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Home My WebLink About225-114CAUTION: 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:McLellan, Bryan J (OGC) To:Staudinger, Mark (Mark) Subject:RE: NDB-022 INT1 Cement Slurry - 2nd Stage (PTD 225-114) Date:Thursday, January 29, 2026 4:03:00 PM Attachments:image003.png Approved. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com> Sent: Thursday, January 29, 2026 2:40 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: NDB-022 INT1 Cement Slurry - 2nd Stage (PTD 225-114) Bryan, I just wanted to seek approval to change our slurry design on the INT1 Liner 2nd Stage job from a 15.3ppg VersaCem Type I/II tail cement to a 14.5ppg SwiftCem Type I/II tail cement for the cement job covering the Tuluvak. We’ve put some work into optimizing this slurry and have used it on 2 wells with good results. The slightly lower density appears to be giving us good results in terms of mitigating losses during that job’s execution. Please let me know if you have any questions or want to discuss further. Thanks, Mark Mark Staudinger Senior Drilling Engineer m: +1 520 273 6643 | e: mark.staudinger@santos.com Santos.com | Follow us on LinkedIn, Facebook and Twitter Santos acknowledges the Traditional Owners and Custodians of the lands on which we operate. We pay our respects to their Elders past, present and emerging. Santos Ltd A.B.N. 80 007 550 923Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may beconfidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use,distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email 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 Russell Conwell Senior Drilling Engineer Oil Search Alaska, LLC 601 W 5th Avenue Anchorage, AK, 99501 Re: Pikka Field, Nanushuk Oil Pool, NDBi-022 Oil Search Alaska, LLC Permit to Drill Number: 225-114 Surface Location: 2419 FSL, 2343 FWL, Sec 4, T11N, R6E, UM Bottomhole Location: 4783 FSL, 241 FEL, Sec 24, T12N, R5E, UM Dear Mr. Conwell: 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. Proposed dry ditch sample interval from Attachment 9 accepted with modification of Ivishak (not to exceed 30'). 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 24 th day of November 2025. 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 23,946' TVD: 4,000' 4a. Location of Well (Governmental Section): 7. Property Designation: ADL 392984, 393016 Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1/15/2026 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4373 500' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 70.0' 15. Distance to Nearest Well Open Surface: x- 422,308.31 y- 5,972,803.03 Zone- 4 23.0' to Same Pool: 3980' 16. Deviated wells: Kickoff depth: 347 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 106.61 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20"x34" 215# X-52 Welded 80' Surface Surface 128' 128' 16" 13-3/8" 68# L-80 TXP BTC 3,065' Surface Surface 3,065' 2,386' 12-1/4" 9-5/8" 47# L-80 HYD563 9,085' 2,915' 2340' 12,000' 3,381' Tie Back 9-5/8" 47# L-80 HYD563 2,915' Surface Surface 2,915' 2340' 8-1/2" x 9-7/8"7" 26# L-80 HYD563 6,240' 11,850' 3,365' 18,090' 4,063' 6-1/8" 4-1/2" 12.6# P-110S HYD563 6,006' 17,940' 4,024' 23,946' 4,000' Tubing 4-1/2" 12.6# P-110S HYD563 17,940' Surface Surface 17,940' 4,024' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Russell Conwell Russell Conwell Contact Email:russell.conwell@santos.com Senior Drilling Engineer Contact Phone:1-907-615-2234 Date: Permit to Drill API Number: Permit Approval Number: Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft):Perforation Depth MD (ft): Authorized Title: Authorized Signature: Production Liner Intermediate Authorized Name: Conductor/Structural LengthCasing Cement Volume MDSize Plugs (measured): (including stage data) Grouted to surface See attachment 6 See attachment 6 N/A Effect. Depth MD (ft): Effect. Depth TVD (ft): See attachment 6 18. Casing Program: Top - Setting Depth - BottomSpecifications 1,873 GL / BF Elevation above MSL (ft): Total Depth MD (ft): Total Depth TVD (ft): IS000361277U STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 See attachment 6 1,464 195 FSL, 2,352 FEL, Sec 19, T12N, R6E, UM 4,783 FSL, 241 FEL, Sec 24, T12N, R5E, UM LONS 19-003 601 W Fifth Avenue, Anchorage, AK 99501-6301 Oil Search Alaska, LLC 2,419 FSL, 2,343 FWL, Sec 4, T11N, R6E, UM 393020, 391455, 393018, 393010, 392968 Pikka NDB-022 Pikka/Nanushuk Oil Pool Uncemented Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. s N ype of W L l R L 1 Class: os N s No s N o Dh D hh h 277U o well is p G S S 20 A S S S s No s No S G s No esss Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Senior Drilling Engineer 10/21/2025 225-114 By Grace Christianson at 3:46 pm, Oct 29, 2025 TS 11/3/25 See attached conditions of approval. 50-103-20930-00-00 DSR-10/30/25BJM 11/24/25 11/24/25 11/24/25 NDB-022 (PTD 225-114) Approval 1. Diverter variance 250 - 2. . All a - -25- 4. 5. . Cement 9-. . - : a. - - - -~ 9. 2 . 10. - are met: a. a - - c. d. 11. - a. c. d. e. - : i. A ii. iii. - 12. ----in - Page 1 of 1 October 2025 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill Oil Search (Alaska), LLC, a subsidiary of Santos Limited NDB-027 Dear Sir/Madam, Oil Search (Alaska), LLC hereby applies for a Permit to Drill an onshore development well from the NDB drilling pad on the North Slope of Alaska. NDB-022 is planned to be a horizontal producer targeting the Nanushuk 3. The approximate spud date is anticipated to be January 15th, 2026. Nabors Rig 272 will be used to drill this well. The 16 Surface Hole will TD above the Tuluvak sand and then 13-3/8 casing will be set and cemented. The 12-1/4 Intermediate Hole #1 will be drilled into the Seabee formation at an inclination of ~84 degrees. A 9-5/8 liner will be set and cemented from TD to secure the shoe and cover the Tuluvak sand. A 9-5/8 tieback will be run to the top of the 9-5/8 liner after the 7 liner is set. The 8-1/2 x 9-7/8 Intermediate Hole #2 will be drilled through the Seabee and Nanushuk formations with the casing set in the Nanushuk 3 formation at ~75 degrees. A 7 liner will be set and cemented from TD to cover the Nanushuk formation. The 6-1/8 Production Hole will be geo-steered and landed in the Nanushuk 3 sand and the lateral will be drilled to TD. The well will be completed as a stimulated 4-1/2 liner with frac sleeves and isolation packers. The production liner will be tied back to surface with a 4-1/2 tubing upper completion string. Managed Pressure Drilling (MPD) will be implemented in the Intermediate #2 and Production Hole intervals. Please find enclosed for your review Form 10-401 Permit to Drill with a supporting Application for Permit to Drill containing information as required by 20 AAC 25.005. If there are any questions and/or additional information desired, please contact me at (907) 615-2234 or russell.conwell@santos.com. Respectfully, Russell Conwell Senior Drilling Engineer Oil Search (Alaska), LLC Enclosures: Form 10-401 Permit to Drill Application for Permit to Drill Respectfully, Russell Conwell MPD Application for Permit to Drill NDB-022 Well 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 Requests......................................................................................................12 Attachments.................................................................................................................... ..............................17 Attachment 1: Location Maps..........................................................................................................18 Attachment 2: Directional Plan........................................................................................................20 Attachment 3: BOPE Equipment ......................................................................................................21 Attachment 4: Drilling Hazards.........................................................................................................22 Attachment 5A: Leak Off Test Procedure (Conventional)................................................................24 Attachment 5B: Leak Off Test Procedure (With MPD).....................................................................25 Attachment 6: Cement Summary.....................................................................................................26 Attachment 7: Prognosed Formation Tops......................................................................................30 Attachment 8: Well Schematic.........................................................................................................31 Attachment 9: Formation Evaluation Program................................................................................32 Attachment 10: Wellhead & Tree Diagram......................................................................................33 Attachment 11: Diverter Variance Request NDB Surface Hole Map View.......................................34 Attachment 12: Oil Search Alaska 21-day BOPE Test Schedule Waiver Approval Letter.................35 Attachment 13: Managed Pressure Drilling.....................................................................................38 Attachment 14: As Built Survey NDB Well 27 Conductor Final........................................................40 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 NDB-022. 