Please find enclosed for your review Form 10-401 Permit to Drill with information as required by 20 AAC 25.005. If there are any questions, please contact me at (907)777-8395 or jengel@hilcorp.com. Respectfully, Joe Engel Senior Drilling Engineer Hilcorp North Slope, LLC Enclosures: Form 10-401 Permit to Drill Application for Permit to Drill Prudhoe Bay East (PBU) L1-10A Version 1 3/31/2025 Prudhoe Bay East L1-10A Producer Table of Contents 1. Well Name......................................................................................................................................3 2. Location Summary..........................................................................................................................3 3. Blowout Prevention Equipment Information.................................................................................4 4. Drilling Hazards Information...........................................................................................................5 5. Procedure for Conducting Formation Integrity Tests.....................................................................6 6. Casing and Cementing Program.....................................................................................................6 7. Diverter System Information..........................................................................................................7 8. Drilling Fluid Program.....................................................................................................................7 9. Abnormally Pressured Formation Information..............................................................................8 10. Seismic Analysis............................................................................................................................8 11. Seabed Condition Analysis............................................................................................................8 12. Evidence of Bonding.....................................................................................................................8 13. Proposed Drilling Program ...........................................................................................................9 14. Discussion of Mud and Cuttings Disposal and Annular Disposal................................................12 15. Proposed Variance Request........................................................................................................12 Attachment 1: Location & GIS Maps................................................................................................13 Attachment 2: BOPE Equipment ......................................................................................................15 Attachment 3: Hole Section Hazards................................................................................................17 Attachment 4: LOT / FIT Test Procedure..........................................................................................20 Attachment 5: Cement Summary.....................................................................................................21 Attachment 6: Prognosed Formation Tops......................................................................................22 Attachment 7: Well Schematic.........................................................................................................23 Attachment 8: Formation Evaluation Program................................................................................25 Attachment 9: Wellhead Diagram....................................................................................................26 Attachment 10: Management of Change.........................................................................................27 Attachment 11: Drill Pipe Specs.......................................................................................................28 Attachment 12: Kick Tolerance Calculations....................................................................................3 0 Attachment 13: Directional Plan......................................................................................................32 Prudhoe Bay East L1-10A Producer As per 20 AAC 25.005 (c), an application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application. 1. Well Name 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application for a Permit to Drill is submitted is designated as L1-10A.This will be a development production well. 2. Location Summary 20 AAC 25.005 (c) (2) A plat identifying the property and the property's owners and showing: (A) the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines; (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth Location at Surface Reference to Government Section Lines 2437' FSL, 2634' FEL, Sec 1, T11N, R14E, UM, AK NAD 27 Coordinate System X: 688,770.54 Y: 5,974,793.67 Innovation Rig KB Elevation 26.5’ above GL Ground Level 14’ above MSL Location at Top of Productive Interval Reference to Government Section Lines 751' FNL, 145' FWL, Sec 12, T11N, R14E, UM, AK NAD 27 Coordinate System X: 686,352.37 Y: 5,971,543.98 Measured Depth, Rig KB (MD)10,285.6’ Total Vertical Depth, Rig KB (TVD)8,177.5’ Total vertical Depth, Subsea (TVDSS)8,137’ Location at Bottom of Productive Interval Reference to Government Section Lines 1944' FNL, 590' FEL, Sec 10, T11N, R14E, UM, AK NAD 27 Coordinate System X: 680,370 Y: 5,970,204 Measured Depth, Rig KB (MD)16,647’ Total Vertical Depth, Rig KB (TVD)8,665.5’ Total Vertical Depth, Subsea (TVDSS)8,625’ Prudhoe Bay East L1-10A Producer (D) other information required by 20 AAC 25.050(b); 20 AAC 25.050 (b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must: (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; and Please refer to Attachment 1: Location Maps, Attachment 6: Formation Tops and Attachment 13: Directional Plan for further details. (2) for all wells within 200 feet of the proposed wellbore: (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The applicant is the only affected owner. 3. Blowout Prevention Equipment Information 20 AAC 25.005 (c) (3) A diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; BOP test frequency for L1-10A will be 7 days until window milling is initiated, afterwards 14- days. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 14-day BOP test period should not be requested. Summary of Innovation BOP Equipment & Test Requirements Hole Section Equipment Test Pressure (psi) 8-1/2” x 9-7/8” & 6-1/8” x 13-5/8” x 5M Control Technology Inc Annular BOP x 13-5/8” x 5M Control Technology Inc Double Gate o Blind ram in bottom cavity x Mud cross w/ 3” x 5M side outlets x 13-5/8” x 5M Control Technology Single ram x 3-1/8” x 5M Choke Line x 3-1/8” x 5M Kill line x 3-1/8” x 5M Choke manifold x Standpipe, floor valves, etc. Initial Test: 250/3500 (Annular 2500 psi) Subsequent Tests: 250/3500 (Annular 2500 psi) Primary closing unit: Control Technology Inc. (CTI), 6 station, 3,000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are in the doghouse and on accumulator unit. Please refer to Attachment 2: BOPE Equipment for further details. Prudhoe Bay East L1-10A Producer 4. Drilling Hazards Information 20 AAC 25.005 (c) (4) Information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of true vertical depth, unless the commission approves a different pressure gradient that provides a more accurate means of determining the maximum potential surface pressure; 8-1/2” x 9-7/8” Intermediate Hole Pressure Data Maximum anticipated BHP 3,611 psi in the top Sag River at 8,097’ TVD Maximum surface pressure 2,819 psi from the Sag River (0.10 psi/ft gas gradient to surface) Planned BOP test pressure Rams test to 3,500 psi / 250 psi Annular test to 2,500 psi / 250 psi Formation Integrity Test – 8-1/2” x 9-7/8” 12.0 ppg EMW FIT after drilling 20’ of new hole outside of 9- 5/8” window If unable to achieve 12.0 ppg EMW, utilize surface casing FIT t/ 12.5. See Attachment 12 12.0 provides greater than 25bbl KT based on 9.5ppg MW 9-5/8” Casing Test 2,500 psi, chart for 30 min (Test pressure driven by 50% of Casing Burst) 6-1/8” Production Hole Pressure Data Maximum anticipated BHP 3,833 psi in the Ivishak at 8,662’ TVD Maximum surface pressure 2,986 psi from the Ivishak (0.10 psi/ft gas gradient to surface) Planned BOP test pressure Rams test to 3,500 psi / 250 psi Annular test to 2,500 psi / 250 psi Formation Integrity Test – 6-1/8” hole 10.5 ppg EMW FIT after drilling 20’ of new hole outside of 7” 10.5 provides greater than 25 bbl based on 8.8 ppg MW, 8.5 ppg pore pressure 9.4 ppg minimum to drill ahead, 10.5 EMW for drilling ECDs 7” Casing Test 2,500 psi , chart for 30 min (B) data on potential gas zones; and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please refer to Attachment 3: Hole Section Hazards Prudhoe Bay East L1-10A Producer 5. Procedure for Conducting Formation Integrity Tests 20 AAC 25.005 (c) (5) A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); Please refer to Attachment 4: LOT / FIT Test Procedure 6. Casing and Cementing Program 20 AAC 25.005 (c) (6) A complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre-perforated liner, or screen to be installed; Casing/Tubing Program Hole Size Tubular O.D. Tubular ID (in)Wt/Ft Grade Conn Length Top MD Bottom MD / TVD 8-1/2” x 9-7/8”7” (Special Drift)6.125”29# L-80 VAMTOP 10,175’Surface 10,175’ / 8,096’ 6-1/8”4-1/2” Solid 3.958”12.6#13Cr80 VAMTOP ~6,622 ~10,025’16,647’ / 8,665’ Tubing 4-1/2” Solid 3.958”12.6#13Cr80 VAMTOP ~10,025 Surface ~10,025’ / 7,980’ Please refer to Attachment 5: Cement Summary for further details. Prudhoe Bay East L1-10A Producer 7. Diverter System Information 20 AAC 25.005 (c) (7) A diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Diverter system is not applicable to a sidetrack well below the surface casing. 