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 2,419 FSL, 2,343 FWL, Sec 4, T11N, R6E, UM NAD 27 Coordinate System N 5,972,803 E 422,308 Rig KB Elevation 47 above GL Ground Level 23.0 above MSL Location at Top of Productive Interval Reference to Government Section Lines 195 FSL, 2,352 FEL, Sec 19, T12N, R6E, UM NAD 27 Coordinate System N 5,983,243 E 410,181 Measured Depth, Rig KB (MD) 18,600 Total Vertical Depth, Rig KB (TVD) 4,146 Total vertical Depth, Subsea (TVDSS) 4,076 Location at Bottom of Productive Interval Reference to Government Section Lines 4,783 FSL, 241 FEL, Sec 24, T12N, R5E, UM NAD 27 Coordinate System N 5,986,525 E 412,442 Measured Depth, Rig KB (MD) 23,946 Total Vertical Depth, Rig KB (TVD) 4,000 Total vertical Depth, Subsea (TVDSS) 3,930 (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 2: 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; A 21-day BOPE test schedule is planned per the waiver acceptance letter and conditional requirements outlined in Docket Number OTH-25-010 from the AOGCC to Oil Search Alaska for Nabors 272 operating at NDB (see attachment 12). Nabors 272 BOP Equipment: BOP Equipment NOV Shaffer Spherical annular BOP, 13-5/8 x 5000 psi NOV T3 6012 double gate, 13-5/8 x 5000 psi Mud cross, 13-5/8 x 5000 psi with 2 ea. 3-1/8" x 5000 psi side outlets Choke Line, 3-1/8 x 5000 psi with 3-1/8 manual and HCR valve Kill Line, 2-1/16 x 5000 psi with 3-1/8 manual and HCR valve NOV T3 6012 single gate, 13-5/8 x 5000 psi Choke Manifold 3-1/8 x 5000 psi working pressure with Axon Type S remote controlled chokes and NRG mud/gas separator BOP Closing Unit NOV SARA Koomey Control System, 316 gallon, 299 gallon reservoir. Twenty-Four 15 gallon bottles. Equipped with 1 electric and 3 air pumps with emergency power. Please refer to Attachment 3: BOPE Equipment for further details. 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; 12-1/4 Intermediate #1 Hole Pressure Data Maximum anticipated BHP 1,617 psi at TD in Seabee at 3,381 TVD (9.2ppg EMW in the Seabee formation to section TD) Maximum surface pressure 1,279 psi from TD in the Seabee (0.10 psi/ft gas gradient to surface, 3,381 TVD) Planned BOP test pressure Rams test to 5,000 psi / 250 psi (Initial) Rams test to 3,600 psi / 250 psi (Subsequent) Annular test to 3,000 psi / 250 psi (Test pressure driven by annular pressure during frac job) Integrity Test 12-1/4 hole FIT after drilling 20-50 of new hole to 14.0 ppg. (12.7 ppg LOT required for Kick Tolerance with 11.5ppg MW) 13-3/8 Casing Test 2,600 psi surface pressure (Test pressure driven by 50% of Casing Burst) 8-1/2 Intermediate #2 Hole Pressure Data Maximum anticipated BHP 1,859 psi in the Nanushuk 3 at 4,063 TVD (8.8ppg EMW Nanushuk 3 formation to section TD) Maximum surface pressure 1,453 psi from the Nanushuk 3 (0.10 psi/ft gas gradient to surface, 4,063 TVD) Planned BOP test pressure Rams test to 3,600 psi / 250 psi Annular test to 3,000 psi / 250 psi (Test pressure driven by annular pressure during frac job) Integrity Test 8-1/2 hole FIT after drilling 20-50 of new hole to 14.0 ppg. (11.4 ppg LOT required for Kick Tolerance with 10.5ppg MW) 9-5/8 Liner Test 4,000 psi surface pressure (MIT-IA after upper completion run, test pressure driven by annular pressure during frac job) 6-1/8 Production Hole Pressure Data Maximum anticipated BHP 1,873 psi in the Nanushuk 3.2 at 4,093 TVD (8.8ppg EMW top NT3.2 formation to heel target) Maximum surface pressure 1,464 psi from the NT3.2 (0.10 psi/ft gas gradient to surface, 4,093 TVD) Planned BOP test pressure Rams test to 3,600 psi / 250 psi Annular test to 3,000 psi / 250 psi (Test pressure driven by annular pressure during frac job) Integrity Test 6-1/8 hole FIT after drilling 20-50 of new hole to 14.0 ppg. (10.3ppg required for infinite kick tolerance with 9.8ppg MW) 7 Liner Test 4,000 psi surface pressure (MIT-IA after upper completion run, test pressure driven by annular pressure during frac job) (B) data on potential gas zones; and The Tuluvak formation is expected in this area and has a high potential for gas as based on offset Exploration and Appraisal well data. The Tuluvak is expected to be over-pressured at 10.2ppg pore pressure. The well plan is designed to safely manage pressures consistent with offset wells in the same manner that hydrocarbons are handled in the reservoir zone. BOPE will be installed before entering any hydrocarbon zones and appropriate mud weights will be utilized to provide sufficient overbalance. (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 4: Drilling Hazards 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 5: Leak Off 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 Liner / Tbg O.D.Wt/Ft Grade Conn Length Top MD Bottom MD / TVD 42 20x34 215# X-52 Welded 80 Surface 128 / 128 16 13-3/8 68# L-80 TXP BTC 3,065 Surface 3,065 / 2,386 12-1/4 9-5/8 47# L-80 HYD 563 9,085 2,915 12,000 / 3,381 Tie Back 9-5/8 47# L-80 HYD 563 2,915 Surface 2,915 / 2,340 8-1/2 x 9-7/87 26 L-80 HYD 563 6,240 11,850 18,090 / 4,063 6-1/8 4-1/2 12.6# P-110S HYD 563 6,006 17,940 23,946 / 4,000 Tubing 4-1/2 12.6# P-110S HYD 563 17,940 Surface 17,940 / 4,024 Please refer to Attachment 6: Cement Summary for further details. The Tuluvak is expected to be over-pressured at 10.2ppg 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); Nabors 272 Diverter Equipment: Hydril MSP annular BOP, 21 1/4 x 2000 psi, flanged Diverter Spool 21 1/4 x 2000 psi with 16-3/4 flanged sidearm connection. Interlocked knife/gate valves. 16 Diverter Line. Please refer to Attachment 3: BOPE Equipment for further details. A diverter variance is requested for NDB-022. Please refer to Section 15 for further details. 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 16 Surface Hole 12-1/4 Int #1 Hole 8-1/2 Int #2 Hole 6-1/8 Prod Hole Mud Type Spud Mud (WBM) MOBM MOBM MOBM Mud Properties: Mud Weight Funnel Vis PV YP API Fluid Loss HPHT Fluid Loss pH MBT 9.0 - 10 ppg 100 - 300 sec ALAP 30 - 80 < 10 ml/30min n/a 8.6-10.5 <35 11.0 - 12.0 ppg 50 - 80 sec ALAP 15 - 30 n/a < 5 ml/30min n/a n/a 9.5 - 12.0 ppg 50 - 80 sec ALAP 15 - 30 n/a < 5 ml/30min n/a n/a 7.5 - 10.0 ppg (>9.0ppg via MPD) 50 - 80 sec ALAP 10 - 20 n/a < 5 ml/30min n/a n/a A diagram of drilling fluid system on Nabors 272 is on file with AOGCC. A diverter variance is requested for NDB-022 Recommend granting requested diverter variance on the condition that the surface hole will not be drilled more than 250' TVD below the MCU marker. TS 11/3/25 (>9.0ppg via MPD 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 NDB-022 well 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 Oil Search Alaska is on file with the Commission. 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 NDB-022 is listed below. Please refer to Attachments 8-10 for a Well Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram. Proposed NDB-022 Drilling Program 1. Drill 20 conductor to ~128 MD/TVD. Cement to surface. Install Cellar and landing ring on conductor. 2. Move in / rig up Nabors 272. 3. Nipple up spacer spools over the 20 conductor. 4. Pick up 5-7/8 drill pipe, fill pits with spud mud and prepare for surface hole drilling. Make up 16 motor BHA with MWD and LWD tools. 5. Spud well and drill surface hole section to TD. Perform wiper trips as required. Circulate and condition hole to run casing. POOH and lay down BHA. 6. Run 13-3/8 68# surface casing as per casing tally and land on pre-installed landing ring. Circulate and condition mud prior to commencing cement job. 7. Cement 13-3/8 casing as per cement program. Verify cement returns to surface. 8. NU casing head and spacer spool. NU BOPE with Rotating Control Device (RCD). BOP configured from top to bottom: annular preventor, 4-1/2 x 7 VBR, blind/shear, mud cross, 9-5/8 Fixed Rams. Test rams to 5000 psi high (initial test only 3600 psi for subsequent tests) and annular to 3000 psi high as per AOGCC regulations. Provide AOGCC 48 hrs notice for witnessing BOP test. 9. Close blind shear rams and pressure test casing to 2600 psi for 30 min. 10. Make up 12-1/4 RSS BHA with MWD and LWD tools. RIH, clean out to top of float equipment and displace well to MOBM. 11. Drill out shoe track and 20 - 50 of new formation. Perform FIT / LOT. 12. Directionally drill 12-1/4 intermediate hole section #1 to TD. Circulate and condition hole to run liner. POOH. 13. RU and run 9-5/8 intermediate liner #1 as per casing tally then RIH on 5-7/8 DP / HWDP to TD. Circulate and condition mud prior to commencing cement job. 14. Set liner hanger and release running tool. Cement 9-5/8 liner with 1st stage cement job as per cement program. Monitor returns during displacement until plug bump. 15. Un-sting from liner hanger and POOH and LD liner running tools. 16. RIH with mechanical shifting tool and open 2 nd stage cement job tools. Pump secondary cement job, set liner top packer, and circulate cement to surface. POOH and lay down 5- 7/8 drillpipe and liner running tool. 17. Pressure test 13-3/8 casing and 9-5/8 liner to 2600 psi for 30 min. 18. Make up 8-1/2 RSS BHA with MWD and LWD tools. RIH on 5 drillpipe, clean out to top of float equipment and drill out the shoe track. 