8. Drilling Fluid Program 20 AAC 25.005 (c) (8) A drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling Fluid Program Summary Intermediate Hole Production Hole Mud Type 6% KCl LSND 3% KCl BaraDril-N Mud Properties: Mud Weight PV YP HPHT Fluid Loss pH MBT 9.5-10.8 ppg 15-25 15-25 < 11.0 9-10 < 12 8.8 – 9.5 ppg 15-25 15-25 <11 9-10 <7 A diagram of drilling fluid system on Innovation is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033 Prudhoe Bay East L1-10A Producer 9. Abnormally Pressured Formation Information 20 AAC 25.005 (c) (9) For an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); N/A – Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis 20 AAC 25.005 (c) (10) For an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A – Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis 20 AAC 25.005 (c) (11) For a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); The L1-10A is to be drilled from an onshore location. 12. Evidence of Bonding 20 AAC 25.005 (c) (12) Evidence showing that the requirements of 20 AAC 25.025 have been met; Evidence of bonding for Hilcorp North Slope, LLC is on file with the Commission. Prudhoe Bay East L1-10A Producer 13. Proposed Drilling Program 20 AAC 25.005 (c) (13) A copy of the proposed drilling program; the drilling program must indicate if a well is proposed for hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform hydraulic fracturing, a person must make a separate request by submitting an Application for Sundry Approvals (Form 10-403) with the information required under 20 AAC 25.280 and 20 AAC 25.283; The proposed drilling program to L1-10A is listed below. Please refer to Attachments for a Well Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram. Completed Pre Rig Work 1. Reservoir was abandoned as per prior approved separate sundry 2. 2-7/8” tubing cut at ~4,300’ MD Proposed Drilling Program L1-10A 1. MIRU Innovation Rig 2. Verify well is dead. Circulate KWF if needed 3. Set BPV, ND Tree, NU BOPE, test as per PTD a. AOGCC opportunity to witness, 3500psi, annular 2500psi 4. Pull BPV, MU landing joint and BOLDS 5. Pull 2-7/8” tubing, pre rig cut ~ 4,300’ MD, confirm with OE 6. MU Mill BHA and perform scraper/cleanout run to top of 2-7/8” tubing stub. 7. Displace well to 9.5 ppg milling fluid 8. PU storm packer and hang off mill bha, test storm packer to 2500 psi 9. ND BOPE and tubing spool and install 7” casing spool. NU and shell test same. a. Barriers: i. Tested cement plug and IA, 2500 psi. Verify. ii. KWF iii. PT Storm Packer 10. Release storm packer and POOH LD mill bha 11. MU Whipstock and Mill assembly and RIH to ~4,300’ MD 12. Orient whipstock to ~ 100* azimuth with GWD, set anchor and shear off 13. Ensure wellbore 9.5ppg milling fluid in wellbore 14. Test 9-5/8” casing to 2500psi f/ 30 min, chart test 15. Mill 9-5/8” window & 20’ of new hole 16. Pull milling assembly back into casing, RU and perform FIT to 12.0 ppg EMW a. If unable to achieve 12.0 ppg EMW, utilize prior 13-3/8” FIT t/ 12.5 ppg EMW b. See Attachment 12 for surface casing FIT value 17. POOH and LD milling assembly, gauge mills a. If mills are under gauge, PU back up mills and dress of window 18. MU motor BHA, RIH, trip through window with pumps off and no rotary, drill to ~4600’MD to bury 8-1/2” x 9-7/8” RSS BHA. POOH. *Email digital data of casing test and FIT to AOGCC upon completion of FIT - JJL Prudhoe Bay East L1-10A Producer 19. MU 8-1/2” x 9-7/8” RSS BHA, TIH, trip through window with no pumps or rotary, trip to bottom. Displace well to drilling fluid, 9.5 ppg a. Install MPD RCD, to be used to monitor well conditions and provide constant bottomhole pressure for shale stabilization 20. Drill 8-1/2” x 9-7/8” hole to ~200’ MD above HRZ 21. CBU and perform short trip to window 22. TIH to bottom, add black product to mud for shale stability, and drill ahead to TD a. Hold constant bottom hole pressure of ~10.5 – 11.0 ppg EMW for shale stability 23. At TD CBU, and increase MW t/ 10.5 for shale stability 24. POOH to window offsetting swab with MPD, pull BHA through window with no pumps or rotary, POOH and LD BHA 25. Run 7” long string to TD a. Circulate casing every ~ 2000’MD while RIH, max rate 4 bpm to not exceed drilling ECDs 26. Cement 7” casing as per cement program, 27. Lay down landing joint and RILDS 28. Freeze protect 9-5/8” x 7” annulus and 29. Laydown 5” DP and PU 4” DP 30. MU 6-1/8” cleanout assembly, TIH top of 7” shoe track 31. PT 7” casing to 2500 psi, chart test 32. Drill out 7” shoe track & 20’ of new hole 33. Pull back into 7” shoe, perform FIT t/ 10.5 ppg EMW 34. POOH, LD Cleanout BHA 35. MU 6-1/8” RSS BHA, RIH to bottom 36. Drill 6-1/8” lateral as per directional plan to TD a. Install MPD RCD to be used to monitor wellbore conditions during connections 37. CBU, and POOH to 7” shoe 38. POOH and LD BHA 39. RU and run 4-1/2” Liner on 4” DP to TD 40. Cement 4-1/2” Liner as per plan 41. Set Liner Hanger/liner top packer, release running tool 42. CBU to remove any cement above liner top packer 43. RU and PT liner to packer / 7” annulus t. 1500 psi f/ 10 min, charted 44. POOH LD running tool 45. Run 4-1/2” tubing as per tally 46. Land Hanger, RILDS 47. Install TWC, ND BOPE, NU Tree 48. PT tubing hanger void 500/5000 psi, PT tree to 250/5000psi 49. Spot CI Brine 50. Drop Ball & Rod, set tubing packer 51. PT Tubing 3500 psi, bleed tubing to 1000 psi & PT IA to 3500 psi a. All tests 30 min, charted * Email digital data of casing test, cementing summary, and FIT to AOGCC upon completion of FIT - JJL Prudhoe Bay East L1-10A Producer 52. Bleed Pressure on tubing to 0 psi, shear SOV, spot freeze protect 53. RU jumper to allowed freeze protect to swap 54. RDMO Post Rig Work 1. Wireline: Pull ball and rod, RHC Plug 2. Service Coil: Perforate Well (Separate Sundry) 3. Well Tie In 4. Put Well on Production Note: This well will not be fracture stimulated Prudhoe Bay East L1-10A Producer 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 20 AAC 25.005 (c) (14) A general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well. All cuttings and mud generated during drilling operations will be hauled to Prudhoe G&I on Pad 4. Drilling mud and cuttings will be hauled offsite as it is generated via truck. There is no intention to request authorization under 20 AAC 25.080 for any annular disposal operation in the well. 15. Proposed Variance Request There are no variance requests for this well at this time. Prudhoe Bay East L1-10A Producer Attachment 1: Location & GIS Maps Prudhoe Bay East L1-10A Producer Prudhoe Bay East L1-10A Producer Attachment 2: BOPE Equipment Innovation Rig BOPE Schematic Per 20 AAC 25.035(e)1.A For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least three preventers, including (i) one equipped with pipe rams that fit the size of drill pipe, tubing, or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars; (ii) (ii) one with blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and (iii) (iii) one annular type Prudhoe Bay East L1-10A Producer BOPE Configuration for each operation: Decomplete / Mill Window / Drill Intermediate / Run 7” Casing: x 13-5/8” Annular x UPR: 2-7/8” x 5-1/2” VBR x Blind Rams x LPR: 7” Solid Body Drill Production / Run 4-1/2” Liner & Completion: x 13-5/8” Annular x UPR: 2-7/8” x 5-1/2” VBR x Blind Rams x LPR: 2-7/8” x 5-1/2” VBR Innovation Rig Choke Manifold Schematic Prudhoe Bay East L1-10A Producer Attachment 3: Hole Section Hazards 8-1/2” x 9-7/8” Intermediate Hole Section Hazard Mitigations Overpressure SV1 & Ugnu Due to offset cretaceous injection, there may be higher than normal pressure in the SV1, Ugnu and Schrader Sands, ML PP 9.3ppg. MW will be increased accordingly. Utilize MPD to monitor for pressure on connections. Hole Cleaning Maintain rheology of mud system, 6 rpm value greater than hole diameter. Maintain flow rates of 200 ft/min AV, 120 rpm. Do not out drill our ability to clean the hole. Pump sweeps as needed. Monitor ECDs Lost Circulation / Breathing Monitor ECD with MWD tools. Monitor active mud system. Pump LCM as needed. Ensure adequate LCM is available, follow lost circulation decision tree, Do not drill into sag any further than necessary. Breathing has been seen, treat all flow at wellbore influx until proven otherwise. Casing run Underreamed hole section, sufficient wellbore clean up, pinned float shoe, circulation schedule while RIH, monitor drag trends, watch casing circulation rates and ECDs Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight / back- pressure to hold back formations – MPD to maintain CBHP Shale Stability Hole section will cross multiple shale formations. Directional plan and MW have been chosen based upon historical stability window. Ensure black product has been added to the mud system, MPD to maintain CBHP to minimize pressure cycling, swab pressures. Ensure sufficient MW is left in the well at TD. Pack Off During Cementing Clean up well bore at TD, and prior to running casing. Stage circulation rates up following circulation schedule Circulate bottoms up at multiple depths to condition mud the way in the hole. Circulate at TD to planned cementing rates and ensure hole is clean.Keep circulation rates below drilling ECDS, model accordingly, low displacement rates Gas Cut Mud Gas cut mud as been seen. Ensure sufficient MW is used during hole section. Monitor wells and MPD while drilling and on connections. Ensure gas detectors are tested and functioning. Watch swab effect while TOOH Intermediate Casing Pick Due to MW required for shale stability and low sag PP, we want to call intermediate casing point with the least bout of sag open as possible.Follow geologist for casing pick depth and procedure, ‘scratch and sniff’. Offset Injection Offset injection does exist, ensure all previously listed wells have been shut in a minimum of 2 days prior to beginning to drill the production section Prudhoe Bay East L1-10A Producer 6-1/8” Production Hole Section Hazard Mitigations Offset Injection Offset injection does exist, ensure all previously listed wells have been shut in a minimum of 2 days prior to beginning to drill the production section Lost Returns / Breathing Monitor ECD with MWD tools. Have adequate LCM available. Breathing has been seen, treat all flow as influx until proven otherwise. Have sufficient fluid available. Faulting Be prepared for faulting, known and unknown. Losses can occur after faults, if losses are extreme consider suspending well operations. Hole Swabbing Reduce tripping speed, lower mud rheology, offset swab with MPD, pump out of the hole if required. Abnormal Pressures Lower than normal pressures in the target reservoir. Ensure LCM in the mud systems and monitor fluid systems. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight / back- pressure to hold back formations. Anti Collision See Close Approaches in Directional Plan attachment. Continually monitor surveys for magnetic interference. Shale / Wellbore Instability Maintain adequate mud weight / back-pressure for wellbore stability.Monitor cuttings returns, LWD logs, and drilling. Production hole could cross multiple shale formations. MPD to minimize pressure cycles on formation. Zone 3 Crossing Only 1 zone 3 crossing in this hole section, one bit run should be sufficient. Have backup in case a bit trip occurs. Prudhoe Bay East L1-10A Producer DS L1 has a history of H2S. Ensure detectors are tested and functioning. x AOGCC to be notified withing 24 hours if H2S is encountered more than 20 ppm during drilling operations x Rig will have fully functional automatic H2S detection equipment meeting the requirements of 20 AAC 25.066 x In the event H2S is detected, well work will be suspended and personnel evacuated until a detailed mitigation procured can be developed. DS L1 H2S History: Wells withover 100ppm H2S readings: There are no wells with H2S 100ppm or greater DS L1 has a history of H2S. Prudhoe Bay East L1-10A Producer Attachment 4: LOT / FIT Test Procedure Prudhoe Bay East L1-10A Producer Attachment 5: Cement Summary 7” Intermediate Casing Cement OH x CSG 8.5” x 9-7/8” OH x 7” Casing Basis Cement Vol Open hole volume + excess + 120’ ft shoe track TOC 500’ MD above Sag (Top Sag: 10175’ MD, TOC 9675’ MD) Total Cement Volume Spacer 60 bbls of 11.0 ppg Tuned Spacer Cement 30% Open Hole Excess 15.8ppg:31.6 bbls,177.3 ft3, 152.8 sks HalCem Class G – 1.16 cuft/sk BHST 170 deg F Displacement (10175’ – 120’) * .0371bpf =373.1 bbl 4-1/2” Liner Cement OH x CSG 6-1/8” OH x 4-1/2” Liner Basis Cement Vol CH volume (150’ 7” Liner Lap) + (OH volume x 30%) + 120’ ft shoe track TOC 7” x 5” Liner Top, ~ 10,025’ MD Total Cement Volume Spacer 30 bbls of 11.0 ppg Tuned Spacer Cement 30% Open Hole Excess 15.8ppg: 113.1 bbls,634.5 ft3, 547 sks HalCem Class G – 1.16 cuft/sk BHST 170 -180 deg F Displacement (16647 – 10025 – 120) * .0152bpf (4-1/2” capacity) + 10025 * .0103 bpf (4” dp capacity) 98.8 + 103.3 = 202.1 bbl Section Calculation Vol (bbl) Vol (ft3) Vol (sks) 8.5" Pilot Hole x 7" (120') (10175 - 10055)' x 0.0226 bpf x 1.3 = 3.6 20.2 9.875" OH x 7" (10055 - 9675) x .0471bpf x 1.3 = 23.5 131.8 7" Shoetrack 120' x 0.0372 bpf = 4.5 25.2 Total Tail 31.6 177.3 152.8Tail Section Calculation Vol (bbl) Vol (ft3) Vol (sks) 6-1/8" OH x 4-1/2" (16,647 - 10,175)' x 0.0168 bpf x 1.3 = 108.7 609.8 7" CH x 4-1/2" (10175 - 10025) x .0175 bpf = 2.6 14.6 4-1/2" Shoetrack 120' x 0.0152 bpf = 1.8 10.1 Total Tail 113.1 634.5 547.0Tail Prudhoe Bay East L1-10A Producer Attachment 6: Prognosed Formation Tops Xi ͙͖͕͕ «͐SV (Sand) Water ͓͔͔͘ ͓͔͒͘ ϱ͓͔͔͒ 1891 ͗ϟ͔͒ @͓Ugnu (Sand) Water ͔͐͏͑ ͓͔͗͘ ϱ͓͗͐͘ 2330 ͘ϟ͒ @͒Ugnu (Sand) Water ͔͓͏͒ ͔͏͔͗ ϱ͔͏͓͓ 2439 ͘ϟ͒ @͐Ugnu (Sand) Water ͕͕͐͗ ͔͔͖͏ ϱ͔͔͒͏ 2674 ͘ϟ͒ ®͑Schrader (Sand) Water ͖͕͐͑ ͕͕͐͘ ϱ͕͐͑͗ 2964 ͘ϟ͒ ®͐Schrader (Sand) Water ͖͓͕͗ ͕͔͕͒ ϱ͕͕͒͐ 3054 ͘ϟ͒ a͒Colville (Shale)͖͓͗͏ ͕͔͓͗ ϱ͕͔͓͒ a͐Colville (Shale)͓͖͒͘ ͖͔͏͖ ϱ͖͓͕͖ F¾HRZ (Shale)͔͗͒͘ ͖͔͗͏ ϱ͖͗͏͘ F¾ϯĺŕώŪťώĖŽôŘ Put River (Sand) Gas ͐͏͐͐͘ ͗͏͔͓ ϱ͗͏͐͒ 3663 ͗ϟ͖͘ [ϯĺŕώXĖĲČÍħ Kingak (Shale)͐͏͖͐͒ ͗͏͓͘ ϱ͗͏͔͓ @Sag River (Sand) Gas ͐͏͖͔͐ ͗͏͖͘ ϱ͗͏͔͕ 3611 ͗ϟ͕͑ FShublik (Shale / Carbonate Gas ͐͏͑͏͒ ͗͐͐͘ ϱ͗͏͖͗ "Ivishak (Sand)͐͏͕͑͗ ͖͗͐͗ ϱ͖͗͐͒ 3618 ͗ϟ͔͔ ĺŕώ¾͒Ivishak (Conglomerate) Gas ͐͏͓͕͐ ͗͑͐͘ ϱ͔͗͑͏ 3668 ͗ϟ͔͔ ĺŕώ͑Ivishak (Conglomerate) Gas ͐͏͔͖͏ ͔͗͒͏ ϱ͗͒͏͘ 3694 ͗ϟ͔͔ ĺŕώ͑Ivishak (Sand/Shale) Gas ͐͏͗͏͏ ͓͓͕͗ ϱ͓͗͏͔ 3737 ͗ϟ͔͔ ĺŕώ͐Ivishak (Sand/Shale) Oil ͓͐͐͐͒ ͔͖͗͘ ϱ͔͔͖͗ 3804 ͗ϟ͔͔ ĺŕώ͐Ivishak (Sand/Shale) Oil ͐͐͑͘͘ ͕͕͗͑ ϱ͕͗͑͑ 3833 ͗ϟ͔͔ ANTICIPATED FORMATION TOPS & GEOHAZARDS L1-10A wp03 TOP NAME LITHOLOGY EXPECTE D FLUID MD (FT) TVD (FT) TVDSS (FT) Est. ML PP (psi) ML PP (ppg) Prudhoe Bay East L1-10A Producer Attachment 7: Well Schematic Post Sundry Schematic, Well Status When Rig Arrives Prudhoe Bay East L1-10A Producer Prudhoe Bay East L1-10A Producer Attachment 8: Formation Evaluation Program 8-1/2” x 9-7/8”” Intermediate Hole LWD Gamma Ray (including at-bit Gamma) Resistivity 6-1/8” Production Hole LWD Gamma Ray Resistivity Azimuthal Resistivity Density Neutron Mudlogging No mudlogging is planned. Prudhoe Bay East L1-10A Producer Attachment 9: Wellhead Diagram Prudhoe Bay East L1-10A Producer Attachment 10: Management of Change Prudhoe Bay East L1-10A Producer Attachment 11: Drill Pipe Specs Prudhoe Bay East L1-10A Producer Prudhoe Bay East L1-10A Producer Attachment 12: Kick Tolerance Calculations L1-10 13-3/8” Casing Test & FIT – 5/18/85 Prudhoe Bay East L1-10A Producer Prudhoe Bay East L1-10A Producer Attachment 13: Directional Plan Intermediate Section Offset Wells with CF < 1.0: x There are no wells that have a CF less than 1.0, only proposed well plans Production Section Offset Wells with CF < 1.0: x There are no wells that have a CF less than 1.0, only proposed well plans Standard Proposal Report 28 March, 2025 Plan: L1-10A wp03 Hilcorp North Slope, LLC Lisburne L1 Plan: L1-10 Plan: L1-10A 3600420048005400600066007200780084009000True Vertical Depth (1200 usft/in)-600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800Vertical Section at 242.79° (1200 usft/in)L1-10A wp02 tgt01L1-10A wp02 tgt04L1-10A wp02 tgt02L1-10A wp02 tgt05L1-10A wp02 tgt03L1-10A wp02 tgt07L1-10A wp02 tgt063500400045005000L1-109 5/8" x 12 1/4" Window7" x 8 1/2"4 1/2" x 6 1/4"45005000550060006500700075008000850090009500100001050011000115001200012500 130001350014000145001500015500 160001650016648L1-10A wp03KOP : Start Dir 12.3º/100' : 4100' MD, 4011.7'TVD : 160° RT TFEnd Dir : 4117' MD, 4024.96' TVDStart Dir 5º/100' : 4137' MD, 4040.76'TVDEnd Dir : 5551.28' MD, 5181.51' TVDStart Dir 4º/100' : 9493.47' MD, 7596.92'TVDEnd Dir : 9799.93' MD, 7809' TVDStart Dir 5º/100' : 10175.23' MD, 8096.5'TVDEnd Dir : 10868.92' MD, 8465.3' TVDStart Dir 5º/100' : 11076.88' MD, 8520.33'TVDEnd Dir : 11791.67' MD, 8650.29' TVDStart Dir 4º/100' : 11941.67' MD, 8663.36'TVDEnd Dir : 12052.07' MD, 8668.74' TVDStart Dir 2º/100' : 12225.09' MD, 8670.5'TVDEnd Dir : 12304.07' MD, 8670.23' TVDStart Dir 2º/100' : 12966.78' MD, 8658.99'TVDEnd Dir : 13065.4' MD, 8659.01' TVDStart Dir 2º/100' : 13265.4' MD, 8662.5'TVDEnd Dir : 13318.29' MD, 8663.43' TVDStart Dir 2º/100' : 13858.06' MD, 8672.96'TVDEnd Dir : 13983.66' MD, 8672.43' TVDStart Dir 2º/100' : 14133.66' MD, 8668.5'TVDEnd Dir : 14246.55' MD, 8667.21' TVDStart Dir 2º/100' : 15263.13' MD, 8670.5'TVDEnd Dir : 15295.04' MD, 8670.43' TVDStart Dir 2º/100' : 16301.15' MD, 8662.85'TVEnd Dir : 16347.73' MD, 8662.88' TVTotal Depth : 16647.73' MD, 8665.5' TVSV1UG4UG3UG1WS2WS1CM3CM1THRZBHRZ/Top Put RiverLCU/Top KingakTSGRTSHUTSADTop Z3Top 2CTop 2BTop 1BTop 1AHilcorp North Slope, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: L1-10Ground Level: 14.00+N/-S +E/-WNorthingEastingLatittudeLongitude0.000.005974793.67688770.54 70° 20' 9.1463 N 148° 28' 6.0818 WSURVEY PROGRAMDate: 2024-06-05T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool43.70 4100.00 1 : Schlumberger GCT multishot (L1-10)3_Gyro-CT_pre-1998_Csg4100.00 4500.00 L1-10A wp03 (Plan: L1-10A) GYD_Quest GWD4500.00 12000.00 L1-10A wp03 (Plan: L1-10A) 3_MWD+IFR2+MS+Sag12000.00 16647.73 L1-10A wp03 (Plan: L1-10A) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation4395.50 4355.00 4559.10 SV14859.50 4819.00 5102.54 UG45084.50 5044.00 5402.35 UG35570.50 5530.00 6186.15 UG16168.50 6128.00 7162.14 WS26356.50 6316.00 7468.98 WS16583.50 6543.00 7839.46 CM37507.50 7467.00 9347.52 CM17849.50 7809.00 9852.80 THRZ8053.50 8013.00 10119.10 BHRZ/Top Put River8094.50 8054.00 10172.62 LCU/Top Kingak8096.50 8056.00 10175.23 TSGR8118.50 8078.00 10204.27 TSHU8177.50 8137.00 10285.59 TSAD8290.50 8250.00 10461.19 Top Z38349.50 8309.00 10569.53 Top 2C8445.50 8405.00 10801.31 Top 2B8597.50 8557.00 11414.04 Top 1B8662.50 8622.00 11931.81 Top 1AREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: L1-10, True NorthVertical (TVD) Reference:L1-10A Planned RKB @ 40.50usftMeasured Depth Reference:L1-10A Planned RKB @ 40.50usftCalculation Method:Minimum CurvatureProject:LisburneSite:L1Well:Plan: L1-10Wellbore:Plan: L1-10ADesign:L1-10A wp03CASING DETAILSTVD TVDSS MD SizeName4024.96 3984.46 4117.00 9-5/8 9 5/8" x 12 1/4" Window8096.32 8055.8210175.00 7 7" x 8 1/2"8665.50 8625.0016647.73 4-1/2 4 1/2" x 6 1/4"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 4100.00 39.75 121.10 4011.70 -186.73 380.54 0.00 0.00 -253.05 KOP : Start Dir 12.3º/100' : 4100' MD, 4011.7'TVD : 160° RT TF2 4117.00 37.79 122.24 4024.96 -192.32 389.60 12.30 160.00 -258.56 End Dir : 4117' MD, 4024.96' TVD3 4137.00 37.79 122.24 4040.76 -198.86 399.96 0.00 0.00 -264.79 Start Dir 5º/100' : 4137' MD, 4040.76'TVD4 5551.28 52.21 230.78 5181.51 -870.93 323.48 5.00 127.45 110.51 End Dir : 5551.28' MD, 5181.51' TVD5 9493.47 52.21 230.78 7596.92 -2840.86 -2090.23 0.00 0.00 3157.85 Start Dir 4º/100' : 9493.47' MD, 7596.92'TVD6 9799.93 40.00 229.33 7809.00 -2982.16 -2259.40 4.00 -175.60 3372.91 End Dir : 9799.93' MD, 7809' TVD7 10175.23 40.00 229.33 8096.50 -3139.38 -2442.38 0.00 0.00 3607.52 L1-10A wp02 tgt01 Start Dir 