19. Drill out the 9-5/8 shoe and 20 - 50 of new formation. Perform FIT / LOT. 20. Install the MPD bearing assembly and adjust mud weight as required for ECD management with MPD. 21. Directionally drill 8-1/2 x 9-7/8 intermediate hole section #2 to TD utilizing MPD. 22. Circulate and condition hole to run liner. Displace weighted trip fluid as required and POOH. 23. Run cleanout/string mill assembly to dress the 9-5/8 CFLEX tool. 24. RU and run 7 intermediate liner #2 as per casing tally then RIH on 5 DP / HWDP to TD. Circulate and condition mud prior to commencing cement job. 25. Set liner hanger and release running tool. Cement 7 liner as per cement program. Monitor returns during displacement until plug bump. 26. Set liner top packer, un-sting from liner hanger, POOH and LD liner running tools. 27. RIH with polish mill assembly for cleanout of the 9-5/8 liner top PBR. Run 9-5/8 tieback string. Freeze protect the 13-3/8 x 9-5/8 annulus with diesel and land tieback. 28. Pressure test the 13-3/8 x 9-5/8 annulus to 2600 psi for 30 min. 29. Change upper BOP rams from 4-1/2 x 7 VBRs to 3-1/2 x 5-1/2 VBRs. Test rams to 3600 psi high and annular to 3000 psi high as per AOGCC regulations. Provide AOGCC 24hrs notice for witnessing BOP test. 30. Pressure test the 9-5/8 liner / tieback and 7 liner to 3500 psi for 30 min. 31. Make up 6-1/8 RSS BHA with MWD and LWD tools. RIH on tapered string with 4 x 5 drillpipe. 32. RIH to top of the float equipment logging 7 liner cement with Sonic LWD tool tripping in. 33. Displace well to MOBM at the required mud weight for MPD while drilling out the shoe track. 34. Circulate casing clean, install the MPD bearing assembly and test MPD surface equipment as required. 35. Drill 20 - 50 of new formation. Perform FIT / LOT. 36. Directionally drill 6-1/8 production hole section to TD using MPD. 37. Circulate and condition hole to run liner. Displace weighted trip fluid as required and POOH. 38. RU and run 4-1/2 production liner as per tally then RIH on tapered 4 x 5 DP to TD. 39. Drop 1.125 ball and circulate to close WIV. Close WIV collar and set liner hanger/top packer. 40. Pressure test the 9-5/8 x 7 x 4-1/2 IA to liner top packer to 3,500 psi for 10 min. Release the running tool. 41. Circulate 9.2ppg viscosified brine with Lube 776 and SafeLube at 10 bpm. 42. POOH and LD liner running tool. 43. RU and run 4-1/2 upper completion and downhole jewelry with TEC wire. Space out seals. 44. Circulate 9.2ppg NaCl Brine with corrosion inhibitor and biocide. Land tubing hanger. 45. Pressure test tubing to 3,500 psi for 30 mins. Pressure up on the annulus to 4,000 psi for 30 mins. Bleed pressure on tubing and shear upper gas lift valve. 46. Reverse circulate freeze protect and U-Tube. 47. Install TWC, pressure test to 2,500 psi for 10 mins. ND BOPE, NU frac tree. 48. Secure well and prepare for rig move. 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. The Oil Search Alaska NGI (Nanushuk Grind & Inject) facility is now operational, and cuttings will be hauled via truck as generated, processed at NGI, and disposed of into the DW-02 Class 1 disposal well. The NGI facility is located on NDB. In the event that NGI is not operational, water-based and oil-based drilling muds and cuttings will typically be hauled directly offsite via truck as it is generated. Contractual arrangements have been made with other operators on the North Slope to utilize their waste injection/disposal facilities (Class 1 and Class 2) at Prudhoe Bay, Kuparuk and Milne Point. If waste cannot be hauled directly offsite, it may be stored temporarily in drilling waste cuttings bins or a bermed cuttings storage cell in accordance with a drilling waste temporary storage plan approved by Alaska Department of Conservation (ADEC) Solid Waste Program until it can be transported for proper disposal. There is no intention to request authorization under 20 AAC 25.080 for any annular disposal operation in the well. 15. Proposed Variance Requests 20 AAC 25.035. Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements. (h)(2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter is not necessary A diverter variance is requested for the NDB-022 surface hole section. Oil Search Alaska, LLC (OSA) has conducted internal risk assessments and determined that the risk of needing to use a diverter is negligible and operationally could pose an increase in HSE risks. NDB-022 surface hole is surrounded by more than 21 other existing surface holes at the NDB pad location. Additionally, there are 3 previously drilled wells (NDBi-016, NDB-024, and NDB-027) within 600 of the proposed NDB-022 surface hole TD location (see attachment 11). More than 36 wells have been drilled in the NDB pad and Pikka area over the last 54 years with no signs or indications of shallow free gas above the Tuluvak. There are 16 Exploration and Appraisal wells and more than 21 NDB Pad wells totaling more than 70,000 of drilled interval. In addition, OSA has acquired eight openhole logs across the surface hole intervals in the area consisting of four E-line Density Neutron logs and four LWD Sonic logs. All logs definitively show no free gas accumulations. During this time period, there have been zero well control events above the Tuluvak. OSA has built highly detailed geological models which predict the Top of the Tuluvak with very high accuracy. There is very low structural uncertainty and a high confidence marker with the MCU given the number of wells already drilled in the area. The area around NDB is covered by 3D seismic data that was acquired in 2010 and reprocessed in 2023. The data is of adequate quality without gaps and obvious noise trains or shallow velocity anomalies. The smallest detectable and mapped faults in the surrounding area is estimated to be 20-30. There are no observed faults in the vicinity of this hole section for the NDB-022 well. NDB-022 surface casing will target a maximum setting depth of 250 TVD below the MCU marker to maintain a 100 TVD standoff from the gas-bearing Tuluvak sand formation. OSA will implement drilling practices to effectively manage any hydrates encountered while drilling surface hole as follows: (1) Mitigate breakout potential: keep mud temperature cool, no extended circulation at any point in the well, optimized drilling and tripping strategies, utilization of GWD to minimize stationary time. (2) Identify hydrates (i.e. bubbles in the flow both with no signs of pit gain or flow from the well). (3) Handle hydrates at surface (i.e. utilization of degasser and isolation of gas-cut mud in the pits). (4) Drilling practices (i.e. controlling pump rates and maximizing ROP to get through a hydrate zone). Nabors Rig 272's current elevated diverter rig-up introduces health, safety, and environmental (HSE) risks due to the complexities of installation at height. With the ongoing facility commissioning at NDB pad, the diverter line will need to be moved to ground level in the near future to be routed beneath the flowlines and pipe racks, passing through support pilings. This change will increase operational challenges and HSE risks, as the 75-foot diverter line will require multiple bends to navigate around existing equipment and infrastructure. With the multiple well penetrations at the NDB Pad and Pikka area, no free gas above the Tuluvak, the strong geologic understanding, and low structural uncertainty, combined with the increased HSE risks and challenges of running a diverter line, it is requested that a diverter variance for NDB-022 be granted. 20 AAC 25.035. Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements. (e)(10)(A) when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance A 21-day BOPE test schedule is planned as per the waiver acceptance letter and conditional requirements outlined in Docket Number OTH-25-010 from the AOGCC to Oil Search Alaska for Nabors 272 operating at NDB (see attachment 12). 20 AAC 25.030. Casing and cementing (d)(5) intermediate and production casing must be cemented with sufficient cement to fill the annular space from the casing shoe to a minimum of 500 feet measured depth or 250 feet true vertical depth, whichever is greater, above all significant hydrocarbon zones and abnormally geo- pressured strata or, if zonal coverage is not required under (a) of this section, from the casing shoe to a minimum of 500 feet measured depth or 250 feet true vertical depth, whichever is greater, above the casing shoe A variance is requested to the above regulation 20 AAC 25.030 (d)(5) for the following: 1. 9-5/8 Primary Cement Job: The primary cement job will target a top of cement 1000 feet MD (~100 feet TVD at ~84° inclination) above the 9-5/8 shoe. Due to ERD nature of this section, additional TVD height of the cement top will significantly increase cement volumes and the subsequent risk of losses due to ECDs exceeding the formation fracture gradient. Note, with this well design the 9-5/8 is considered as an intermediate drilling liner and the shoe is not designed to isolate any significant hydrocarbon zones or abnormally geo-pressured strata. Isolation over the top of the Nanushuk formation will be provided by cement integrity at the subsequent 7 liner shoe. 2. 