5º/100' : 10175.23' MD, 8096.5'TVD8 10868.92 74.66 231.02 8465.30 -3506.33 -2885.11 5.00 2.87 4169.04 End Dir : 10868.92' MD, 8465.3' TVD9 11076.88 74.66 231.02 8520.33 -3632.48 -3041.02 0.00 0.00 4365.38 Start Dir 5º/100' : 11076.88' MD, 8520.33'TVD10 11791.67 85.00 265.85 8650.29 -3883.22 -3685.08 5.00 76.91 5052.82 End Dir : 11791.67' MD, 8650.29' TVD11 11941.67 85.00 265.85 8663.36 -3894.03 -3834.12 0.00 0.00 5190.31 L1-10A wp02 tgt02 Start Dir 4º/100' : 11941.67' MD, 8663.36'TVD12 12052.07 89.42 265.85 8668.74 -3902.01 -3944.07 4.00 0.00 5291.74 End Dir : 12052.07' MD, 8668.74' TVD13 12225.09 89.42 265.85 8670.50 -3914.53 -4116.62 0.00 0.00 5450.93 L1-10A wp02 tgt03 Start Dir 2º/100' : 12225.09' MD, 8670.5'TVD14 12304.07 90.97 265.58 8670.23 -3920.43 -4195.38 2.00 -9.82 5523.67 End Dir : 12304.07' MD, 8670.23' TVD15 12966.78 90.97 265.58 8658.99 -3971.49 -4856.02 0.00 0.00 6134.56 Start Dir 2º/100' : 12966.78' MD, 8658.99'TVD16 13065.40 89.00 265.59 8659.01 -3979.08 -4954.34 2.00 179.73 6225.47 End Dir : 13065.4' MD, 8659.01' TVD17 13265.40 89.00 265.59 8662.50 -3994.45 -5153.72 0.00 0.00 6409.82 L1-10A wp02 tgt04 Start Dir 2º/100' : 13265.4' MD, 8662.5'TVD18 13318.29 88.99 264.53 8663.43 -3999.01 -5206.41 2.00 -90.66 6458.76 End Dir : 13318.29' MD, 8663.43' TVD19 13858.06 88.99 264.53 8672.96 -4050.43 -5743.64 0.00 0.00 6960.06 Start Dir 2º/100' : 13858.06' MD, 8672.96'TVD20 13983.66 91.50 264.52 8672.43 -4062.41 -5868.65 2.00 -0.28 7076.72 End Dir : 13983.66' MD, 8672.43' TVD21 14133.66 91.50 264.52 8668.50 -4076.73 -6017.92 0.00 0.00 7216.02 L1-10A wp02 tgt05 Start Dir 2º/100' : 14133.66' MD, 8668.5'TVD22 14246.55 89.81 263.02 8667.21 -4088.98 -6130.13 2.00 -138.28 7321.42 End Dir : 14246.55' MD, 8667.21' TVD23 15263.13 89.81 263.02 8670.50 -4212.56 -7139.16 0.00 0.00 8275.30 L1-10A wp02 tgt06 Start Dir 2º/100' : 15263.13' MD, 8670.5'TVD24 15295.04 90.43 263.18 8670.43 -4216.40 -7170.84 2.00 14.75 8305.23 End Dir : 15295.04' MD, 8670.43' TVD25 16301.15 90.43 263.18 8662.85 -4335.87 -8169.80 0.00 0.00 9248.29 Start Dir 2º/100' : 16301.15' MD, 8662.85'TVD26 16347.73 89.50 263.18 8662.88 -4341.40 -8216.05 2.00 -179.99 9291.95 End Dir : 16347.73' MD, 8662.88' TVD27 16647.73 89.50 263.18 8665.50 -4377.02 -8513.91 0.00 0.00 9573.14 L1-10A wp02 tgt07 Total Depth : 16647.73' MD, 8665.5' TVD -5500-5000-4500-4000-3500-3000-2500-2000-1500-1000-50005001000South(-)/North(+) (1000 usft/in)-8500 -8000 -7500 -7000 -6500 -6000 -5500 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000West(-)/East(+) (1000 usft/in)L1-10A wp02 tgt06L1-10A wp02 tgt07L1-10A wp02 tgt03L1-10A wp02 tgt05L1-10A wp02 tgt02L1-10A wp02 tgt04L1-10A wp02 tgt0125 00300035004000 45004750L1-109 5/8" x 12 1/4" Window7" x 8 1/2"4 1/2" x 6 1/4"4750500052505500575060006250650067507000725075007750800085008 66 6 L1-10A wp03KOP : Start Dir 12.3º/100' : 4100' MD, 4011.7'TVD : 160° RT TFEnd Dir : 4117' MD, 4024.96' TVDStart Dir 5º/100' : 4137' MD, 4040.76'TVDEnd Dir : 5551.28' MD, 5181.51' TVDStart Dir 4º/100' : 9493.47' MD, 7596.92'TVDEnd Dir : 9799.93' MD, 7809' TVDStart Dir 5º/100' : 10175.23' MD, 8096.5'TVDEnd Dir : 10868.92' MD, 8465.3' TVDStart Dir 5º/100' : 11076.88' MD, 8520.33'TVDEnd Dir : 11791.67' MD, 8650.29' TVDStart Dir 4º/100' : 11941.67' MD, 8663.36'TVDEnd Dir : 12052.07' MD, 8668.74' TVDStart Dir 2º/100' : 12225.09' MD, 8670.5'TVDEnd Dir : 12304.07' MD, 8670.23' TVDStart Dir 2º/100' : 12966.78' MD, 8658.99'TVDEnd Dir : 13065.4' MD, 8659.01' TVDStart Dir 2º/100' : 13265.4' MD, 8662.5'TVDEnd Dir : 13318.29' MD, 8663.43' TVDStart Dir 2º/100' : 13858.06' MD, 8672.96'TVDEnd Dir : 13983.66' MD, 8672.43' TVDStart Dir 2º/100' : 14133.66' MD, 8668.5'TVDEnd Dir : 14246.55' MD, 8667.21' TVDStart Dir 2º/100' : 15263.13' MD, 8670.5'TVDEnd Dir : 15295.04' MD, 8670.43' TVDStart Dir 2º/100' : 16301.15' MD, 8662.85'TVDEnd Dir : 16347.73' MD, 8662.88' TVDTotal Depth : 16647.73' MD, 8665.5' TVDCASING DETAILSTVDTVDSS MDSize Name4024.96 3984.46 4117.00 9-5/8 9 5/8" x 12 1/4" Window8096.32 8055.82 10175.00 7 7" x 8 1/2"8665.50 8625.00 16647.73 4-1/2 4 1/2" x 6 1/4"Project: LisburneSite: L1Well: Plan: L1-10Wellbore: Plan: L1-10APlan: L1-10A wp03WELL DETAILS: Plan: L1-10Ground Level: 14.00+N/-S+E/-WNorthing Easting Latittude Longitude0.00 0.005974793.67 688770.5470° 20' 9.1463 N 148° 28' 6.0818 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: L1-10, True NorthVertical (TVD) Reference: L1-10A Planned RKB @ 40.50usftMeasured Depth Reference:L1-10A Planned RKB @ 40.50usftCalculation Method:Minimum Curvature Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Lisburne L1 Standard Proposal Report Well: Wellbore: Plan: L1-10 Plan: L1-10A Survey Calculation Method:Minimum Curvature L1-10A Planned RKB @ 40.50usft Design:L1-10A wp03 Database:Alaska MD Reference:L1-10A Planned RKB @ 40.50usft North Reference: Well Plan: L1-10 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Lisburne, GPMA, LISBURNE 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: L1, TR-11-14 usft Map usft usft °1.40Slot Radius:"0 5,970,246.77 683,519.17 0.00 70° 19' 25.7206 N 148° 30' 42.6540 W Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: Plan: L1-10, L1-10 usft usft 0.00 0.00 5,974,793.67 688,770.54 14.00Wellhead Elevation:16.73 usft0.00 70° 20' 9.1463 N 148° 28' 6.0818 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) Plan: L1-10A Model NameMagnetics BGGM2024 6/5/2025 14.22 80.71 57,077.21979287 Phase:Version: Audit Notes: Design L1-10A wp03 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:4,100.00 242.790.000.0026.50 3/28/2025 6:31:10PM COMPASS 5000.17 Build 04 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Lisburne L1 Standard Proposal Report Well: Wellbore: Plan: L1-10 Plan: L1-10A Survey Calculation Method:Minimum Curvature L1-10A Planned RKB @ 40.50usft Design:L1-10A wp03 Database:Alaska MD Reference:L1-10A Planned RKB @ 40.50usft North Reference: Well Plan: L1-10 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 0.000.000.000.00380.54-186.734,011.70121.1039.754,100.00 3,971.20 160.006.87-11.5612.30389.60-192.324,024.96122.2437.794,117.00 3,984.46 0.000.000.000.00399.96-198.864,040.76122.2437.794,137.00 4,000.26 127.457.671.025.00323.48-870.935,181.51230.7852.215,551.28 5,141.01 0.000.000.000.00-2,090.23-2,840.867,596.92230.7852.219,493.47 7,556.42 -175.60-0.47-3.994.00-2,259.40-2,982.167,809.00229.3340.009,799.93 7,768.50 0.000.000.000.00-2,442.38-3,139.388,096.50229.3340.0010,175.23 8,056.00 2.870.245.005.00-2,885.11-3,506.338,465.30231.0274.6610,868.92 8,424.80 0.000.000.000.00-3,041.02-3,632.488,520.33231.0274.6611,076.88 8,479.83 76.914.871.455.00-3,685.08-3,883.228,650.29265.8585.0011,791.67 8,609.79 0.000.000.000.00-3,834.12-3,894.038,663.36265.8585.0011,941.67 8,622.86 0.000.004.004.00-3,944.07-3,902.018,668.74265.8589.4212,052.07 8,628.24 0.000.000.000.00-4,116.62-3,914.538,670.50265.8589.4212,225.09 8,630.00 -9.82-0.341.972.00-4,195.38-3,920.438,670.23265.5890.9712,304.07 8,629.73 0.000.000.000.00-4,856.02-3,971.498,658.99265.5890.9712,966.78 8,618.49 179.730.01-2.002.00-4,954.34-3,979.088,659.01265.5989.0013,065.40 8,618.51 0.000.000.000.00-5,153.72-3,994.458,662.50265.5989.0013,265.40 8,622.00 -90.66-2.00-0.022.00-5,206.41-3,999.018,663.43264.5388.9913,318.29 8,622.93 0.000.000.000.00-5,743.64-4,050.438,672.96264.5388.9913,858.06 8,632.46 -0.28-0.012.002.00-5,868.65-4,062.418,672.43264.5291.5013,983.66 8,631.93 0.000.000.000.00-6,017.92-4,076.738,668.50264.5291.5014,133.66 8,628.00 -138.28-1.33-1.492.00-6,130.13-4,088.988,667.21263.0289.8114,246.55 8,626.71 0.000.000.000.00-7,139.16-4,212.568,670.50263.0289.8115,263.13 8,630.00 14.750.511.932.00-7,170.84-4,216.408,670.43263.1890.4315,295.04 8,629.93 0.000.000.000.00-8,169.80-4,335.878,662.85263.1890.4316,301.15 8,622.35 -179.990.00-2.002.00-8,216.05-4,341.408,662.88263.1889.5016,347.73 8,622.38 0.000.000.000.00-8,513.91-4,377.028,665.50263.1889.5016,647.73 8,625.00 3/28/2025 6:31:10PM COMPASS 5000.17 Build 04 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Lisburne L1 Standard Proposal Report Well: Wellbore: Plan: L1-10 Plan: L1-10A Survey Calculation Method:Minimum Curvature L1-10A Planned RKB @ 40.50usft Design:L1-10A wp03 Database:Alaska MD Reference:L1-10A Planned RKB @ 40.50usft North Reference: Well Plan: L1-10 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 14.00 Vert Section 26.50 0.00 26.50 0.00 0.000.00 688,770.545,974,793.6714.00 0.00 0.00 43.70 0.33 43.70 0.05 0.0111.09 688,770.555,974,793.72-3.20 1.92 -0.03 48.30 0.33 48.30 0.07 0.0217.30 688,770.555,974,793.74-7.80 0.78 -0.05 57.50 0.33 57.50 0.12 0.0427.08 688,770.575,974,793.79-17.00 0.61 -0.09 66.80 0.33 66.80 0.17 0.0632.53 688,770.605,974,793.84-26.30 0.34 -0.13 79.40 0.32 79.40 0.23 0.1032.43 688,770.645,974,793.90-38.90 0.08 -0.19 92.90 0.30 92.90 0.29 0.1429.66 688,770.675,974,793.97-52.40 0.19 -0.26 106.50 0.27 106.50 0.35 0.1725.95 688,770.705,974,794.03-66.00 0.26 -0.31 120.10 0.25 120.10 0.41 0.2024.40 688,770.735,974,794.08-79.60 0.16 -0.36 133.80 0.23 133.80 0.46 0.2227.81 688,770.755,974,794.13-93.30 0.18 -0.41 147.60 0.23 147.60 0.51 0.2533.31 688,770.785,974,794.18-107.10 0.16 -0.45 161.30 0.22 161.30 0.55 0.2832.00 688,770.805,974,794.23-120.80 0.08 -0.50 175.10 0.17 175.10 0.59 0.3017.14 688,770.825,974,794.27-134.60 0.51 -0.54 188.80 0.12 188.80 0.63 0.30337.44 688,770.825,974,794.30-148.30 0.80 -0.55 202.60 0.12 202.60 0.64 0.28279.85 688,770.805,974,794.32-162.10 0.84 -0.54 216.30 0.17 216.30 0.64 0.25239.90 688,770.775,974,794.31-175.80 0.80 -0.51 230.10 0.22 230.10 0.60 0.21219.63 688,770.745,974,794.28-189.60 0.61 -0.47 243.80 0.28 243.80 0.55 0.18203.59 688,770.715,974,794.23-203.30 0.67 -0.42 257.60 0.35 257.60 0.48 0.16191.85 688,770.695,974,794.16-217.10 0.69 -0.36 271.30 0.40 271.30 0.39 0.15183.34 688,770.685,974,794.07-230.80 0.55 -0.31 285.10 0.43 285.10 0.29 0.15176.24 688,770.685,974,793.97-244.60 0.43 -0.27 298.80 0.45 298.80 0.19 0.16168.80 688,770.705,974,793.86-258.30 0.44 -0.23 312.50 0.47 312.50 0.08 0.20157.01 688,770.735,974,793.76-272.00 0.70 -0.21 326.30 0.47 326.30 -0.01 0.26133.81 688,770.805,974,793.67-285.80 1.37 -0.23 340.00 0.47 340.00 -0.06 0.36101.04 688,770.905,974,793.62-299.50 1.94 -0.29 353.80 0.45 353.80 -0.05 0.4673.18 688,771.005,974,793.63-313.30 1.61 -0.39 367.50 0.42 367.49 -0.01 0.5660.07 688,771.105,974,793.67-326.99 0.76 -0.49 381.20 0.38 381.19 0.04 0.6454.61 688,771.185,974,793.73-340.69 0.40 -0.59 394.95 0.35 394.94 0.09 0.7148.43 688,771.245,974,793.78-354.44 0.36 -0.67 408.65 0.32 408.64 0.15 0.7641.88 688,771.305,974,793.84-368.14 0.35 -0.75 422.40 0.18 422.39 0.20 0.8024.25 688,771.335,974,793.89-381.89 1.15 -0.80 436.10 0.23 436.09 0.21 0.8399.63 688,771.375,974,793.91-395.59 1.85 -0.84 449.80 0.42 449.79 0.16 0.86184.53 688,771.395,974,793.85-409.29 3.36 -0.84 463.60 0.47 463.59 0.05 0.86177.08 688,771.395,974,793.74-423.09 0.55 -0.79 477.30 0.50 477.29 -0.06 0.87171.01 688,771.415,974,793.63-436.79 0.43 -0.74 491.10 0.52 491.09 -0.18 0.90163.00 688,771.445,974,793.51-450.59 0.54 -0.71 504.80 0.52 504.79 -0.29 0.95142.54 688,771.505,974,793.40-464.29 1.35 -0.71 518.55 0.50 518.54 -0.35 1.05100.76 688,771.605,974,793.35-478.04 2.65 -0.77 532.30 0.45 532.29 -0.34 1.1666.00 688,771.715,974,793.36-491.79 2.09 -0.87 546.10 0.40 546.09 -0.29 1.2554.28 688,771.795,974,793.41-505.59 0.72 -0.98 559.80 0.37 559.79 -0.23 1.3248.47 688,771.865,974,793.47-519.29 0.36 -1.07 574.00 0.33 573.99 -0.17 1.3841.53 688,771.925,974,793.53-533.49 0.41 -1.15 577.55 0.32 577.54 -0.16 1.3938.77 688,771.945,974,793.55-537.04 0.52 -1.17 598.05 0.27 598.04 -0.12 1.48100.03 688,772.025,974,793.59-557.54 1.48 -1.26 621.60 0.38 621.59 -0.21 1.54176.25 688,772.085,974,793.50-581.09 1.74 -1.27 3/28/2025 6:31:10PM COMPASS 5000.17 Build 04 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Lisburne L1 Standard Proposal Report Well: Wellbore: Plan: L1-10 Plan: L1-10A Survey Calculation Method:Minimum Curvature L1-10A Planned RKB @ 40.50usft Design:L1-10A wp03 Database:Alaska MD Reference:L1-10A Planned RKB @ 40.50usft North Reference: Well Plan: L1-10 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 -604.74 Vert Section 645.25 0.52 645.24 -0.39 1.57164.01 688,772.125,974,793.32-604.74 0.71 -1.22 669.00 0.52 668.99 -0.58 1.67140.21 688,772.225,974,793.14-628.49 0.90 -1.22 692.90 0.45 692.89 -0.65 1.8386.06 688,772.395,974,793.06-652.39 1.87 -1.33 716.85 0.37 716.84 -0.59 1.9845.16 688,772.535,974,793.13-676.34 1.24 -1.49 740.85 0.27 740.84 -0.49 2.0733.78 688,772.625,974,793.23-700.34 0.49 -1.61 764.85 0.30 764.84 -0.45 2.1698.94 688,772.715,974,793.27-724.34 1.28 -1.71 788.90 0.47 788.88 -0.56 2.24167.50 688,772.805,974,793.17-748.38 1.90 -1.74 812.85 0.53 812.83 -0.76 2.31154.62 688,772.875,974,792.97-772.33 0.53 -1.71 836.90 0.47 836.88 -0.89 2.45107.68 688,773.025,974,792.85-796.38 1.67 -1.78 860.65 0.37 860.63 -0.87 2.6150.94 688,773.175,974,792.87-820.13 1.72 -1.92 884.25 0.27 884.23 -0.77 2.6921.79 688,773.245,974,792.97-843.73 0.80 -2.04 907.85 0.27 907.83 -0.73 2.76100.88 688,773.325,974,793.01-867.33 1.46 -2.12 931.55 0.40 931.53 -0.82 2.82180.74 688,773.375,974,792.92-891.03 1.86 -2.13 955.15 0.48 955.13 -1.00 2.84163.39 688,773.415,974,792.75-914.63 0.65 -2.07 978.85 0.45 978.83 -1.14 2.95120.01 688,773.525,974,792.61-938.33 1.46 -2.10 1,002.45 0.37 1,002.43 -1.14 3.0951.60 688,773.665,974,792.61-961.93 1.97 -2.23 1,026.05 0.27 1,026.03 -1.03 3.15355.31 688,773.715,974,792.72-985.53 1.33 -2.33 1,049.75 0.30 1,049.73 -0.99 3.08263.33 688,773.645,974,792.76-1,009.23 1.73 -2.29 1,073.35 0.42 1,073.33 -1.08 3.01186.40 688,773.585,974,792.67-1,032.83 1.94 -2.18 1,097.05 0.47 1,097.03 -1.26 3.01171.45 688,773.585,974,792.48-1,056.53 0.53 -2.10 1,120.65 0.45 1,120.63 -1.43 3.09142.28 688,773.665,974,792.32-1,080.13 0.99 -2.09 1,144.30 0.42 1,144.28 -1.49 3.2380.65 688,773.805,974,792.26-1,103.78 1.89 -2.19 1,167.95 0.37 1,167.93 -1.41 3.3531.98 688,773.935,974,792.34-1,127.43 1.39 -2.34 1,191.55 0.32 1,191.53 -1.28 3.401.65 688,773.975,974,792.48-1,151.03 0.79 -2.43 1,215.20 0.30 1,215.18 -1.20 3.34286.99 688,773.915,974,792.56-1,174.68 1.59 -2.42 1,238.80 0.37 1,238.78 -1.24 3.23216.47 688,773.805,974,792.51-1,198.28 1.66 -2.31 1,262.45 0.43 1,262.43 -1.39 3.17190.84 688,773.755,974,792.36-1,221.93 0.79 -2.19 1,286.05 0.43 1,286.02 -1.56 3.19158.05 688,773.775,974,792.19-1,245.52 1.03 -2.12 1,309.70 0.42 1,309.67 -1.65 3.3195.32 688,773.895,974,792.11-1,269.17 1.87 -2.19 1,333.30 0.40 1,333.27 -1.59 3.4435.84 688,774.025,974,792.17-1,292.77 1.73 -2.33 1,356.95 0.38 1,356.92 -1.44 3.491.85 688,774.075,974,792.31-1,316.42 0.97 -2.45 1,380.60 0.35 1,380.57 -1.32 3.44307.60 688,774.015,974,792.44-1,340.07 1.41 -2.45 1,404.20 0.38 1,404.17 -1.32 3.32233.72 688,773.895,974,792.43-1,363.67 1.86 -2.35 1,427.80 0.42 1,427.77 -1.46 3.25183.07 688,773.835,974,792.30-1,387.27 1.46 -2.23 1,451.40 0.42 1,451.37 -1.61 3.29145.80 688,773.875,974,792.14-1,410.87 1.14 -2.19 1,475.05 0.40 1,475.02 -1.70 3.42101.08 688,774.015,974,792.06-1,434.52 1.32 -2.27 1,498.70 0.38 1,498.67 -1.66 3.5647.48 688,774.145,974,792.10-1,458.17 1.49 -2.41 1,522.30 0.38 1,522.27 -1.53 3.61352.70 688,774.195,974,792.23-1,481.77 1.48 -2.51 1,545.90 0.40 1,545.87 -1.42 3.53299.58 688,774.105,974,792.34-1,505.37 1.48 -2.49 1,569.50 0.40 1,569.47 -1.40 3.38251.66 688,773.955,974,792.35-1,528.97 1.38 -2.36 1,593.10 0.40 1,593.07 -1.49 3.25216.81 688,773.835,974,792.26-1,552.57 1.02 -2.21 1,616.70 0.35 1,616.67 -1.63 3.20178.15 688,773.785,974,792.12-1,576.17 1.07 -2.10 1,640.10 0.33 1,640.07 -1.73 3.27110.18 688,773.855,974,792.03-1,599.57 1.63 -2.12 1,663.40 0.37 1,663.37 -1.69 3.3837.31 688,773.965,974,792.07-1,622.87 1.79 -2.23 1,686.60 0.42 1,686.57 -1.54 3.42355.45 688,774.005,974,792.21-1,646.07 1.23 -2.33 3/28/2025 6:31:10PM COMPASS 5000.17 Build 04 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Lisburne L1 Standard Proposal Report Well: Wellbore: Plan: L1-10 Plan: L1-10A Survey Calculation Method:Minimum Curvature L1-10A Planned RKB @ 40.50usft Design:L1-10A wp03 Database:Alaska MD Reference:L1-10A Planned RKB @ 40.50usft North Reference: Well Plan: L1-10 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 -1,669.27 Vert Section 1,709.80 0.43 1,709.77 -1.38 3.37329.90 688,773.945,974,792.37-1,669.27 0.81 -2.36 1,733.05 0.40 1,733.02 -1.29 3.24284.04 688,773.825,974,792.46-1,692.52 1.40 -2.30 1,756.30 0.40 1,756.26 -1.32 3.10231.17 688,773.675,974,792.43-1,715.76 1.53 -2.16 1,779.60 0.43 1,779.56 -1.45 3.00210.56 688,773.575,974,792.30-1,739.06 0.65 -2.00 1,802.80 0.45 1,802.76 -1.60 2.91208.94 688,773.495,974,792.14-1,762.26 0.10 -1.85 1,826.10 0.45 1,826.06 -1.76 2.82205.13 688,773.415,974,791.98-1,785.56 0.13 -1.70 1,849.30 0.45 1,849.26 -1.93 2.75202.72 688,773.345,974,791.81-1,808.76 0.08 -1.56 1,872.60 0.50 1,872.56 -2.11 2.67206.35 688,773.265,974,791.63-1,832.06 0.25 -1.41 1,895.80 0.58 1,895.76 -2.30 2.56213.07 688,773.165,974,791.44-1,855.26 0.44 -1.23 1,919.10 0.58 1,919.06 -2.49 2.43214.93 688,773.035,974,791.24-1,878.56 0.08 -1.02 1,942.40 0.42 1,942.36 -2.63 2.29240.15 688,772.895,974,791.10-1,901.86 1.15 -0.83 1,965.65 0.47 1,965.61 -2.67 2.12270.55 688,772.725,974,791.05-1,925.11 1.02 -0.66 1,988.90 0.43 1,988.86 -2.66 1.94279.61 688,772.545,974,791.06-1,948.36 0.35 -0.51 2,012.20 0.38 2,012.16 -2.61 1.78292.60 688,772.385,974,791.10-1,971.66 0.45 -0.39 2,035.50 0.53 2,035.46 -2.55 1.61288.64 688,772.215,974,791.16-1,994.96 0.66 -0.26 2,058.80 0.53 2,058.75 -2.50 1.40277.08 688,772.005,974,791.21-2,018.25 0.46 -0.10 2,082.05 0.55 2,082.00 -2.46 1.18283.92 688,771.785,974,791.24-2,041.50 0.29 0.07 2,105.35 0.50 2,105.30 -2.39 0.98292.42 688,771.585,974,791.30-2,064.80 0.40 0.22 2,129.05 0.35 2,129.00 -2.31 0.83307.80 688,771.425,974,791.38-2,088.50 0.79 0.32 2,152.85 0.43 2,152.80 -2.19 0.72325.53 688,771.315,974,791.50-2,112.30 0.60 0.36 2,176.70 0.62 2,176.65 -2.01 0.59324.87 688,771.185,974,791.67-2,136.15 0.80 0.39 2,200.65 0.65 2,200.60 -1.79 0.44326.04 688,771.035,974,791.89-2,160.10 0.14 0.43 2,224.80 0.72 2,224.75 -1.54 0.30335.30 688,770.885,974,792.14-2,184.25 0.54 0.44 2,249.00 0.78 2,248.94 -1.25 0.19342.23 688,770.765,974,792.43-2,208.44 0.45 0.40 2,273.25 0.87 2,273.19 -0.91 0.11349.76 688,770.675,974,792.76-2,232.69 0.58 0.32 2,297.40 0.95 2,297.34 -0.53 0.06356.64 688,770.615,974,793.14-2,256.84 0.56 0.19 2,321.60 1.00 2,321.54 -0.12 0.062.26 688,770.605,974,793.55-2,281.04 0.45 0.00 2,345.75 0.95 2,345.68 0.29 0.096.72 688,770.625,974,793.96-2,305.18 0.38 -0.21 2,369.95 0.88 2,369.88 0.67 0.1510.30 688,770.675,974,794.35-2,329.38 0.37 -0.44 2,394.15 0.85 2,394.08 1.03 0.2212.63 688,770.735,974,794.71-2,353.58 0.19 -0.67 2,418.05 0.80 2,417.97 1.36 0.3221.81 688,770.835,974,795.04-2,377.47 0.59 -0.91 2,441.85 0.80 2,441.77 1.66 0.4524.76 688,770.955,974,795.35-2,401.27 0.17 -1.16 2,465.70 0.73 2,465.62 1.95 0.5823.62 688,771.075,974,795.64-2,425.12 0.30 -1.41 2,489.50 0.82 2,489.42 2.21 0.7746.40 688,771.255,974,795.90-2,448.92 1.34 -1.69 2,513.35 1.20 2,513.26 2.41 1.1270.00 688,771.605,974,796.11-2,472.76 2.33 -2.10 2,537.15 1.55 2,537.06 2.56 1.6778.59 688,772.155,974,796.27-2,496.56 1.70 -2.66 2,561.05 1.88 2,560.95 2.65 2.3886.75 688,772.855,974,796.38-2,520.45 1.71 -3.33 2,584.90 2.22 2,584.78 2.64 3.2394.04 688,773.715,974,796.39-2,544.28 1.79 -4.08 2,608.75 2.58 2,608.61 2.51 4.22100.07 688,774.705,974,796.29-2,568.11 1.84 -4.90 2,632.65 3.00 2,632.48 2.25 5.35105.81 688,775.845,974,796.05-2,591.98 2.11 -5.79 2,656.55 3.50 2,656.34 1.81 6.63111.73 688,777.135,974,795.64-2,615.84 2.52 -6.73 2,680.40 3.95 2,680.14 1.16 8.04117.44 688,778.555,974,795.03-2,639.64 2.44 -7.68 2,704.30 4.42 2,703.98 0.30 9.55121.63 688,780.085,974,794.21-2,663.48 2.34 -8.63 2,728.10 4.87 2,727.70 -0.76 11.16124.81 688,781.725,974,793.19-2,687.20 2.18 -9.58 2,751.95 5.32 2,751.46 -2.01 12.87127.59 