9-5/8 Secondary Cement Job: To not place cement across the entire annular space from the 9-5/8 shoe to above shallowest significant hydrocarbon zone. A two-stage cement job will be performed to isolate the shoe in the Seabee, and the second stage cement job will isolate the significant hydrocarbon zone in the Tuluvak formation. Due to the ERD nature and high angle of the Pikka NDB development wells, a single stage cement job on the 9-5/8 intermediate liner is not achievable without exceeding the fracture gradient and compromising cement placement and zonal isolation. The two-stage cement job will achieve all casing and cementing objectives outlined in AOGCC regulation 20 AAC 25.030.(a), stating that a well casing and cementing program must be designed to: 1) provide suitable and safe operating conditions for the total measured depth proposed; 2) confine fluids to the wellbore; 3) prevent migration of fluids from one stratum to another; 4) ensure control of well pressures encountered; 5) protect against thaw subsidence and freezeback effects within permafrost; 6) prevent contamination of freshwater; 7) protect significant hydrocarbon zones; and 8) provide well control until the next casing is set, considering all factors relevant to well control including formation fracture gradients, formation pressures, casing setting depths, and proposed total depth. The formation interval between the top of stage one and the bottom of stage two includes the Seabee and lower Tuluvak formation. These formations are interbedded silts and shales with very low permeability and contain no significant hydrocarbons. Based on offset well logs, cuttings, mudlogging analysis, and the latest petrophysical interpretation, the base of the significant hydrocarbon zone in the Tuluvak formation is contained only within the upper portion of TS 880 clinoform of the Upper Tuluvak in the NDB area. Within the TS 880 clinoform, the base of significant hydrocarbon is at or above 2,640 TVD. The Tuluvak formation below 2,640 TVD is not a significant hydrocarbon zone. A stage collar placement is proposed 50 MD below the TS 790 formation marker (Upper Tuluvak). This stage collar depth will isolate any potential gas based on offset well data. The TS 875 and TS 870 clinoform is between the TS 880 clinoform and TS 790 top. The TS 875 and TS 870 clinoforms are shale dominated, very low net to gross, has no vertical permeability, and represents a seal to the hydrocarbon bearing TS 880. Moving the cementing stage tool to be placed at 50 MD below the TS 790 formation marker allows placement of higher quality cement that provides better isolation across the significant hydrocarbon zone in the Tuluvak. Attempting to place cement across the entire Tuluvak will add risk to the primary objective of cement isolation across the significant hydrocarbon zone which is only located in the upper portion of the Tuluvak (TS 880). The increased risk is due to: a) Cementing the entire Tuluvak would require large cement jobs that jeopardize cement isolation across the upper Tuluvak. b) Large cement jobs likely require the use of lighter weight cement across the significant hydrocarbon zone. 3. 7 Liner Cement Job: The 7 liner cement job will target a top of cement 200 feet TVD above the top of the Nanushuk formation. Due to ERD nature of this section (inclination 70-84°), additional TVD height of the cement top will significantly increase cement volumes and the subsequent risk of losses due to ECDs exceeding the formation fracture gradient. Additionally, the 200 feet TVD above the top of the Nanushuk is targeted to: a) Provide additional cement coverage above the topmost hydrocarbon zone in the NT8. The planned TOC is ~253 feet TVD (~2389 feet MD) above the top of the NT8. Logs within the Pikka NDB project area have consistently shown that there are no significant hydrocarbon zones between the top NT8 and the top Nanushuk formation. b) Allow the use of a single heavier tail slurry to provide the improved cement integrity and isolation across the top of the Nanushuk. Note, improved cement bond log quality has generally been observed with heavier weight tail slurries. c) Minimize the operational risk of cement returns up into the 9-5/8 shoe and above the top of the 7 liner hanger. Additional cement volume / excess may be pumped to help ensure the targeted top of cement is achieved based on detailed cement modelling or operational conditions (i.e. lost circulation, low fracture gradient or excessive washout) observed prior to execution of the cement job. Recommend approving variance for two stage cement job. TS 11/3/24 20 AAC 25.033. Primary well control for drilling: drilling fluid program and drilling fluid system. (b)(1)(A) A drilling fluid of sufficient density to overbalance the pressure of uncased formations penetrated A variance is requested to the above regulation 20 AAC 25.033 (b)(1)(A) for drilling fluid density in the production hole only. Due to the ERD nature of these wells, staying under the ECD limit of 13.5ppg has become extremely difficult to manage. Exceeding the 13.5ppg ECD limit greatly increases the risk of lost circulation and further increases the risk of unsuccessful well execution. A ~7.5-8.0ppg mud weight will be used with Managed Pressure Drilling (MPD). MPD will be utilized to drill the production hole while being statically and dynamically overbalanced to the Nanushuk formation by holding back pressure on connections and while drilling (if needed). A 9.5-10.0ppg fluid will be circulated in the hole prior to tripping. Two independent barriers will be maintained throughout the operations: 6-1/8 Drilling: (1) RCD and MPD choke (2) BOP stack 6-1/8 Tripping and 4-1/2 Liner Run: (1) 9.5-10.0ppg mud (2) BOP stack The Pikka development at NDB pad has well established pore pressures with active monitoring via downhole pressure gauges. The target interval is an oil reservoir with limited formation permeability. The MPD choke will be set up to automatically trap pressure on connections, or anytime the mud pump is stopped. The choke pressure will be set to maintain a constant bottom hole pressure. The MPD chokes will prevent a sudden drop in surface pressure if the pumps are stopped suddenly. MPD equipment has been installed and in use on the rig since October 2024. The rig crews are familiar with the equipment and communication between the rig crew and MPD technicians have been excellent. There is an additional driller responsibility to notify the MPD technician of a change in pump rate, however, this is a courtesy notification as the MPD system will automatically trap pressure when the pump is shut down. The MPD provider (Beyond Energy Services) has extensive experience utilizing the MPD system to drill dynamically overbalanced. Beyond has established procedures and contingency plans in place fit for purpose for the Nabors 272 rig to ensure that sufficient surface pressure is kept on the well to maintain overbalanced to the Nanushuk formation. All influxes to be circulated out per conventional well kill protocols. Rig crew to monitor flow and pit levels per standard operations. Rig crew to shut in per standard operations (no change to standing orders). Influx will be managed conventionally with closed BOP and slow pump rate. Attachments Attachment 1: Location Map Attachment 2: Directional Plan SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 47.0 0.00 0.00 47.0 0.0 0.0 0.00 0.00 0.0 2 347.0 0.00 0.00 347.0 0.0 0.0 0.00 0.00 0.0 3 587.0 6.00 345.00 586.6 12.1 -3.2 2.50 345.00 11.8 4 1000.1 18.00 329.42 990.0 88.2 -41.5 2.98 -22.89 96.1 5 1160.1 18.00 329.42 1142.2 130.8 -66.6 0.00 0.00 145.4 6 2934.1 72.42 323.27 2346.0 1120.3 -765.3 3.07 -7.20 1356.7 7 3134.1 72.42 323.27 2406.4 1273.1 -879.3 0.00 0.00 1547.3 8 3518.1 83.94 323.23 2484.9 1573.8 -1103.8 3.00 -0.18 1922.3 9 17671.8 83.94 323.23 3979.5 12848.7 -9528.2 0.00 0.00 15989.8 10 18073.1 73.50 329.36 4058.0 13175.3 -9746.5 3.00 150.62 16382.5 11 18174.1 73.50 329.36 4086.7 13258.6 -9795.8 0.00 0.0016479.1 12 18599.9 90.53 329.35 4145.6 13620.1 -10010.0 4.00 -0.0416898.1 NDB-022 Heel Rev 1.0 13 22952.7 90.53 329.35 4105.0 17364.5 -12228.9 0.00 0.00 21238.3 NDB-022 Fault Target Rev 0.0 14 23019.6 92.54 329.28 4103.2 17422.1 -12263.1 3.00 -1.85 21305.1 15 23246.6 92.54 329.28 4093.1 17617.0 -12378.9 0.00 0.00 21531.2 NDB-022 Fault Block-1 Rev 1.0 16 23278.7 93.49 329.47 4091.4 17644.6 -12395.2 3.00 11.21 21563.2 17 23497.5 93.49 329.47 4078.1 17832.7 -12506.1 0.00 0.00 21780.9 NDB-022 Fault Block-2 Rev 1.0 18 23946.2 106.61 329.44 4000.0 18212.4 -12730.2 2.92 -0.12 22220.5 NDB-022 Toe Rev 2.0 47 500 500 1000 1000 1500 1500 2000 2000 2500 2500 3000 3000 5000 5000 6000 6000 7000 7000 8000 8000 9000 9000 10000 10000 12000 12000 14000 14000 16000 16000 18000 18000 20000 20000 25000 Plan NDB-022 Rev F.1 Plan Summary 0 3 0 3500 7000 10500 14000 17500 21000 24500 Measured Depth 20" Conductor Driven 9-5/8" Intermediate Liner 7" Intermediate Liner 4-1/2" x 6-1/8" 45 45 90 90 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [90 usft/in] 475176101126151176201226251276301326351376401426451476501525550575600624649673697721746770794818842866890914938961985NDBi-018 7075100125150175200225250275300325350375400425450475499524548572596620644667690713 736 758 Plan: NDBi-019 Rev A.0 70751001251501752002252502753003253503754004254504755005255505756006256506756997247497747998248498748989239489739981023104810731098112311481173119812231248127312981323134813731398142414491474150015251551157616021627165316781704Plan: NDBi-020 Rev A.0 475075100125150175200225250275300325350375400425450475499524548572596620644667691714 737 759 782 804Plan:NDB-021 Rev A.0 