688,783.465,974,791.98-2,710.96 2.15 -10.53 3/28/2025 6:31:10PM COMPASS 5000.17 Build 04 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Lisburne L1 Standard Proposal Report Well: Wellbore: Plan: L1-10 Plan: L1-10A Survey Calculation Method:Minimum Curvature L1-10A Planned RKB @ 40.50usft Design:L1-10A wp03 Database:Alaska MD Reference:L1-10A Planned RKB @ 40.50usft North Reference: Well Plan: L1-10 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 -2,734.65 Vert Section 2,775.75 5.70 2,775.15 -3.44 14.65129.79 688,785.275,974,790.60-2,734.65 1.83 -11.46 2,799.60 6.00 2,798.87 -5.02 16.50131.04 688,787.165,974,789.07-2,758.37 1.37 -12.38 2,823.45 6.28 2,822.59 -6.70 18.43131.22 688,789.135,974,787.44-2,782.09 1.18 -13.32 2,847.30 6.50 2,846.29 -8.44 20.43130.92 688,791.175,974,785.75-2,805.79 0.93 -14.31 2,871.10 6.63 2,869.93 -10.20 22.50129.86 688,793.295,974,784.04-2,829.43 0.75 -15.34 2,894.95 6.82 2,893.62 -11.96 24.67127.99 688,795.505,974,782.34-2,853.12 1.22 -16.47 2,918.80 7.07 2,917.29 -13.67 26.99125.02 688,797.865,974,780.68-2,876.79 1.83 -17.75 2,942.60 7.23 2,940.91 -15.31 29.46122.18 688,800.375,974,779.11-2,900.41 1.63 -19.20 2,966.40 7.43 2,964.51 -16.91 32.04121.34 688,802.995,974,777.58-2,924.01 0.95 -20.76 2,990.25 7.68 2,988.16 -18.55 34.71121.85 688,805.705,974,776.00-2,947.66 1.09 -22.39 3,014.10 7.97 3,011.78 -20.27 37.46122.29 688,808.505,974,774.35-2,971.28 1.24 -24.05 3,038.00 8.25 3,035.44 -22.06 40.32121.73 688,811.405,974,772.63-2,994.94 1.22 -25.77 3,061.80 8.43 3,058.99 -23.84 43.28120.33 688,814.405,974,770.93-3,018.49 1.14 -27.59 3,085.70 8.65 3,082.63 -25.59 46.37118.78 688,817.535,974,769.26-3,042.13 1.33 -29.54 3,109.60 9.13 3,106.24 -27.33 49.62117.42 688,820.835,974,767.60-3,065.74 2.19 -31.64 3,133.45 9.68 3,129.77 -29.07 53.11115.81 688,824.365,974,765.94-3,089.27 2.56 -33.94 3,157.30 10.18 3,153.26 -30.82 56.83114.47 688,828.135,974,764.29-3,112.76 2.31 -36.45 3,180.95 10.70 3,176.52 -32.57 60.74113.81 688,832.085,974,762.64-3,136.02 2.26 -39.13 3,204.50 11.15 3,199.64 -34.35 64.83113.30 688,836.225,974,760.96-3,159.14 1.95 -41.95 3,227.95 11.60 3,222.63 -36.16 69.09112.56 688,840.525,974,759.27-3,182.13 2.02 -44.92 3,251.50 12.13 3,245.68 -37.98 73.58111.63 688,845.055,974,757.56-3,205.18 2.39 -48.08 3,274.90 12.72 3,268.53 -39.79 78.28110.68 688,849.795,974,755.86-3,228.03 2.67 -51.42 3,298.35 13.20 3,291.39 -41.62 83.21109.90 688,854.775,974,754.16-3,250.89 2.18 -54.98 3,321.80 13.80 3,314.19 -43.47 88.36109.65 688,859.965,974,752.44-3,273.69 2.57 -58.71 3,345.30 14.47 3,336.98 -45.39 93.77109.58 688,865.415,974,750.65-3,296.48 2.85 -62.64 3,368.80 14.95 3,359.71 -47.37 99.40109.13 688,871.095,974,748.82-3,319.21 2.10 -66.74 3,392.25 15.35 3,382.34 -49.37 105.19108.87 688,876.935,974,746.97-3,341.84 1.73 -70.98 3,415.75 15.70 3,404.98 -51.41 111.14109.01 688,882.935,974,745.08-3,364.48 1.50 -75.34 3,439.25 15.97 3,427.59 -53.51 117.20109.24 688,889.045,974,743.13-3,387.09 1.18 -79.77 3,462.75 16.12 3,450.18 -55.67 123.33109.56 688,895.225,974,741.13-3,409.68 0.74 -84.23 3,486.15 16.30 3,472.65 -57.88 129.47110.08 688,901.425,974,739.07-3,432.15 0.99 -88.68 3,509.65 16.62 3,495.18 -60.19 135.72110.50 688,907.725,974,736.92-3,454.68 1.45 -93.18 3,533.15 17.10 3,517.67 -62.60 142.09110.82 688,914.165,974,734.67-3,477.17 2.08 -97.75 3,556.55 17.77 3,540.00 -65.11 148.64111.28 688,920.765,974,732.32-3,499.50 2.92 -102.42 3,580.05 18.47 3,562.33 -67.79 155.44111.61 688,927.635,974,729.82-3,521.83 3.01 -107.25 3,603.60 19.37 3,584.61 -70.62 162.53111.99 688,934.795,974,727.16-3,544.11 3.86 -112.26 3,627.10 20.47 3,606.70 -73.66 169.94112.53 688,942.275,974,724.32-3,566.20 4.75 -117.46 3,650.60 21.45 3,628.65 -76.92 177.69113.12 688,950.105,974,721.25-3,588.15 4.27 -122.86 3,674.10 22.40 3,650.45 -80.41 185.74113.70 688,958.235,974,717.97-3,609.95 4.15 -128.42 3,697.65 23.47 3,672.14 -84.14 194.12114.32 688,966.715,974,714.45-3,631.64 4.66 -134.17 3,721.15 24.58 3,693.60 -88.14 202.81115.04 688,975.505,974,710.67-3,653.10 4.89 -140.07 3,744.70 25.60 3,714.93 -92.42 211.83115.74 688,984.625,974,706.62-3,674.43 4.51 -146.14 3,768.20 26.47 3,736.04 -96.95 221.10116.33 688,994.005,974,702.32-3,695.54 3.86 -152.31 3,791.75 27.37 3,757.04 -101.72 230.63116.89 689,003.655,974,697.79-3,716.54 3.97 -158.60 3,815.30 28.25 3,777.87 -106.74 240.41117.47 689,013.545,974,693.02-3,737.37 3.91 -165.00 3/28/2025 6:31:10PM COMPASS 5000.17 Build 04 Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Lisburne L1 Standard Proposal Report Well: Wellbore: Plan: L1-10 Plan: L1-10A Survey Calculation Method:Minimum Curvature L1-10A Planned RKB @ 40.50usft Design:L1-10A wp03 Database:Alaska MD Reference:L1-10A Planned RKB @ 40.50usft North Reference: Well Plan: L1-10 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 -3,757.98 Vert Section 3,838.80 29.17 3,798.48 -112.00 250.39118.07 689,023.665,974,688.01-3,757.98 4.10 -171.48 3,862.30 30.17 3,818.90 -117.52 260.63118.58 689,034.035,974,682.75-3,778.40 4.39 -178.06 3,885.90 31.22 3,839.19 -123.32 271.19118.94 689,044.745,974,677.22-3,798.69 4.52 -184.80 3,909.50 32.35 3,859.25 -129.36 282.06119.16 689,055.755,974,671.46-3,818.75 4.81 -191.71 3,932.70 33.47 3,878.73 -135.52 293.06119.40 689,066.905,974,665.58-3,838.23 4.86 -198.67 3,955.90 34.65 3,897.95 -141.93 304.36119.72 689,078.365,974,659.45-3,857.45 5.14 -205.79 3,979.05 35.93 3,916.84 -148.60 315.95120.05 689,090.115,974,653.08-3,876.34 5.59 -213.05 4,002.20 37.17 3,935.44 -155.53 327.87120.32 689,102.205,974,646.45-3,894.94 5.40 -220.48 4,025.40 38.12 3,953.81 -162.70 340.09120.51 689,114.605,974,639.59-3,913.31 4.13 -228.07 4,048.50 38.87 3,971.89 -170.01 352.47120.58 689,127.165,974,632.60-3,931.39 3.25 -235.74 4,056.50 39.05 3,978.11 -172.57 356.80120.63 689,131.555,974,630.15-3,937.61 2.23 -238.42 13 3/8" 4,071.65 39.38 3,989.85 -177.46 365.04120.71 689,139.915,974,625.47-3,949.35 2.23 -243.51 4,094.75 39.70 4,007.66 -185.00 377.66121.02 689,152.725,974,618.25-3,967.16 1.63 -251.29 4,100.00 39.75 4,011.70 -186.73 380.54121.10 689,155.635,974,616.59-3,971.20 1.36 -253.05 KOP : Start Dir 12.3º/100' : 4100' MD, 4011.7'TVD : 160° RT TF 4,117.00 37.79 4,024.96 -192.32 389.60122.24 689,164.835,974,611.23-3,984.46 12.30 -258.56 End Dir : 4117' MD, 4024.96' TVD - 9 5/8" x 12 1/4" Window 4,137.00 37.79 4,040.76 -198.86 399.96122.24 689,175.365,974,604.96-4,000.26 0.00 -264.79 Start Dir 5º/100' : 4137' MD, 4040.76'TVD 4,200.00 35.94 4,091.17 -220.16 431.15126.51 689,207.075,974,584.45-4,050.67 5.00 -282.79 4,300.00 33.37 4,173.46 -256.76 474.54134.05 689,251.365,974,548.95-4,132.96 5.00 -304.64 4,400.00 31.31 4,257.99 -296.55 510.12142.58 689,287.935,974,510.08-4,217.49 5.00 -318.09 4,500.00 29.88 4,344.12 -339.21 537.62152.00 689,316.495,974,468.12-4,303.62 5.00 -323.04 4,559.10 29.37 4,395.50 -365.64 549.99157.89 689,329.525,974,442.01-4,355.00 5.00 -321.96 SV1 4,600.00 29.17 4,431.18 -384.42 556.83162.06 689,336.845,974,423.41-4,390.68 5.00 -319.46 4,700.00 29.24 4,518.52 -431.83 567.62172.31 689,348.815,974,376.29-4,478.02 5.00 -307.37 4,800.00 30.07 4,605.48 -481.10 569.88182.29 689,352.325,974,327.10-4,564.98 5.00 -286.86 4,900.00 31.61 4,691.39 -531.83 563.62191.58 689,347.335,974,276.22-4,650.89 5.00 -258.09 5,000.00 33.76 4,775.60 -583.66 548.87199.95 689,333.905,974,224.05-4,735.10 5.00 -221.28 5,100.00 36.41 4,857.46 -636.17 525.75207.33 689,312.115,974,170.98-4,816.96 5.00 -176.71 5,102.54 36.48 4,859.50 -637.50 525.06207.51 689,311.455,974,169.62-4,819.00 5.00 -175.48 UG4 5,200.00 39.46 4,936.36 -688.97 494.43213.79 689,282.135,974,117.40-4,895.86 5.00 -124.72 5,300.00 42.82 5,011.69 -741.66 455.16219.42 689,244.205,974,063.74-4,971.19 5.00 -65.70 5,400.00 46.42 5,082.88 -793.85 408.23224.36 689,198.605,974,010.40-5,042.38 5.00 -0.10 5,402.35 46.51 5,084.50 -795.06 407.03224.47 689,197.435,974,009.15-5,044.00 5.00 1.52 UG3 5,500.00 50.21 5,149.39 -845.12 353.99228.73 689,145.675,973,957.78-5,108.89 5.00 71.58 5,551.28 52.21 5,181.51 -870.93 323.48230.78 689,115.825,973,931.21-5,141.01 5.00 110.52 End Dir : 5551.28' MD, 5181.51' TVD 5,600.00 52.21 5,211.36 -895.28 293.65230.78 689,086.625,973,906.12-5,170.86 0.00 148.18 5,700.00 52.21 5,272.63 -945.25 232.42230.78 689,026.675,973,854.63-5,232.13 0.00 225.48 5,800.00 52.21 5,333.90 -995.22 171.20230.78 688,966.725,973,803.14-5,293.40 0.00 302.78 3/28/2025 6:31:10PM COMPASS 5000.17 Build 04 Page 8 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Lisburne L1 Standard Proposal Report Well: Wellbore: Plan: L1-10 Plan: L1-10A Survey Calculation Method:Minimum Curvature L1-10A Planned RKB @ 40.50usft Design:L1-10A wp03 Database:Alaska MD Reference:L1-10A Planned RKB @ 40.50usft North Reference: Well Plan: L1-10 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 -5,354.67 Vert Section 5,900.00 52.21 5,395.17 -1,045.19 109.97230.78 688,906.775,973,751.64-5,354.67 0.00 380.08 6,000.00 52.21 5,456.44 -1,095.16 48.74230.78 688,846.835,973,700.15-5,415.94 0.00 457.38 6,100.00 52.21 5,517.72 -1,145.13 -12.49230.78 688,786.885,973,648.66-5,477.22 0.00 534.68 6,186.15 52.21 5,570.50 -1,188.18 -65.23230.78 688,735.245,973,604.30-5,530.00 0.00 601.27 UG1 6,200.00 52.21 5,578.99 -1,195.10 -73.71230.78 688,726.935,973,597.17-5,538.49 0.00 611.98 6,300.00 52.21 5,640.26 -1,245.07 -134.94230.78 688,666.995,973,545.67-5,599.76 0.00 689.28 6,400.00 52.21 5,701.53 -1,295.04 -196.17230.78 688,607.045,973,494.18-5,661.03 0.00 766.58 6,500.00 52.21 5,762.80 -1,345.01 -257.40230.78 688,547.095,973,442.69-5,722.30 0.00 843.88 6,600.00 52.21 5,824.07 -1,394.98 -318.63230.78 688,487.155,973,391.19-5,783.57 0.00 921.18 6,700.00 52.21 5,885.34 -1,444.95 -379.85230.78 688,427.205,973,339.70-5,844.84 0.00 998.48 6,800.00 52.21 5,946.61 -1,494.92 -441.08230.78 688,367.255,973,288.21-5,906.11 0.00 1,075.78 6,900.00 52.21 6,007.88 -1,544.89 -502.31230.78 688,307.315,973,236.72-5,967.38 0.00 1,153.08 