475075100125150175200225250275300325350375400425450475500525549574599624648673697722746770794818842866889913936959982NDB-023 Slot Saver 475075100125150175200225250275300325350376401426451476501526551576601626652677702728753778804829855880906931957982100810331057108211071132115711821208123412591285131113371363138914151441146714931519NDB-024 475075100125150175200225250275300325350376401426451476501526551576601626652677702728753778804829855880906931957982100810331057108211071132115711821208123412591285131113371363138914151441146714931519NDB-024PB1 475075100125150175200225250275300325350375400425450475500524549573598622646670694718741 NDB-025 475075100125150175200225250275300325350375400425450475500525550575600626651677702728753779804830855880906 9319579821008 1033105810831108113311571183Plan: NDBi-026 Rev A.0 475075100125150175200225250275300325350375400425450NDB-027475075100125150175200225250275300325350375400425450NDB-027 MWD475075100125150175200225250275300325350375400425450NDB-027 PB1 0 2500 0 3000 6000 9000 12000 15000 18000 21000 Vertical Section at 325.05° 20" Conductor Driven 13-3/8" Surface Casing 9-5/8" Intermediate Liner 7" Intermediate Liner 4-1/2" x 6-1/8" 0 30 60 0 275 550 825 1100 1375 1650 1925 Measured Depth Equivalent Magnetic Distance DDI 7.423 SURVEY PROGRAM Date: 2021-02-16T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 47.0 1000.0 Plan NDB-022 Rev F.1 (NDB-022)SDI_KPR_gyroMWD+SAG 1000.0 3065.0 Plan NDB-022 Rev F.1 (NDB-022)3_MWD+IFR2+MS+Sag 3065.0 12000.0 Plan NDB-022 Rev F.1 (NDB-022)3_MWD+IFR2+MS+Sag 12000.0 18073.0 Plan NDB-022 Rev F.1 (NDB-022)3_MWD+IFR2+MS+Sag 18073.0 23946.2 Plan NDB-022 Rev F.1 (NDB-022)3_MWD+IFR2+MS+Sag Surface Location North / 5972550.74 East / 1562340.66 Elevation / 23.0 CASING DETAILS TVD MD Name 128.0 128.0 20" Conductor Driven 2385.5 3065.013-3/8" Surface Casing 3380.6 12000.09-5/8" Intermediate Liner 4062.8 18090.0 7" Intermediate Liner 4000.0 23946.2 4-1/2" x 6-1/8" Mag Model & Date: BGGM2025 01-Jan-26 Magnetic North is 13.41° East of True North (Magnetic Declin Mag Dip & Field Strength: 80.51°57092.1382748 FORMATION TOP DETAILS TVDPath Formation 1048.0Upper Schrader Bluff 1140.0Base Ice Bearing Permafrost 1394.0Base Permafrost Transition 1744.0Middle Schrader Bluff 2135.8 MCU 2432.5Tuluvak Shale 2498.4Tuluvak Sand 2796.5 TS_790 3158.7 Seabee 3769.9 Nanushuk 3823.0 NT8 MFS 3860.0 NT7 MFS 3909.0 NT6 MFS 3935.0 NT5 MFS 3975.0 NT4 MFS 4016.8NT3 MFS Toe up 4043.1 NT3 MFS 4057.3NT3.2 Top Reservoir Up 4093.1NT3.2 Top Reservoir 4105.0NDB-022_Fault By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by BHI DE Accepted by BHI PSD Approved by Santos DE DF @ 70.0usft Standard Planning Report - Geographic 15 October, 2025 Plan: Plan NDB-022 Rev F.1 Santos NAD27 Conversion Pikka NDB B-22 NDB-022 Santos Ltd Planning Report - Geographic Well B-22Local Co-ordinate Reference:Database:EDM DF @ 70.0usftTVD Reference:Santos NAD27 ConversionCompany: DF @ 70.0usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-22Well: NDB-022Wellbore: Plan NDB-022 Rev F.1Design: Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Pikka, North Slope Alaska, United States Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: From: Site Latitude: Longitude: Position Uncertainty: Northing: Easting: NDB Map Slot Radius:0.9 usft usft usft " 5,972,909.31 423,383.61 36 70° 20' 10.134 N 150° 37' 17.794 W Well Well Position Longitude: Latitude: Easting: Northing: +E/-W +N/-S Position Uncertainty Ground Level: B-22 Wellhead Elevation:0.5 0.0 0.0 5,972,803.03 422,308.31 70° 20' 8.980 N 150° 37' 49.167 W 23.0 usft usft usft usft usft usft usft °-0.59Grid Convergence: Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) NDB-022 Model NameMagnetics BGGM2025 1/01/2026 13.41 80.51 57,092.13848152 Phase:Version: Audit Notes: Design Plan NDB-022 Rev F.1 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:47.0 325.050.00.047.0 Plan Survey Tool Program RemarksTool NameSurvey (Wellbore) Date 15/10/2025 Depth To (usft) Depth From (usft) SDI_KPR_gyroMWD+SAG SDI Keeper gyroMWD + SA Plan NDB-022 Rev F.1 (NDB-022147.0 1,000.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan NDB-022 Rev F.1 (NDB-02221,000.0 3,065.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan NDB-022 Rev F.1 (NDB-02233,065.0 12,000.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan NDB-022 Rev F.1 (NDB-022412,000.0 18,073.0 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-s Plan NDB-022 Rev F.1 (NDB-022518,073.0 23,945.9 15/10/2025 10:50:14 COMPASS 5000.17 Build Page 2 Santos Ltd Planning Report - Geographic Well B-22Local Co-ordinate Reference:Database:EDM DF @ 70.0usftTVD Reference:Santos NAD27 ConversionCompany: DF @ 70.0usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-22Well: NDB-022Wellbore: Plan NDB-022 Rev F.1Design: Inclination (°) Azimuth (°) +E/-W (usft) TFO (°) +N/-S (usft) Measured Depth (usft) Vertical Depth (usft) Dogleg Rate (°/100usft) Build Rate (°/100usft) Turn Rate (°/100usft) Plan Sections Target 0.000.000.000.000.00.047.00.000.0047.0 0.000.000.000.000.00.0347.00.000.00347.0 345.000.002.502.50-3.212.1586.6345.006.00587.0 -22.89-3.772.902.98-41.588.2990.0329.4218.001,000.1 0.000.000.000.00-66.6130.81,142.2329.4218.001,160.1 -7.20-0.353.073.07-765.31,120.32,346.0323.2772.422,934.1 0.000.000.000.00-879.31,273.12,406.4323.2772.423,134.1 -0.17-0.013.003.00-1,103.81,573.82,484.9323.2483.943,518.1 0.000.000.000.00-9,527.512,848.83,979.5323.2483.9417,671.5 150.631.53-2.603.00-9,745.813,175.34,058.0329.3673.5018,072.7 0.000.000.000.00-9,795.113,258.64,086.7329.3673.5018,173.7 -0.040.000.004.00-10,009.313,620.14,145.6329.3590.5318,599.6 NDB-022 Heel Rev 84.910.000.000.00-12,228.017,364.84,105.0329.3690.5322,952.3 NDB-022 Fault Targ -2.02-0.113.003.00-12,262.117,422.34,103.2329.2992.5423,019.2 0.000.000.000.00-12,377.917,617.34,093.1329.2992.5423,246.2 NDB-022 Fault Bloc 11.250.592.943.00-12,394.317,644.94,091.4329.4893.4923,278.4 0.000.000.000.00-12,505.117,833.04,078.1329.4893.4923,497.1 NDB-022 Fault Bloc -0.12-0.012.922.92-12,729.218,212.74,000.0329.45106.6123,945.9 NDB-022 Toe Rev 2 15/10/2025 10:50:14 COMPASS 5000.17 Build Page 3 Santos Ltd Planning Report - Geographic Well B-22Local Co-ordinate Reference:Database:EDM DF @ 70.0usftTVD Reference:Santos NAD27 ConversionCompany: DF @ 70.0usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-22Well: NDB-022Wellbore: Plan NDB-022 Rev F.1Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 47.0 0.00 47.0 0.0 0.00.00 422,308.315,972,803.03 70° 20' 8.980 N 150° 37' 49.167 W 100.0 0.00 100.0 0.0 0.00.00 422,308.315,972,803.03 70° 20' 8.980 N 150° 37' 49.167 W 128.0 0.00 128.0 0.0 0.00.00 422,308.315,972,803.03 70° 20' 8.980 N 150° 37' 49.167 W 20" Conductor Driven 200.0 0.00 200.0 0.0 0.00.00 422,308.315,972,803.03 70° 20' 8.980 N 150° 37' 49.167 W 300.0 0.00 300.0 0.0 0.00.00 422,308.315,972,803.03 70° 20' 8.980 N 150° 37' 49.167 W 347.0 0.00 347.0 0.0 0.00.00 422,308.315,972,803.03 70° 20' 8.980 N 150° 37' 49.167 W 400.0 1.33 400.0 0.6 -0.2345.00 422,308.165,972,803.63 70° 20' 8.986 N 150° 37' 49.172 W 500.0 3.83 499.9 4.9 -1.3345.00 422,307.045,972,807.98 70° 20' 9.028 N 150° 37' 49.206 W 587.0 6.00 586.6 12.1 -3.2345.00 422,305.195,972,815.19 70° 20' 9.099 N 150° 37' 49.262 W 600.0 6.36 599.5 13.5 -3.6343.64 422,304.825,972,816.54 70° 20' 9.112 N 150° 37' 49.273 W 700.0 9.20 698.6 26.1 -8.3336.78 422,300.245,972,829.25 70° 20' 9.237 N 150° 37' 49.411 W 800.0 12.11 796.8 42.8 -16.2333.16 422,292.535,972,846.04 70° 20' 9.401 N 150° 37' 49.641 W 900.0 15.04 894.0 63.5 -27.3330.93 422,281.705,972,866.85 70° 20' 9.605 N 150° 37' 49.963 W 1,000.0 18.00 989.9 88.2 -41.4329.42 422,267.795,972,891.65 70° 20' 9.847 N 150° 37' 50.377 W 1,000.1 18.00 990.0 88.2 -41.5329.42 422,267.775,972,891.68 70° 20' 9.848 N 150° 37' 50.378 W 1,061.1 18.00 1,048.0 104.5 -51.0329.42 422,258.355,972,908.00 70° 20' 10.007 N 150° 37' 50.658 W Upper Schrader Bluff 1,100.0 18.00 1,085.0 114.8 -57.2329.42 422,252.355,972,918.41 70° 20' 10.109 N 150° 37' 50.836 W 1,157.8 18.00 1,140.0 130.2 -66.3329.42 422,243.415,972,933.89 70° 20' 10.260 N 150° 37' 51.102 W Base Ice Bearing Permafrost 1,160.1 18.00 1,142.2 130.8 -66.6329.42 422,243.065,972,934.50 70° 20' 10.266 N 150° 37' 51.112 W 1,200.0 19.22 1,180.0 141.7 -73.1328.95 422,236.665,972,945.49 70° 20' 10.374 N 150° 37' 51.303 W 1,300.0 22.27 1,273.5 171.9 -91.7328.00 422,218.445,972,975.86 70° 20' 10.671 N 150° 37' 51.844 W 1,400.0 25.33 1,364.9 206.0 -113.3327.26 422,197.185,973,010.15 70° 20' 11.006 N 150° 37' 52.475 W 1,432.3 26.32 1,394.0 217.8 -120.9327.06 422,189.685,973,022.04 70° 20' 11.122 N 150° 37' 52.698 W Base Permafrost Transition 1,500.0 28.40 1,454.1 243.9 -137.9326.68 422,172.945,973,048.28 70° 20' 11.378 N 150° 37' 53.195 W 1,600.0 31.46 1,540.8 285.4 -165.5326.20 422,145.785,973,090.12 70° 20' 11.787 N 150° 37' 54.001 W 1,700.0 34.53 1,624.7 330.5 -196.0325.80 422,115.805,973,135.56 70° 20' 12.231 N 150° 37' 54.890 W 1,800.0 37.60 1,705.5 379.1 -229.2325.45 422,083.075,973,184.48 70° 20' 12.709 N 150° 37' 55.861 W 1,849.0 39.10 1,744.0 404.2 -246.5325.30 422,066.045,973,209.69 70° 20' 12.955 N 150° 37' 56.366 W Middle Schrader Bluff 1,900.0 40.66 1,783.1 431.0 -265.1325.15 422,047.695,973,236.72 70° 20' 13.219 N 150° 37' 56.910 W 2,000.0 43.73 1,857.1 486.0 -303.6324.89 422,009.765,973,292.14 70° 20' 13.760 N 150° 37' 58.035 W 2,100.0 46.80 1,927.5 544.0 -344.6324.65 421,969.395,973,350.57 70° 20' 14.330 N 150° 37' 59.232 W 2,200.0 49.87 1,994.0 604.9 -387.9324.44 421,926.695,973,411.86 70° 20' 14.929 N 150° 38' 0.497 W 2,300.0 52.94 2,056.3 668.4 -433.5324.24 421,881.805,973,475.82 70° 20' 15.553 N 150° 38' 1.828 W 2,400.0 56.01 2,114.4 734.4 -481.2324.06 421,834.835,973,542.27 70° 20' 16.202 N 150° 38' 3.220 W 2,438.9 57.21 2,135.8 760.6 -500.2324.00 421,816.045,973,568.73 70° 20' 16.460 N 150° 38' 3.777 W MCU 2,500.0 59.09 2,168.1 802.6 -530.8323.90 421,785.925,973,611.01 70° 20' 16.873 N 150° 38' 4.669 W 2,600.0 62.16 2,217.1 872.9 -582.2323.74 421,735.225,973,681.86 70° 20' 17.565 N 150° 38' 6.172 W 2,700.0 65.23 2,261.4 945.1 -635.3323.59 421,682.875,973,754.61 70° 20' 18.275 N 150° 38' 7.723 W 2,800.0 68.30 2,300.9 1,019.0 -690.0323.45 421,629.025,973,829.04 70° 20' 19.001 N 150° 38' 9.319 W 2,900.0 71.37 2,335.4 1,094.3 -745.9323.31 421,573.825,973,904.94 70° 20' 19.742 N 150° 38' 10.954 W 2,934.1 72.42 2,346.0 1,120.3 -765.3323.27 421,554.715,973,931.13 70° 20' 19.998 N 150° 38' 11.521 W 3,000.0 72.42 2,365.9 1,170.7 -802.9323.27 421,517.675,973,981.85 70° 20' 20.493 N 150° 38' 12.618 W 3,065.0 72.42 2,385.5 1,220.3 -839.9323.27 421,481.145,974,031.89 70° 20' 20.981 N 150° 38' 13.700 W 13-3/8" Surface Casing 3,100.0 72.42 2,396.1 1,247.1 -859.9323.27 421,461.465,974,058.83 70° 20' 21.244 N 150° 38' 14.283 W 3,134.1 72.42 2,406.4 1,273.1 -879.3323.27 421,442.295,974,085.10 70° 20' 21.501 N 150° 38' 14.852 W 3,200.0 74.40 2,425.2 1,323.7 -917.1323.26 421,405.055,974,136.08 70° 20' 21.998 N 150° 38' 15.955 W 3,228.1 75.24 2,432.5 1,345.5 -933.3323.26 421,389.055,974,157.99 70° 20' 22.212 N 150° 38' 16.429 W Tuluvak Shale 3,300.0 77.40 2,449.5 1,401.5 -975.1323.25 421,347.865,974,214.38 70° 20' 22.762 N 150° 38' 17.649 W 3,400.0 80.40 2,468.8 1,480.1 -1,033.8323.25 421,289.985,974,293.60 70° 20' 23.536 N 150° 38' 19.364 W 3,500.0 83.40 2,482.9 1,559.4 -1,093.1323.24 421,231.575,974,373.51 70° 20' 24.315 N 150° 38' 21.095 W 3,518.1 83.94 2,484.9 1,573.8 -1,103.8323.24 421,220.985,974,387.99 70° 20' 24.457 N 150° 38' 21.409 W 15/10/2025 10:50:14 COMPASS 5000.17 Build Page 4 Santos Ltd Planning Report - Geographic Well B-22Local Co-ordinate Reference:Database:EDM DF @ 70.0usftTVD Reference:Santos NAD27 ConversionCompany: DF @ 70.0usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-22Well: NDB-022Wellbore: Plan NDB-022 Rev F.1Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 3,600.0 83.94 2,493.5 1,639.0 -1,152.6323.24 421,172.895,974,453.77 70° 20' 25.099 N 150° 38' 22.834 W 3,645.9 83.94 2,498.4 1,675.6 -1,179.9323.24 421,145.935,974,490.64 70° 20' 25.459 N 150° 38' 23.633 W Tuluvak Sand 3,700.0 83.94 2,504.1 1,718.7 -1,212.1323.24 421,114.215,974,534.03 70° 20' 25.882 N 150° 38' 24.573 W 3,800.0 83.94 2,514.7 1,798.4 -1,271.6323.24 421,055.525,974,614.30 70° 20' 26.666 N 150° 38' 26.312 W 3,900.0 83.94 2,525.2 1,878.0 -1,331.1323.24 420,996.845,974,694.57 70° 20' 27.449 N 150° 38' 28.051 W 4,000.0 83.94 2,535.8 1,957.7 -1,390.6323.24 420,938.165,974,774.84 70° 20' 28.232 N 150° 38' 29.790 W 4,100.0 83.94 2,546.3 2,037.3 -1,450.2323.24 420,879.475,974,855.11 70° 20' 29.016 N 150° 38' 31.529 W 4,200.0 83.94 2,556.9 2,117.0 -1,509.7323.24 420,820.795,974,935.37 70° 20' 29.799 N 150° 38' 33.268 W 4,300.0 83.94 2,567.5 2,196.7 -1,569.2323.24 420,762.115,975,015.64 70° 20' 30.582 N 150° 38' 35.007 W 4,400.0 83.94 2,578.0 2,276.3 -1,628.7323.24 420,703.425,975,095.91 70° 20' 31.366 N 150° 38' 36.746 W 4,500.0 83.94 2,588.6 2,356.0 -1,688.2323.24 420,644.745,975,176.18 70° 20' 32.149 N 150° 38' 38.485 W 4,600.0 83.94 2,599.1 2,435.7 -1,747.7323.24 420,586.065,975,256.44 70° 20' 32.932 N 150° 38' 40.224 W 4,700.0 83.94 2,609.7 2,515.3 -1,807.3323.24 420,527.375,975,336.71 70° 20' 33.716 N 150° 38' 41.964 W 4,800.0 83.94 2,620.3 2,595.0 -1,866.8323.24 420,468.695,975,416.98 70° 20' 34.499 N 150° 38' 43.703 W 4,900.0 83.94 2,630.8 2,674.7 -1,926.3323.24 420,410.015,975,497.25 70° 20' 35.282 N 150° 38' 45.442 W 5,000.0 83.94 2,641.4 2,754.3 -1,985.8323.24 420,351.325,975,577.51 70° 20' 36.066 N 150° 38' 47.182 W 5,100.0 83.94 2,651.9 2,834.0 -2,045.3323.24 420,292.645,975,657.78 70° 20' 36.849 N 150° 38' 48.921 W 5,200.0 83.94 2,662.5 2,913.6 -2,104.8323.24 420,233.965,975,738.05 70° 20' 37.632 N 150° 38' 50.661 W 5,300.0 83.94 2,673.1 2,993.3 -2,164.4323.24 420,175.275,975,818.32 70° 20' 38.416 N 150° 38' 52.400 W 5,400.0 83.94 2,683.6 3,073.0 -2,223.9323.24 420,116.595,975,898.59 70° 20' 39.199 N 150° 38' 54.140 W 5,500.0 83.94 2,694.2 3,152.6 -2,283.4323.24 420,057.915,975,978.85 70° 20' 39.982 N 150° 38' 55.879 W 5,600.0 83.94 2,704.7 3,232.3 -2,342.9323.24 419,999.225,976,059.12 70° 20' 40.766 N 150° 38' 57.619 W 5,700.0 83.94 2,715.3 3,312.0 -2,402.4323.24 419,940.545,976,139.39 70° 20' 41.549 N 150° 38' 59.358 W 5,800.0 83.94 2,725.9 3,391.6 -2,461.9323.24 419,881.865,976,219.66 70° 20' 42.332 N 150° 39' 1.098 W 5,900.0 83.94 2,736.4 3,471.3 -2,521.5323.24 419,823.175,976,299.92 70° 20' 43.115 N 150° 39' 2.838 W 6,000.0 83.94 2,747.0 3,550.9 -2,581.0323.24 419,764.495,976,380.19 70° 20' 43.899 N 150° 39' 4.578 W 6,100.0 83.94 2,757.5 3,630.6 -2,640.5323.24 419,705.815,976,460.46 70° 20' 44.682 N 150° 39' 6.317 W 6,200.0 83.94 2,768.1 3,710.3 -2,700.0323.24 419,647.125,976,540.73 70° 20' 45.465 N 150° 39' 8.057 W 6,300.0 83.94 2,778.7 3,789.9 -2,759.5323.24 419,588.445,976,621.00 70° 20' 46.248 N 150° 39' 9.797 W 6,400.0 83.94 2,789.2 3,869.6 -2,819.1323.24 419,529.765,976,701.26 70° 20' 47.032 N 150° 39' 11.537 W 6,469.1 83.94 2,796.5 3,924.6 -2,860.2323.24 419,489.215,976,756.73 70° 20' 47.573 N 150° 39' 12.739 W TS_790 6,500.0 83.94 2,799.8 3,949.3 -2,878.6323.24 419,471.075,976,781.53 70° 20' 47.815 N 150° 39' 13.277 W 6,600.0 83.94 2,810.3 4,028.9 -2,938.1323.24 419,412.395,976,861.80 70° 20' 48.598 N 150° 39' 15.017 W 6,700.0 83.94 2,820.9 4,108.6 -2,997.6323.24 419,353.715,976,942.07 70° 20' 49.382 N 150° 39' 16.757 W 6,800.0 83.94 2,831.5 4,188.2 -3,057.1323.24 419,295.025,977,022.33 70° 20' 50.165 N 150° 39' 18.497 W 6,900.0 83.94 2,842.0 4,267.9 -3,116.6323.24 419,236.345,977,102.60 70° 20' 50.948 N 150° 39' 20.237 W 7,000.0 83.94 2,852.6 4,347.6 -3,176.2323.24 419,177.665,977,182.87 70° 20' 51.731 N 150° 39' 21.977 W 7,100.0 83.94 2,863.2 4,427.2 -3,235.7323.24 419,118.975,977,263.14 70° 20' 52.514 N 150° 39' 23.717 W 7,200.0 83.94 2,873.7 4,506.9 -3,295.2323.24 419,060.295,977,343.40 70° 20' 53.298 N 150° 39' 25.457 W 7,300.0 83.94 2,884.3 4,586.6 -3,354.7323.24 419,001.615,977,423.67 70° 20' 54.081 N 150° 39' 27.198 W 7,400.0 83.94 2,894.8 4,666.2 -3,414.2323.24 418,942.925,977,503.94 70° 20' 54.864 N 150° 39' 28.938 W 7,500.0 83.94 2,905.4 4,745.9 -3,473.7323.24 418,884.245,977,584.21 70° 20' 55.647 N 150° 39' 30.678 W 7,600.0 83.94 2,916.0 4,825.6 -3,533.3323.24 418,825.565,977,664.48 70° 20' 56.430 N 150° 39' 32.418 W 7,700.0 83.94 2,926.5 4,905.2 -3,592.8323.24 418,766.875,977,744.74 70° 20' 57.214 N 150° 39' 34.159 W 7,800.0 83.94 2,937.1 4,984.9 -3,652.3323.24 418,708.195,977,825.01 70° 20' 57.997 N 150° 39' 35.899 W 7,900.0 83.94 2,947.6 5,064.5 -3,711.8323.24 418,649.515,977,905.28 70° 20' 58.780 N 150° 39' 37.640 W 8,000.0 83.94 2,958.2 5,144.2 -3,771.3323.24 418,590.825,977,985.55 70° 20' 59.563 N 150° 39' 39.380 W 8,100.0 83.94 2,968.8 5,223.9 -3,830.8323.24 418,532.145,978,065.81 70° 21' 0.346 N 150° 39' 41.121 W 8,200.0 83.94 2,979.3 5,303.5 -3,890.4323.24 418,473.465,978,146.08 70° 21' 1.130 N 150° 39' 42.861 W 8,300.0 83.94 2,989.9 5,383.2 -3,949.9323.24 418,414.775,978,226.35 70° 21' 1.913 N 150° 39' 44.602 W 8,400.0 83.94 3,000.4 5,462.9 -4,009.4323.24 418,356.095,978,306.62 70° 21' 2.696 N 150° 39' 46.343 W 8,500.0 83.94 3,011.0 5,542.5 -4,068.9323.24 418,297.415,978,386.88 70° 21' 3.479 N 150° 39' 48.083 W 8,600.0 83.94 3,021.6 5,622.2 -4,128.4323.24 418,238.725,978,467.15 70° 21' 4.262 N 150° 39' 49.824 W 8,700.0 83.94 3,032.1 5,701.8 -4,187.9323.24 418,180.045,978,547.42 70° 21' 5.045 N 150° 39' 51.565 W 8,800.0 83.94 3,042.7 5,781.5 -4,247.5323.24 418,121.365,978,627.69 70° 21' 5.829 N 150° 39' 53.305 W 8,900.0 83.94 3,053.2 5,861.2 -4,307.0323.24 418,062.675,978,707.96 70° 21' 6.612 N 150° 39' 55.046 W 9,000.0 83.94 3,063.8 5,940.8 -4,366.5323.24 418,003.995,978,788.22 70° 21' 7.395 N 150° 39' 56.787 W 15/10/2025 10:50:14 COMPASS 5000.17 Build Page 5 Santos Ltd Planning Report - Geographic Well B-22Local Co-ordinate Reference:Database:EDM DF @ 70.0usftTVD Reference:Santos NAD27 ConversionCompany: DF @ 70.0usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-22Well: NDB-022Wellbore: Plan NDB-022 Rev F.1Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 9,100.0 83.94 3,074.4 6,020.5 -4,426.0323.24 417,945.315,978,868.49 70° 21' 8.178 N 150° 39' 58.528 W 9,200.0 83.94 3,084.9 6,100.2 -4,485.5323.24 417,886.625,978,948.76 70° 21' 8.961 N 150° 40' 0.269 W 9,300.0 83.94 3,095.5 6,179.8 -4,545.1323.24 417,827.945,979,029.03 70° 21' 9.744 N 150° 40' 2.010 W 9,400.0 83.94 3,106.0 6,259.5 -4,604.6323.24 417,769.265,979,109.29 70° 21' 10.527 N 150° 40' 3.751 W 9,500.0 83.94 3,116.6 6,339.1 -4,664.1323.24 417,710.575,979,189.56 70° 21' 11.310 N 150° 40' 5.492 W 9,600.0 83.94 3,127.2 6,418.8 -4,723.6323.24 417,651.895,979,269.83 70° 21' 12.094 N 150° 40' 7.233 W 9,700.0 83.94 3,137.7 6,498.5 -4,783.1323.24 