7,000.00 52.21 6,069.15 -1,594.86 -563.54230.78 688,247.365,973,185.22-6,028.65 0.00 1,230.38 7,100.00 52.21 6,130.42 -1,644.83 -624.76230.78 688,187.415,973,133.73-6,089.92 0.00 1,307.69 7,162.14 52.21 6,168.50 -1,675.89 -662.81230.78 688,150.165,973,101.73-6,128.00 0.00 1,355.72 WS2 7,200.00 52.21 6,191.70 -1,694.80 -685.99230.78 688,127.465,973,082.24-6,151.20 0.00 1,384.99 7,300.00 52.21 6,252.97 -1,744.77 -747.22230.78 688,067.525,973,030.74-6,212.47 0.00 1,462.29 7,400.00 52.21 6,314.24 -1,794.74 -808.45230.78 688,007.575,972,979.25-6,273.74 0.00 1,539.59 7,468.98 52.21 6,356.50 -1,829.21 -850.68230.78 687,966.225,972,943.73-6,316.00 0.00 1,592.91 WS1 7,500.00 52.21 6,375.51 -1,844.71 -869.68230.78 687,947.625,972,927.76-6,335.01 0.00 1,616.89 7,600.00 52.21 6,436.78 -1,894.69 -930.90230.78 687,887.685,972,876.27-6,396.28 0.00 1,694.19 7,700.00 52.21 6,498.05 -1,944.66 -992.13230.78 687,827.735,972,824.77-6,457.55 0.00 1,771.49 7,800.00 52.21 6,559.32 -1,994.63 -1,053.36230.78 687,767.785,972,773.28-6,518.82 0.00 1,848.79 7,839.46 52.21 6,583.50 -2,014.35 -1,077.52230.78 687,744.135,972,752.96-6,543.00 0.00 1,879.29 CM3 7,900.00 52.21 6,620.59 -2,044.60 -1,114.59230.78 687,707.845,972,721.79-6,580.09 0.00 1,926.09 8,000.00 52.21 6,681.86 -2,094.57 -1,175.81230.78 687,647.895,972,670.30-6,641.36 0.00 2,003.39 8,100.00 52.21 6,743.13 -2,144.54 -1,237.04230.78 687,587.945,972,618.80-6,702.63 0.00 2,080.69 8,200.00 52.21 6,804.40 -2,194.51 -1,298.27230.78 687,528.005,972,567.31-6,763.90 0.00 2,157.99 8,300.00 52.21 6,865.67 -2,244.48 -1,359.50230.78 687,468.055,972,515.82-6,825.17 0.00 2,235.29 8,400.00 52.21 6,926.95 -2,294.45 -1,420.72230.78 687,408.105,972,464.32-6,886.45 0.00 2,312.59 8,500.00 52.21 6,988.22 -2,344.42 -1,481.95230.78 687,348.155,972,412.83-6,947.72 0.00 2,389.89 8,600.00 52.21 7,049.49 -2,394.39 -1,543.18230.78 687,288.215,972,361.34-7,008.99 0.00 2,467.19 8,700.00 52.21 7,110.76 -2,444.36 -1,604.41230.78 687,228.265,972,309.85-7,070.26 0.00 2,544.49 8,800.00 52.21 7,172.03 -2,494.33 -1,665.64230.78 687,168.315,972,258.35-7,131.53 0.00 2,621.80 8,900.00 52.21 7,233.30 -2,544.30 -1,726.86230.78 687,108.375,972,206.86-7,192.80 0.00 2,699.10 9,000.00 52.21 7,294.57 -2,594.27 -1,788.09230.78 687,048.425,972,155.37-7,254.07 0.00 2,776.40 9,100.00 52.21 7,355.84 -2,644.24 -1,849.32230.78 686,988.475,972,103.88-7,315.34 0.00 2,853.70 9,200.00 52.21 7,417.11 -2,694.21 -1,910.55230.78 686,928.535,972,052.38-7,376.61 0.00 2,931.00 9,300.00 52.21 7,478.38 -2,744.18 -1,971.77230.78 686,868.585,972,000.89-7,437.88 0.00 3,008.30 9,347.52 52.21 7,507.50 -2,767.93 -2,000.87230.78 686,840.095,971,976.42-7,467.00 0.00 3,045.03 CM1 3/28/2025 6:31:10PM COMPASS 5000.17 Build 04 Page 9 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Lisburne L1 Standard Proposal Report Well: Wellbore: Plan: L1-10 Plan: L1-10A Survey Calculation Method:Minimum Curvature L1-10A Planned RKB @ 40.50usft Design:L1-10A wp03 Database:Alaska MD Reference:L1-10A Planned RKB @ 40.50usft North Reference: Well Plan: L1-10 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 -7,499.15 Vert Section 9,400.00 52.21 7,539.65 -2,794.15 -2,033.00230.78 686,808.635,971,949.40-7,499.15 0.00 3,085.60 9,493.47 52.21 7,596.92 -2,840.86 -2,090.23230.78 686,752.605,971,901.27-7,556.42 0.00 3,157.85 Start Dir 4º/100' : 9493.47' MD, 7596.92'TVD 9,500.00 51.95 7,600.94 -2,844.12 -2,094.22230.76 686,748.695,971,897.91-7,560.44 4.00 3,162.89 9,600.00 47.97 7,665.26 -2,892.75 -2,153.33230.34 686,690.835,971,847.81-7,624.76 4.00 3,237.69 9,700.00 43.98 7,734.74 -2,938.85 -2,208.49229.87 686,636.855,971,800.34-7,694.24 4.00 3,307.83 9,799.93 40.00 7,809.00 -2,982.16 -2,259.40229.33 686,587.055,971,755.76-7,768.50 4.00 3,372.91 End Dir : 9799.93' MD, 7809' TVD 9,852.80 40.00 7,849.50 -3,004.31 -2,285.18229.33 686,561.845,971,732.98-7,809.00 0.00 3,405.96 THRZ 9,900.00 40.00 7,885.66 -3,024.08 -2,308.19229.33 686,539.345,971,712.63-7,845.16 0.00 3,435.46 10,000.00 40.00 7,962.26 -3,065.97 -2,356.94229.33 686,491.655,971,669.53-7,921.76 0.00 3,497.98 10,100.00 40.00 8,038.87 -3,107.86 -2,405.70229.33 686,443.975,971,626.43-7,998.37 0.00 3,560.49 10,119.10 40.00 8,053.50 -3,115.86 -2,415.01229.33 686,434.865,971,618.19-8,013.00 0.00 3,572.43 BHRZ/Top Put River 10,172.62 40.00 8,094.50 -3,138.28 -2,441.11229.33 686,409.345,971,595.13-8,054.00 0.00 3,605.89 LCU/Top Kingak 10,175.00 40.00 8,096.32 -3,139.28 -2,442.26229.33 686,408.215,971,594.10-8,055.82 0.00 3,607.37 7" x 8 1/2" 10,175.23 40.00 8,096.50 -3,139.38 -2,442.38229.33 686,408.105,971,594.00-8,056.00 0.00 3,607.52 Start Dir 5º/100' : 10175.23' MD, 8096.5'TVD - TSGR 10,200.00 41.24 8,115.30 -3,149.87 -2,454.62229.42 686,396.135,971,583.20-8,074.80 5.00 3,623.20 10,204.27 41.45 8,118.50 -3,151.71 -2,456.76229.44 686,394.045,971,581.31-8,078.00 5.00 3,625.94 TSHU 10,285.59 45.51 8,177.50 -3,187.98 -2,499.35229.72 686,352.375,971,543.98-8,137.00 5.00 3,680.42 TSAD 10,300.00 46.23 8,187.53 -3,194.66 -2,507.24229.76 686,344.655,971,537.10-8,147.03 5.00 3,690.49 10,400.00 51.23 8,253.47 -3,243.05 -2,564.73230.05 686,288.415,971,487.29-8,212.97 5.00 3,763.73 10,461.19 54.28 8,290.50 -3,274.27 -2,602.10230.20 686,251.835,971,455.13-8,250.00 5.00 3,811.25 Top Z3 10,500.00 56.22 8,312.62 -3,294.66 -2,626.62230.30 686,227.835,971,434.13-8,272.12 5.00 3,842.38 10,569.53 59.70 8,349.50 -3,332.25 -2,672.01230.45 686,183.415,971,395.42-8,309.00 5.00 3,899.93 Top 2C 10,600.00 61.22 8,364.52 -3,349.11 -2,692.46230.52 686,163.395,971,378.05-8,324.02 5.00 3,925.83 10,700.00 66.22 8,408.79 -3,405.99 -2,761.74230.72 686,095.575,971,319.45-8,368.29 5.00 4,013.45 10,800.00 71.21 8,445.08 -3,464.84 -2,833.94230.90 686,024.885,971,258.80-8,404.58 5.00 4,104.57 10,801.31 71.28 8,445.50 -3,465.62 -2,834.90230.90 686,023.945,971,258.00-8,405.00 5.00 4,105.78 Top 2B 10,868.92 74.66 8,465.30 -3,506.33 -2,885.11231.02 685,974.775,971,216.04-8,424.80 5.00 4,169.04 End Dir : 10868.92' MD, 8465.3' TVD 10,900.00 74.66 8,473.53 -3,525.19 -2,908.41231.02 685,951.965,971,196.61-8,433.03 0.00 4,198.39 11,000.00 74.66 8,499.99 -3,585.84 -2,983.38231.02 685,878.545,971,134.08-8,459.49 0.00 4,292.80 11,076.88 74.66 8,520.33 -3,632.48 -3,041.02231.02 685,822.105,971,086.02-8,479.83 0.00 4,365.38 Start Dir 5º/100' : 11076.88' MD, 8520.33'TVD 11,100.00 74.92 8,526.39 -3,646.33 -3,058.50232.19 685,804.975,971,071.73-8,485.89 5.00 4,387.26 11,200.00 76.13 8,551.40 -3,702.26 -3,137.50237.20 685,727.415,971,013.83-8,510.90 5.00 4,483.09 3/28/2025 6:31:10PM COMPASS 5000.17 Build 04 Page 10 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Lisburne L1 Standard Proposal Report Well: Wellbore: Plan: L1-10 Plan: L1-10A Survey Calculation Method:Minimum Curvature L1-10A Planned RKB @ 40.50usft Design:L1-10A wp03 Database:Alaska MD Reference:L1-10A Planned RKB @ 40.50usft North Reference: Well Plan: L1-10 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 -8,533.76 Vert Section 11,300.00 77.45 8,574.26 -3,751.38 -3,221.51242.16 685,644.675,970,962.61-8,533.76 5.00 4,580.27 11,400.00 78.85 8,594.81 -3,793.33 -3,309.89247.06 685,557.375,970,918.46-8,554.31 5.00 4,678.05 11,414.04 79.05 8,597.50 -3,798.62 -3,322.61247.74 685,544.795,970,912.85-8,557.00 5.00 4,691.78 Top 1B 11,500.00 80.33 8,612.89 -3,827.77 -3,401.98251.91 685,466.185,970,881.71-8,572.39 5.00 4,775.70 11,600.00 81.88 8,628.35 -3,854.46 -3,497.08256.73 685,371.805,970,852.64-8,587.85 5.00 4,872.47 11,700.00 83.49 8,641.09 -3,873.18 -3,594.45261.50 685,274.935,970,831.48-8,600.59 5.00 4,967.63 11,791.67 85.00 8,650.29 -3,883.22 -3,685.08265.85 685,184.595,970,819.16-8,609.79 5.00 5,052.82 End Dir : 11791.67' MD, 8650.29' TVD 11,800.00 85.00 8,651.01 -3,883.82 -3,693.35265.85 685,176.335,970,818.35-8,610.51 0.00 5,060.45 11,900.00 85.00 8,659.73 -3,891.03 -3,792.71265.85 685,077.205,970,808.65-8,619.23 0.00 5,152.11 11,931.81 85.00 8,662.50 -3,893.32 -3,824.31265.85 685,045.665,970,805.56-8,622.00 0.00 5,181.27 Top 1A 11,941.67 85.00 8,663.36 -3,894.03 -3,834.11265.85 685,035.885,970,804.60-8,622.86 0.00 5,190.31 Start Dir 4º/100' : 11941.67' MD, 8663.36'TVD 12,000.00 87.33 8,667.26 -3,898.24 -3,892.16265.85 684,977.975,970,798.93-8,626.76 4.00 5,243.85 12,052.07 89.42 8,668.74 -3,902.01 -3,944.07265.85 684,926.175,970,793.86-8,628.24 4.00 5,291.74 End Dir : 12052.07' MD, 8668.74' TVD 12,100.00 89.42 8,669.22 -3,905.48 -3,991.87265.85 684,878.485,970,789.19-8,628.72 0.00 5,335.84 12,200.00 89.42 8,670.24 -3,912.71 -4,091.60265.85 684,778.965,970,779.44-8,629.74 0.00 5,427.85 12,225.09 89.42 8,670.50 -3,914.53 -4,116.62265.85 684,754.005,970,777.00-8,630.00 0.00 5,450.93 Start Dir 2º/100' : 12225.09' MD, 8670.5'TVD 12,304.07 90.97 8,670.23 -3,920.43 -4,195.38265.58 684,675.425,970,769.12-8,629.73 2.00 5,523.67 End Dir : 12304.07' MD, 8670.23' TVD 12,400.00 90.97 8,668.60 -3,927.82 -4,291.01265.58 684,580.015,970,759.32-8,628.10 0.00 5,612.10 12,500.00 90.97 8,666.91 -3,935.52 -4,390.70265.58 684,480.555,970,749.11-8,626.41 0.00 5,704.28 12,600.00 90.97 8,665.21 -3,943.23 -4,490.39265.58 684,381.105,970,738.90-8,624.71 0.00 5,796.46 12,700.00 90.97 8,663.51 -3,950.93 -4,590.07265.58 684,281.645,970,728.69-8,623.01 0.00 5,888.64 12,800.00 90.97 8,661.82 -3,958.64 -4,689.76265.58 684,182.185,970,718.48-8,621.32 0.00 5,980.82 12,900.00 90.97 8,660.12 -3,966.34 -4,789.45265.58 684,082.725,970,708.27-8,619.62 0.00 6,073.00 12,966.78 90.97 8,658.99 -3,971.49 -4,856.02265.58 684,016.315,970,701.45-8,618.49 0.00 6,134.56 Start Dir 2º/100' : 12966.78' MD, 8658.99'TVD 13,000.00 90.31 8,658.61 -3,974.04 -4,889.14265.58 683,983.275,970,698.06-8,618.11 2.00 6,165.19 13,065.40 89.00 8,659.01 -3,979.08 -4,954.35265.59 683,918.215,970,691.39-8,618.51 2.00 6,225.48 End Dir : 13065.4' MD, 8659.01' TVD 13,100.00 89.00 8,659.61 -3,981.74 -4,988.84265.59 683,883.805,970,687.86-8,619.11 0.00 6,257.37 13,200.00 89.00 8,661.36 -3,989.43 -5,088.53265.59 