417,593.215,979,350.10 70° 21' 12.877 N 150° 40' 8.974 W 9,800.0 83.94 3,148.3 6,578.1 -4,842.6323.24 417,534.525,979,430.37 70° 21' 13.660 N 150° 40' 10.715 W 9,898.6 83.94 3,158.7 6,656.7 -4,901.3323.24 417,476.675,979,509.49 70° 21' 14.432 N 150° 40' 12.432 W Seabee 9,900.0 83.94 3,158.8 6,657.8 -4,902.2323.24 417,475.845,979,510.63 70° 21' 14.443 N 150° 40' 12.456 W 10,000.0 83.94 3,169.4 6,737.5 -4,961.7323.24 417,417.165,979,590.90 70° 21' 15.226 N 150° 40' 14.198 W 10,100.0 83.94 3,180.0 6,817.1 -5,021.2323.24 417,358.475,979,671.17 70° 21' 16.009 N 150° 40' 15.939 W 10,200.0 83.94 3,190.5 6,896.8 -5,080.7323.24 417,299.795,979,751.44 70° 21' 16.792 N 150° 40' 17.680 W 10,300.0 83.94 3,201.1 6,976.4 -5,140.2323.24 417,241.115,979,831.70 70° 21' 17.575 N 150° 40' 19.422 W 10,400.0 83.94 3,211.6 7,056.1 -5,199.7323.24 417,182.425,979,911.97 70° 21' 18.358 N 150° 40' 21.163 W 10,500.0 83.94 3,222.2 7,135.8 -5,259.3323.24 417,123.745,979,992.24 70° 21' 19.141 N 150° 40' 22.904 W 10,600.0 83.94 3,232.8 7,215.4 -5,318.8323.24 417,065.065,980,072.51 70° 21' 19.924 N 150° 40' 24.646 W 10,700.0 83.94 3,243.3 7,295.1 -5,378.3323.24 417,006.385,980,152.77 70° 21' 20.707 N 150° 40' 26.387 W 10,800.0 83.94 3,253.9 7,374.8 -5,437.8323.24 416,947.695,980,233.04 70° 21' 21.490 N 150° 40' 28.129 W 10,900.0 83.94 3,264.4 7,454.4 -5,497.3323.24 416,889.015,980,313.31 70° 21' 22.273 N 150° 40' 29.870 W 11,000.0 83.94 3,275.0 7,534.1 -5,556.8323.24 416,830.335,980,393.58 70° 21' 23.057 N 150° 40' 31.612 W 11,100.0 83.94 3,285.6 7,613.8 -5,616.4323.24 416,771.645,980,473.85 70° 21' 23.840 N 150° 40' 33.354 W 11,200.0 83.94 3,296.1 7,693.4 -5,675.9323.24 416,712.965,980,554.11 70° 21' 24.623 N 150° 40' 35.095 W 11,300.0 83.94 3,306.7 7,773.1 -5,735.4323.24 416,654.285,980,634.38 70° 21' 25.406 N 150° 40' 36.837 W 11,400.0 83.94 3,317.2 7,852.7 -5,794.9323.24 416,595.595,980,714.65 70° 21' 26.189 N 150° 40' 38.579 W 11,500.0 83.94 3,327.8 7,932.4 -5,854.4323.24 416,536.915,980,794.92 70° 21' 26.972 N 150° 40' 40.320 W 11,600.0 83.94 3,338.4 8,012.1 -5,913.9323.24 416,478.235,980,875.18 70° 21' 27.755 N 150° 40' 42.062 W 11,700.0 83.94 3,348.9 8,091.7 -5,973.5323.24 416,419.545,980,955.45 70° 21' 28.538 N 150° 40' 43.804 W 11,800.0 83.94 3,359.5 8,171.4 -6,033.0323.24 416,360.865,981,035.72 70° 21' 29.321 N 150° 40' 45.546 W 11,900.0 83.94 3,370.1 8,251.1 -6,092.5323.24 416,302.185,981,115.99 70° 21' 30.104 N 150° 40' 47.288 W 12,000.0 83.94 3,380.6 8,330.7 -6,152.0323.24 416,243.495,981,196.26 70° 21' 30.887 N 150° 40' 49.030 W 9-5/8" Intermediate Liner 12,100.0 83.94 3,391.2 8,410.4 -6,211.5323.24 416,184.815,981,276.52 70° 21' 31.670 N 150° 40' 50.772 W 12,200.0 83.94 3,401.7 8,490.0 -6,271.1323.24 416,126.135,981,356.79 70° 21' 32.453 N 150° 40' 52.514 W 12,300.0 83.94 3,412.3 8,569.7 -6,330.6323.24 416,067.445,981,437.06 70° 21' 33.236 N 150° 40' 54.256 W 12,400.0 83.94 3,422.9 8,649.4 -6,390.1323.24 416,008.765,981,517.33 70° 21' 34.019 N 150° 40' 55.998 W 12,500.0 83.94 3,433.4 8,729.0 -6,449.6323.24 415,950.085,981,597.59 70° 21' 34.802 N 150° 40' 57.740 W 12,600.0 83.94 3,444.0 8,808.7 -6,509.1323.24 415,891.395,981,677.86 70° 21' 35.585 N 150° 40' 59.483 W 12,700.0 83.94 3,454.5 8,888.4 -6,568.6323.24 415,832.715,981,758.13 70° 21' 36.368 N 150° 41' 1.225 W 12,800.0 83.94 3,465.1 8,968.0 -6,628.2323.24 415,774.035,981,838.40 70° 21' 37.150 N 150° 41' 2.967 W 12,900.0 83.94 3,475.7 9,047.7 -6,687.7323.24 415,715.345,981,918.66 70° 21' 37.933 N 150° 41' 4.709 W 13,000.0 83.94 3,486.2 9,127.3 -6,747.2323.24 415,656.665,981,998.93 70° 21' 38.716 N 150° 41' 6.452 W 13,100.0 83.94 3,496.8 9,207.0 -6,806.7323.24 415,597.985,982,079.20 70° 21' 39.499 N 150° 41' 8.194 W 13,200.0 83.94 3,507.3 9,286.7 -6,866.2323.24 415,539.295,982,159.47 70° 21' 40.282 N 150° 41' 9.936 W 13,300.0 83.94 3,517.9 9,366.3 -6,925.7323.24 415,480.615,982,239.74 70° 21' 41.065 N 150° 41' 11.679 W 13,400.0 83.94 3,528.5 9,446.0 -6,985.3323.24 415,421.935,982,320.00 70° 21' 41.848 N 150° 41' 13.421 W 13,500.0 83.94 3,539.0 9,525.7 -7,044.8323.24 415,363.245,982,400.27 70° 21' 42.631 N 150° 41' 15.164 W 13,600.0 83.94 3,549.6 9,605.3 -7,104.3323.24 415,304.565,982,480.54 70° 21' 43.414 N 150° 41' 16.906 W 13,700.0 83.94 3,560.1 9,685.0 -7,163.8323.24 415,245.885,982,560.81 70° 21' 44.197 N 150° 41' 18.649 W 13,800.0 83.94 3,570.7 9,764.6 -7,223.3323.24 415,187.195,982,641.07 70° 21' 44.980 N 150° 41' 20.392 W 13,900.0 83.94 3,581.3 9,844.3 -7,282.8323.24 415,128.515,982,721.34 70° 21' 45.763 N 150° 41' 22.134 W 14,000.0 83.94 3,591.8 9,924.0 -7,342.4323.24 415,069.835,982,801.61 70° 21' 46.546 N 150° 41' 23.877 W 14,100.0 83.94 3,602.4 10,003.6 -7,401.9323.24 415,011.145,982,881.88 70° 21' 47.328 N 150° 41' 25.620 W 14,200.0 83.94 3,612.9 10,083.3 -7,461.4323.24 414,952.465,982,962.15 70° 21' 48.111 N 150° 41' 27.363 W 14,300.0 83.94 3,623.5 10,163.0 -7,520.9323.24 414,893.785,983,042.41 70° 21' 48.894 N 150° 41' 29.105 W 14,400.0 83.94 3,634.1 10,242.6 -7,580.4323.24 414,835.095,983,122.68 70° 21' 49.677 N 150° 41' 30.848 W 14,500.0 83.94 3,644.6 10,322.3 -7,639.9323.24 414,776.415,983,202.95 70° 21' 50.460 N 150° 41' 32.591 W 14,600.0 83.94 3,655.2 10,402.0 -7,699.5323.24 414,717.735,983,283.22 70° 21' 51.243 N 150° 41' 34.334 W 15/10/2025 10:50:14 COMPASS 5000.17 Build Page 6 Santos Ltd Planning Report - Geographic Well B-22Local Co-ordinate Reference:Database:EDM DF @ 70.0usftTVD Reference:Santos NAD27 ConversionCompany: DF @ 70.0usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-22Well: NDB-022Wellbore: Plan NDB-022 Rev F.1Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 14,700.0 83.94 3,665.7 10,481.6 -7,759.0323.24 414,659.045,983,363.48 70° 21' 52.026 N 150° 41' 36.077 W 14,800.0 83.94 3,676.3 10,561.3 -7,818.5323.24 414,600.365,983,443.75 70° 21' 52.809 N 150° 41' 37.820 W 14,900.0 83.94 3,686.9 10,640.9 -7,878.0323.24 414,541.685,983,524.02 70° 21' 53.591 N 150° 41' 39.563 W 15,000.0 83.94 3,697.4 10,720.6 -7,937.5323.24 414,482.995,983,604.29 70° 21' 54.374 N 150° 41' 41.306 W 15,100.0 83.94 3,708.0 10,800.3 -7,997.1323.24 414,424.315,983,684.55 70° 21' 55.157 N 150° 41' 43.049 W 15,200.0 83.94 3,718.5 10,879.9 -8,056.6323.24 414,365.635,983,764.82 70° 21' 55.940 N 150° 41' 44.792 W 15,300.0 83.94 3,729.1 10,959.6 -8,116.1323.24 414,306.945,983,845.09 70° 21' 56.723 N 150° 41' 46.536 W 15,400.0 83.94 3,739.7 11,039.3 -8,175.6323.24 414,248.265,983,925.36 70° 21' 57.506 N 150° 41' 48.279 W 15,500.0 83.94 3,750.2 11,118.9 -8,235.1323.24 414,189.585,984,005.63 70° 21' 58.289 N 150° 41' 50.022 W 15,600.0 83.94 3,760.8 11,198.6 -8,294.6323.24 414,130.895,984,085.89 70° 21' 59.071 N 150° 41' 51.765 W 15,687.0 83.94 3,770.0 11,267.9 -8,346.4323.24 414,079.835,984,155.73 70° 21' 59.752 N 150° 41' 53.282 W Nanushuk 15,700.0 83.94 3,771.3 11,278.2 -8,354.2323.24 414,072.215,984,166.16 70° 21' 59.854 N 150° 41' 53.509 W 15,800.0 83.94 3,781.9 11,357.9 -8,413.7323.24 414,013.535,984,246.43 70° 22' 0.637 N 150° 41' 55.252 W 15,900.0 83.94 3,792.5 11,437.6 -8,473.2323.24 413,954.845,984,326.70 70° 22' 1.420 N 150° 41' 56.996 W 16,000.0 83.94 3,803.0 11,517.2 -8,532.7323.24 413,896.165,984,406.96 70° 22' 2.203 N 150° 41' 58.739 W 16,100.0 83.94 3,813.6 11,596.9 -8,592.2323.24 413,837.485,984,487.23 70° 22' 2.985 N 150° 42' 0.482 W 16,189.1 83.94 3,823.0 11,667.9 -8,645.3323.24 413,785.185,984,558.77 70° 22' 3.683 N 150° 42' 2.036 W NT8 MFS 16,200.0 83.94 3,824.1 11,676.6 -8,651.7323.24 413,778.795,984,567.50 70° 22' 3.768 N 150° 42' 2.226 W 16,300.0 83.94 3,834.7 11,756.2 -8,711.3323.24 413,720.115,984,647.77 70° 22' 4.551 N 150° 42' 3.970 W 16,400.0 83.94 3,845.3 11,835.9 -8,770.8323.24 413,661.435,984,728.03 70° 22' 5.334 N 150° 42' 5.713 W 16,500.0 83.94 3,855.8 11,915.5 -8,830.3323.24 413,602.745,984,808.30 70° 22' 6.117 N 150° 42' 7.457 W 16,539.6 83.94 3,860.0 11,947.1 -8,853.9323.24 413,579.485,984,840.12 70° 22' 6.427 N 150° 42' 8.148 W NT7 MFS 16,600.0 83.94 3,866.4 11,995.2 -8,889.8323.24 413,544.065,984,888.57 70° 22' 6.899 N 150° 42' 9.200 W 16,700.0 83.94 3,877.0 12,074.9 -8,949.3323.24 413,485.385,984,968.84 70° 22' 7.682 N 150° 42' 10.944 W 16,800.0 83.94 3,887.5 12,154.5 -9,008.8323.24 413,426.695,985,049.11 70° 22' 8.465 N 150° 42' 12.688 W 16,900.0 83.94 3,898.1 12,234.2 -9,068.4323.24 413,368.015,985,129.37 70° 22' 9.248 N 150° 42' 14.432 W 17,000.0 83.94 3,908.6 12,313.9 -9,127.9323.24 413,309.335,985,209.64 70° 22' 10.030 N 150° 42' 16.175 W 17,003.9 83.94 3,909.0 12,316.9 -9,130.2323.24 413,307.065,985,212.74 70° 22' 10.061 N 150° 42' 16.243 W NT6 MFS 17,100.0 83.94 3,919.2 12,393.5 -9,187.4323.24 413,250.645,985,289.91 70° 22' 10.813 N 150° 42' 17.919 W 17,200.0 83.94 3,929.8 12,473.2 -9,246.9323.24 413,191.965,985,370.18 70° 22' 11.596 N 150° 42' 19.663 W 17,250.2 83.94 3,935.1 12,513.2 -9,276.8323.24 413,162.525,985,410.45 70° 22' 11.989 N 150° 42' 20.538 W NT5 MFS 17,300.0 83.94 3,940.3 12,552.9 -9,306.4323.24 413,133.285,985,450.44 70° 22' 12.379 N 150° 42' 21.407 W 17,400.0 83.94 3,950.9 12,632.5 -9,365.9323.24 413,074.595,985,530.71 70° 22' 13.161 N 150° 42' 23.151 W 17,500.0 83.94 3,961.4 12,712.2 -9,425.5323.24 413,015.915,985,610.98 70° 22' 13.944 N 150° 42' 24.895 W 17,600.0 83.94 3,972.0 12,791.8 -9,485.0323.24 412,957.235,985,691.25 70° 22' 14.727 N 150° 42' 26.639 W 17,629.1 83.94 3,975.1 12,815.0 -9,502.3323.24 412,940.145,985,714.62 