683,784.345,970,677.67-8,620.86 0.00 6,349.54 13,265.40 89.00 8,662.50 -3,994.45 -5,153.72265.59 683,719.305,970,671.00-8,622.00 0.00 6,409.82 Start Dir 2º/100' : 13265.4' MD, 8662.5'TVD 13,300.00 88.99 8,663.11 -3,997.32 -5,188.20264.90 683,684.915,970,667.26-8,622.61 2.00 6,441.80 13,318.29 88.99 8,663.43 -3,999.01 -5,206.41264.53 683,666.755,970,665.12-8,622.93 2.00 6,458.76 End Dir : 13318.29' MD, 8663.43' TVD 13,400.00 88.99 8,664.87 -4,006.79 -5,287.73264.53 683,585.655,970,655.29-8,624.37 0.00 6,534.65 13,500.00 88.99 8,666.64 -4,016.32 -5,387.26264.53 683,486.405,970,643.26-8,626.14 0.00 6,627.52 13,600.00 88.99 8,668.40 -4,025.85 -5,486.79264.53 683,387.145,970,631.24-8,627.90 0.00 6,720.39 3/28/2025 6:31:10PM COMPASS 5000.17 Build 04 Page 11 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Lisburne L1 Standard Proposal Report Well: Wellbore: Plan: L1-10 Plan: L1-10A Survey Calculation Method:Minimum Curvature L1-10A Planned RKB @ 40.50usft Design:L1-10A wp03 Database:Alaska MD Reference:L1-10A Planned RKB @ 40.50usft North Reference: Well Plan: L1-10 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 -8,629.67 Vert Section 13,700.00 88.99 8,670.17 -4,035.37 -5,586.32264.53 683,287.895,970,619.21-8,629.67 0.00 6,813.27 13,800.00 88.99 8,671.94 -4,044.90 -5,685.85264.53 683,188.645,970,607.18-8,631.44 0.00 6,906.14 13,858.06 88.99 8,672.96 -4,050.43 -5,743.64264.53 683,131.015,970,600.19-8,632.46 0.00 6,960.06 Start Dir 2º/100' : 13858.06' MD, 8672.96'TVD 13,900.00 89.83 8,673.40 -4,054.43 -5,785.38264.53 683,089.385,970,595.15-8,632.90 2.00 6,999.02 13,983.66 91.50 8,672.43 -4,062.41 -5,868.65264.52 683,006.355,970,585.07-8,631.93 2.00 7,076.72 End Dir : 13983.66' MD, 8672.43' TVD 14,000.00 91.50 8,672.00 -4,063.97 -5,884.91264.52 682,990.135,970,583.10-8,631.50 0.00 7,091.90 14,100.00 91.50 8,669.38 -4,073.52 -5,984.42264.52 682,890.905,970,571.06-8,628.88 0.00 7,184.76 14,133.66 91.50 8,668.50 -4,076.73 -6,017.92264.52 682,857.505,970,567.00-8,628.00 0.00 7,216.02 Start Dir 2º/100' : 14133.66' MD, 8668.5'TVD 14,200.00 90.51 8,667.34 -4,083.57 -6,083.89263.64 682,791.725,970,558.50-8,626.84 2.00 7,277.82 14,246.55 89.81 8,667.21 -4,088.98 -6,130.13263.02 682,745.645,970,551.93-8,626.71 2.00 7,321.41 End Dir : 14246.55' MD, 8667.21' TVD 14,300.00 89.81 8,667.38 -4,095.48 -6,183.18263.02 682,692.775,970,544.10-8,626.88 0.00 7,371.57 14,400.00 89.81 8,667.70 -4,107.64 -6,282.44263.02 682,593.865,970,529.45-8,627.20 0.00 7,465.40 14,500.00 89.81 8,668.03 -4,119.79 -6,381.69263.02 682,494.945,970,514.80-8,627.53 0.00 7,559.23 14,600.00 89.81 8,668.35 -4,131.95 -6,480.95263.02 682,396.035,970,500.15-8,627.85 0.00 7,653.07 14,700.00 89.81 8,668.67 -4,144.11 -6,580.21263.02 682,297.115,970,485.50-8,628.17 0.00 7,746.90 14,800.00 89.81 8,669.00 -4,156.26 -6,679.47263.02 682,198.205,970,470.85-8,628.50 0.00 7,840.74 14,900.00 89.81 8,669.32 -4,168.42 -6,778.73263.02 682,099.285,970,456.20-8,628.82 0.00 7,934.57 15,000.00 89.81 8,669.65 -4,180.57 -6,877.98263.02 682,000.375,970,441.55-8,629.15 0.00 8,028.40 15,100.00 89.81 8,669.97 -4,192.73 -6,977.24263.02 681,901.465,970,426.90-8,629.47 0.00 8,122.24 15,200.00 89.81 8,670.30 -4,204.89 -7,076.50263.02 681,802.545,970,412.25-8,629.80 0.00 8,216.07 15,263.13 89.81 8,670.50 -4,212.56 -7,139.16263.02 681,740.105,970,403.00-8,630.00 0.00 8,275.31 Start Dir 2º/100' : 15263.13' MD, 8670.5'TVD 15,295.04 90.43 8,670.43 -4,216.40 -7,170.84263.18 681,708.535,970,398.37-8,629.93 2.00 8,305.23 End Dir : 15295.04' MD, 8670.43' TVD 15,300.00 90.43 8,670.39 -4,216.98 -7,175.76263.18 681,703.625,970,397.66-8,629.89 0.00 8,309.88 15,400.00 90.43 8,669.64 -4,228.86 -7,275.05263.18 681,604.665,970,383.29-8,629.14 0.00 8,403.61 15,500.00 90.43 8,668.89 -4,240.73 -7,374.34263.18 681,505.715,970,368.92-8,628.39 0.00 8,497.35 15,600.00 90.43 8,668.13 -4,252.61 -7,473.63263.18 681,406.765,970,354.55-8,627.63 0.00 8,591.08 15,700.00 90.43 8,667.38 -4,264.48 -7,572.92263.18 681,307.805,970,340.18-8,626.88 0.00 8,684.81 15,800.00 90.43 8,666.63 -4,276.36 -7,672.21263.18 681,208.855,970,325.81-8,626.13 0.00 8,778.55 15,900.00 90.43 8,665.88 -4,288.23 -7,771.50263.18 681,109.905,970,311.44-8,625.38 0.00 8,872.28 16,000.00 90.43 8,665.12 -4,300.11 -7,870.79263.18 681,010.945,970,297.07-8,624.62 0.00 8,966.01 16,100.00 90.43 8,664.37 -4,311.98 -7,970.08263.18 680,911.995,970,282.70-8,623.87 0.00 9,059.74 16,200.00 90.43 8,663.62 -4,323.85 -8,069.37263.18 680,813.045,970,268.33-8,623.12 0.00 9,153.48 16,301.15 90.43 8,662.85 -4,335.87 -8,169.80263.18 680,712.955,970,253.80-8,622.35 0.00 9,248.29 Start Dir 2º/100' : 16301.15' MD, 8662.85'TVD 16,347.73 89.50 8,662.88 -4,341.40 -8,216.05263.18 680,666.855,970,247.11-8,622.38 2.00 9,291.95 End Dir : 16347.73' MD, 8662.88' TVD 16,400.00 89.50 8,663.34 -4,347.60 -8,267.95263.18 680,615.135,970,239.60-8,622.84 0.00 9,340.94 16,500.00 89.50 8,664.21 -4,359.48 -8,367.24263.18 680,516.185,970,225.23-8,623.71 0.00 9,434.68 16,600.00 89.50 8,665.08 -4,371.35 -8,466.53263.18 680,417.235,970,210.86-8,624.58 0.00 9,528.41 3/28/2025 6:31:10PM COMPASS 5000.17 Build 04 Page 12 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Lisburne L1 Standard Proposal Report Well: Wellbore: Plan: L1-10 Plan: L1-10A Survey Calculation Method:Minimum Curvature L1-10A Planned RKB @ 40.50usft Design:L1-10A wp03 Database:Alaska MD Reference:L1-10A Planned RKB @ 40.50usft North Reference: Well Plan: L1-10 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 -8,625.00 Vert Section 16,647.73 89.50 8,665.50 -4,377.02 -8,513.91263.18 680,370.005,970,204.00-8,625.00 0.00 9,573.14 Total Depth : 16647.73' MD, 8665.5' TVD Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Targets Dip Angle (°) Dip Dir. (°) L1-10A wp02 tgt01 8,096.50 5,971,594.00 686,408.10-3,139.38 -2,442.380.00 0.00 - plan hits target center - Point L1-10A wp02 tgt04 8,662.50 5,970,671.00 683,719.30-3,994.45 -5,153.720.00 0.00 - plan hits target center - Point L1-10A wp02 tgt02 8,663.36 5,970,804.60 685,035.88-3,894.03 -3,834.120.00 0.00 - plan hits target center - Point L1-10A wp02 tgt05 8,668.50 5,970,567.00 682,857.50-4,076.73 -6,017.920.00 0.00 - plan hits target center - Point L1-10A wp02 tgt03 8,670.50 5,970,777.00 684,754.00-3,914.53 -4,116.620.00 0.00 - plan hits target center - Point L1-10A wp02 tgt07 8,665.50 5,970,204.00 680,370.00-4,377.02 -8,513.910.00 0.00 - plan hits target center - Point L1-10A wp02 tgt06 8,670.50 5,970,403.00 681,740.10-4,212.56 -7,139.160.00 0.00 - plan hits target center - Point Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 9 5/8" x 12 1/4" Window4,024.964,117.00 9-5/8 12-1/4 7" x 8 1/2"8,096.3210,175.00 78-1/2 4 1/2" x 6 1/4"8,665.5016,647.73 4-1/2 6-1/4 3/28/2025 6:31:10PM COMPASS 5000.17 Build 04 Page 13 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp North Slope, LLC Lisburne L1 Standard Proposal Report Well: Wellbore: Plan: L1-10 Plan: L1-10A Survey Calculation Method:Minimum Curvature L1-10A Planned RKB @ 40.50usft Design:L1-10A wp03 Database:Alaska MD Reference:L1-10A Planned RKB @ 40.50usft North Reference: Well Plan: L1-10 True Measured Depth (usft) Vertical Depth (usft) Dip Direction (°)Name Lithology Dip (°) Formations Vertical Depth SS 10,461.19 8,290.50 Top Z3 7,162.14 6,168.50 WS2 5,402.35 5,084.50 UG3 10,285.59 8,177.50 TSAD 10,175.23 8,096.50 TSGR 10,119.10 8,053.50 BHRZ/Top Put River 11,931.81 8,662.50 Top 1A 7,839.46 6,583.50 CM3 11,414.04 8,597.50 Top 1B 10,569.53 8,349.50 Top 2C 10,172.62 8,094.50 LCU/Top Kingak 10,801.31 8,445.50 Top 2B 5,102.54 4,859.50 UG4 10,204.27 8,118.50 TSHU 4,559.10 4,395.50 SV1 6,186.15 5,570.50 UG1 7,468.98 6,356.50 WS1 9,852.80 7,849.50 THRZ 9,347.52 7,507.50 CM1 Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 4,100.00 4,011.70 -186.73 380.54 KOP : Start Dir 12.3º/100' : 4100' MD, 4011.7'TVD : 160° RT TF 4,117.00 4,024.96 -192.32 389.60 End Dir : 4117' MD, 4024.96' TVD 4,137.00 4,040.76 -198.86 399.96 Start Dir 5º/100' : 4137' MD, 4040.76'TVD 5,551.28 5,181.51 -870.93 323.48 End Dir : 5551.28' MD, 5181.51' TVD 9,493.47 7,596.92 -2,840.86 -2,090.23 Start Dir 4º/100' : 9493.47' MD, 7596.92'TVD 9,799.93 7,809.00 -2,982.16 -2,259.40 End Dir : 9799.93' MD, 7809' TVD 10,175.23 8,096.50 -3,139.37 -2,442.38 Start Dir 5º/100' : 10175.23' MD, 8096.5'TVD 10,868.92 8,465.30 -3,506.33 -2,885.11 End Dir : 10868.92' MD, 8465.3' TVD 11,076.88 8,520.33 -3,632.48 -3,041.02 Start Dir 5º/100' : 11076.88' MD, 8520.33'TVD 11,791.67 8,650.29 -3,883.22 -3,685.08 End Dir : 11791.67' MD, 8650.29' TVD 11,941.67 8,663.36 -3,894.03 -3,834.11 Start Dir 4º/100' : 11941.67' MD, 8663.36'TVD 12,052.07 8,668.74 -3,902.01 -3,944.07 End Dir : 12052.07' MD, 8668.74' TVD 12,225.09 8,670.50 -3,914.53 -4,116.62 Start Dir 2º/100' : 12225.09' MD, 8670.5'TVD 12,304.07 8,670.23 -3,920.43 -4,195.38 End Dir : 12304.07' MD, 8670.23' TVD 12,966.78 8,658.99 -3,971.49 -4,856.02 Start Dir 2º/100' : 12966.78' MD, 8658.99'TVD 13,065.40 8,659.01 -3,979.08 -4,954.35 End Dir : 13065.4' MD, 8659.01' TVD 13,265.40 8,662.50 -3,994.45 -5,153.72 Start Dir 2º/100' : 13265.4' MD, 8662.5'TVD 13,318.29 8,663.43 -3,999.01 -5,206.41 End Dir : 13318.29' MD, 8663.43' TVD 13,858.06 8,672.96 -4,050.43 -5,743.64 Start Dir 2º/100' : 13858.06' MD, 8672.96'TVD 13,983.66 8,672.43 -4,062.41 -5,868.65 End Dir : 13983.66' MD, 8672.43' TVD 14,133.66 8,668.50 -4,076.73 -6,017.92 Start Dir 2º/100' : 14133.66' MD, 8668.5'TVD 14,246.55 8,667.21 -4,088.98 -6,130.13 End Dir : 14246.55' MD, 8667.21' TVD 15,263.13 8,670.50 -4,212.56 -7,139.16 Start Dir 2º/100' : 15263.13' MD, 8670.5'TVD 15,295.04 8,670.43 -4,216.40 -7,170.84 End Dir : 15295.04' MD, 8670.43' TVD 16,301.15 8,662.85 -4,335.87 -8,169.80 Start Dir 2º/100' : 16301.15' MD, 8662.85'TVD 16,347.73 8,662.88 -4,341.40 -8,216.05 End Dir : 16347.73' MD, 8662.88' TVD 16,647.73 8,665.50 -4,377.02 -8,513.91 Total Depth : 16647.73' MD, 8665.5' TVD 3/28/2025 6:31:10PM COMPASS 5000.17 Build 04 Page 14