70° 22' 14.955 N 150° 42' 27.147 W NT4 MFS 17,671.5 83.94 3,979.5 12,848.8 -9,527.5323.24 412,915.285,985,748.62 70° 22' 15.286 N 150° 42' 27.886 W 17,700.0 83.19 3,982.7 12,871.5 -9,544.4323.66 412,898.645,985,771.56 70° 22' 15.510 N 150° 42' 28.380 W 17,800.0 80.58 3,996.9 12,952.0 -9,602.0325.15 412,841.865,985,852.64 70° 22' 16.301 N 150° 42' 30.069 W 17,900.0 77.98 4,015.5 13,033.4 -9,657.1326.67 412,787.655,985,934.55 70° 22' 17.100 N 150° 42' 31.683 W 18,000.0 75.38 4,038.5 13,115.4 -9,709.5328.21 412,736.135,986,017.08 70° 22' 17.906 N 150° 42' 33.218 W 18,018.3 74.91 4,043.2 13,130.4 -9,718.7328.50 412,727.035,986,032.21 70° 22' 18.054 N 150° 42' 33.490 W NT3 MFS 18,072.7 73.50 4,058.0 13,175.3 -9,745.8329.36 412,700.455,986,077.37 70° 22' 18.495 N 150° 42' 34.283 W 18,090.0 73.50 4,062.9 13,189.6 -9,754.2329.36 412,692.165,986,091.70 70° 22' 18.635 N 150° 42' 34.530 W 7" Intermediate Liner 18,100.0 73.50 4,065.7 13,197.8 -9,759.1329.36 412,687.365,986,100.00 70° 22' 18.716 N 150° 42' 34.674 W 18,173.7 73.50 4,086.7 13,258.6 -9,795.1329.36 412,651.985,986,161.16 70° 22' 19.314 N 150° 42' 35.730 W 18,197.2 74.44 4,093.2 13,278.1 -9,806.6329.36 412,640.655,986,180.75 70° 22' 19.505 N 150° 42' 36.068 W NT3.2 Top Reservoir 18,200.0 74.55 4,093.9 13,280.4 -9,808.0329.36 412,639.325,986,183.05 70° 22' 19.527 N 150° 42' 36.107 W 18,300.0 78.55 4,117.2 13,364.0 -9,857.6329.36 412,590.635,986,267.21 70° 22' 20.349 N 150° 42' 37.560 W 18,400.0 82.55 4,133.6 13,448.9 -9,907.8329.35 412,541.255,986,352.57 70° 22' 21.183 N 150° 42' 39.034 W 15/10/2025 10:50:14 COMPASS 5000.17 Build Page 7 Santos Ltd Planning Report - Geographic Well B-22Local Co-ordinate Reference:Database:EDM DF @ 70.0usftTVD Reference:Santos NAD27 ConversionCompany: DF @ 70.0usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-22Well: NDB-022Wellbore: Plan NDB-022 Rev F.1Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 18,500.0 86.55 4,143.1 13,534.5 -9,958.6329.35 412,491.415,986,438.71 70° 22' 22.025 N 150° 42' 40.522 W 18,599.6 90.53 4,145.6 13,620.1 -10,009.3329.35 412,441.585,986,524.82 70° 22' 22.866 N 150° 42' 42.009 W 18,600.0 90.53 4,145.6 13,620.5 -10,009.5329.35 412,441.365,986,525.21 70° 22' 22.870 N 150° 42' 42.016 W 18,700.0 90.53 4,144.7 13,706.5 -10,060.5329.35 412,391.285,986,611.75 70° 22' 23.715 N 150° 42' 43.511 W 18,800.0 90.53 4,143.7 13,792.5 -10,111.5329.35 412,341.205,986,698.29 70° 22' 24.561 N 150° 42' 45.006 W 18,900.0 90.53 4,142.8 13,878.6 -10,162.4329.35 412,291.125,986,784.83 70° 22' 25.406 N 150° 42' 46.501 W 19,000.0 90.53 4,141.9 13,964.6 -10,213.4329.35 412,241.045,986,871.37 70° 22' 26.251 N 150° 42' 47.996 W 19,100.0 90.53 4,140.9 14,050.6 -10,264.4329.35 412,190.965,986,957.91 70° 22' 27.097 N 150° 42' 49.491 W 19,200.0 90.53 4,140.0 14,136.6 -10,315.4329.35 412,140.885,987,044.45 70° 22' 27.942 N 150° 42' 50.986 W 19,300.0 90.53 4,139.1 14,222.7 -10,366.4329.35 412,090.815,987,131.00 70° 22' 28.787 N 150° 42' 52.481 W 19,400.0 90.53 4,138.1 14,308.7 -10,417.3329.35 412,040.735,987,217.54 70° 22' 29.633 N 150° 42' 53.976 W 19,500.0 90.53 4,137.2 14,394.7 -10,468.3329.35 411,990.655,987,304.08 70° 22' 30.478 N 150° 42' 55.471 W 19,600.0 90.53 4,136.3 14,480.7 -10,519.3329.35 411,940.575,987,390.62 70° 22' 31.323 N 150° 42' 56.966 W 19,700.0 90.53 4,135.3 14,566.8 -10,570.3329.35 411,890.505,987,477.16 70° 22' 32.169 N 150° 42' 58.461 W 19,800.0 90.53 4,134.4 14,652.8 -10,621.2329.35 411,840.425,987,563.71 70° 22' 33.014 N 150° 42' 59.956 W 19,900.0 90.53 4,133.5 14,738.8 -10,672.2329.35 411,790.355,987,650.25 70° 22' 33.859 N 150° 43' 1.451 W 20,000.0 90.53 4,132.5 14,824.9 -10,723.2329.35 411,740.275,987,736.79 70° 22' 34.705 N 150° 43' 2.946 W 20,100.0 90.53 4,131.6 14,910.9 -10,774.2329.35 411,690.205,987,823.34 70° 22' 35.550 N 150° 43' 4.442 W 20,200.0 90.53 4,130.7 14,996.9 -10,825.1329.35 411,640.125,987,909.88 70° 22' 36.396 N 150° 43' 5.937 W 20,300.0 90.53 4,129.7 15,082.9 -10,876.1329.35 411,590.055,987,996.42 70° 22' 37.241 N 150° 43' 7.432 W 20,400.0 90.53 4,128.8 15,169.0 -10,927.1329.35 411,539.975,988,082.97 70° 22' 38.086 N 150° 43' 8.927 W 20,500.0 90.53 4,127.9 15,255.0 -10,978.0329.35 411,489.905,988,169.51 70° 22' 38.932 N 150° 43' 10.423 W 20,600.0 90.53 4,126.9 15,341.0 -11,029.0329.35 411,439.835,988,256.06 70° 22' 39.777 N 150° 43' 11.918 W 20,700.0 90.53 4,126.0 15,427.1 -11,080.0329.35 411,389.755,988,342.60 70° 22' 40.622 N 150° 43' 13.413 W 20,800.0 90.53 4,125.1 15,513.1 -11,131.0329.35 411,339.685,988,429.15 70° 22' 41.468 N 150° 43' 14.909 W 20,900.0 90.53 4,124.2 15,599.1 -11,181.9329.35 411,289.615,988,515.69 70° 22' 42.313 N 150° 43' 16.404 W 21,000.0 90.53 4,123.2 15,685.1 -11,232.9329.35 411,239.545,988,602.24 70° 22' 43.158 N 150° 43' 17.900 W 21,100.0 90.53 4,122.3 15,771.2 -11,283.9329.35 411,189.465,988,688.78 70° 22' 44.004 N 150° 43' 19.395 W 21,200.0 90.53 4,121.4 15,857.2 -11,334.8329.35 411,139.395,988,775.33 70° 22' 44.849 N 150° 43' 20.891 W 21,300.0 90.53 4,120.4 15,943.2 -11,385.8329.35 411,089.325,988,861.87 70° 22' 45.694 N 150° 43' 22.386 W 21,400.0 90.53 4,119.5 16,029.3 -11,436.8329.36 411,039.255,988,948.42 70° 22' 46.540 N 150° 43' 23.882 W 21,500.0 90.53 4,118.6 16,115.3 -11,487.7329.36 410,989.185,989,034.96 70° 22' 47.385 N 150° 43' 25.377 W 21,600.0 90.53 4,117.6 16,201.3 -11,538.7329.36 410,939.115,989,121.51 70° 22' 48.230 N 150° 43' 26.873 W 21,700.0 90.53 4,116.7 16,287.4 -11,589.7329.36 410,889.045,989,208.06 70° 22' 49.076 N 150° 43' 28.368 W 21,800.0 90.53 4,115.8 16,373.4 -11,640.7329.36 410,838.975,989,294.60 70° 22' 49.921 N 150° 43' 29.864 W 21,900.0 90.53 4,114.8 16,459.4 -11,691.6329.36 410,788.905,989,381.15 70° 22' 50.766 N 150° 43' 31.360 W 22,000.0 90.53 4,113.9 16,545.5 -11,742.6329.36 410,738.835,989,467.70 70° 22' 51.611 N 150° 43' 32.855 W 22,100.0 90.53 4,113.0 16,631.5 -11,793.6329.36 410,688.765,989,554.24 70° 22' 52.457 N 150° 43' 34.351 W 22,200.0 90.53 4,112.0 16,717.5 -11,844.5329.36 410,638.705,989,640.79 70° 22' 53.302 N 150° 43' 35.847 W 22,300.0 90.53 4,111.1 16,803.5 -11,895.5329.36 410,588.635,989,727.34 70° 22' 54.147 N 150° 43' 37.342 W 22,400.0 90.53 4,110.2 16,889.6 -11,946.5329.36 410,538.565,989,813.89 70° 22' 54.993 N 150° 43' 38.838 W 22,500.0 90.53 4,109.2 16,975.6 -11,997.4329.36 410,488.495,989,900.44 70° 22' 55.838 N 150° 43' 40.334 W 22,600.0 90.53 4,108.3 17,061.6 -12,048.4329.36 410,438.435,989,986.98 70° 22' 56.683 N 150° 43' 41.830 W 22,700.0 90.53 4,107.4 17,147.7 -12,099.4329.36 410,388.365,990,073.53 70° 22' 57.529 N 150° 43' 43.326 W 22,800.0 90.53 4,106.4 17,233.7 -12,150.3329.36 410,338.295,990,160.08 70° 22' 58.374 N 150° 43' 44.822 W 22,900.0 90.53 4,105.5 17,319.7 -12,201.3329.36 410,288.235,990,246.63 70° 22' 59.219 N 150° 43' 46.317 W 22,952.3 90.53 4,105.0 17,364.8 -12,228.0329.36 410,262.035,990,291.92 70° 22' 59.662 N 150° 43' 47.100 W 22,953.0 90.55 4,105.0 17,365.3 -12,228.3329.36 410,261.695,990,292.50 70° 22' 59.667 N 150° 43' 47.110 W NDB-022_Fault 23,000.0 91.96 4,104.0 17,405.8 -12,252.3329.31 410,238.155,990,333.16 70° 23' 0.064 N 150° 43' 47.814 W 23,019.2 92.54 4,103.2 17,422.3 -12,262.1329.29 410,228.505,990,349.79 70° 23' 0.227 N 150° 43' 48.102 W 23,100.0 92.54 4,099.6 17,491.7 -12,303.3329.29 410,188.035,990,419.57 70° 23' 0.908 N 150° 43' 49.311 W 23,200.0 92.54 4,095.2 17,577.5 -12,354.3329.29 410,137.905,990,505.98 70° 23' 1.752 N 150° 43' 50.809 W 23,246.2 92.54 4,093.1 17,617.3 -12,377.9329.29 410,114.735,990,545.93 70° 23' 2.142 N 150° 43' 51.502 W 23,278.4 93.49 4,091.4 17,644.9 -12,394.3329.48 410,098.645,990,573.75 70° 23' 2.414 N 150° 43' 51.982 W 23,300.0 93.49 4,090.1 17,663.5 -12,405.2329.48 410,087.905,990,592.42 70° 23' 2.596 N 150° 43' 52.303 W 23,400.0 93.49 4,084.1 17,749.5 -12,455.9329.48 410,038.105,990,678.91 70° 23' 3.441 N 150° 43' 53.791 W 23,497.1 93.49 4,078.1 17,833.0 -12,505.1329.48 409,989.735,990,762.93 70° 23' 4.262 N 150° 43' 55.237 W 23,500.0 93.57 4,078.0 17,835.4 -12,506.6329.48 409,988.315,990,765.41 70° 23' 4.286 N 150° 43' 55.280 W 23,600.0 96.50 4,069.2 17,921.2 -12,557.2329.47 409,938.615,990,851.71 70° 23' 5.129 N 150° 43' 56.765 W 15/10/2025 10:50:14 COMPASS 5000.17 Build Page 8 Santos Ltd Planning Report - Geographic Well B-22Local Co-ordinate Reference:Database:EDM DF @ 70.0usftTVD Reference:Santos NAD27 ConversionCompany: DF @ 70.0usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-22Well: NDB-022Wellbore: Plan NDB-022 Rev F.1Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft)Latitude Longitude Planned Survey Vertical Depth (usft) 23,688.0 99.07 4,057.3 17,996.3 -12,601.5329.47 409,895.105,990,927.26 70° 23' 5.867 N 150° 43' 58.065 W NT3.2 Top Reservoir Up 23,700.0 99.42 4,055.3 18,006.5 -12,607.5329.46 409,889.195,990,937.52 70° 23' 5.967 N 150° 43' 58.242 W 23,800.0 102.35 4,036.5 18,091.1 -12,657.4329.46 409,840.185,991,022.59 70° 23' 6.798 N 150° 43' 59.707 W 23,884.0 104.80 4,016.8 18,161.4 -12,698.9329.45 409,799.425,991,093.33 70° 23' 7.489 N 150° 44' 0.925 W NT3 MFS Toe up 23,900.0 105.27 4,012.6 18,174.7 -12,706.7329.45 409,791.715,991,106.72 70° 23' 7.620 N 150° 44' 1.155 W 23,945.9 106.61 4,000.0 18,212.7 -12,729.2329.45 409,769.685,991,144.94 70° 23' 7.993 N 150° 44' 1.814 W Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Design Targets LongitudeLatitude Dip Angle (°) Dip Dir. (°) NDB-022 Toe Rev 2.0 4,000.0 5,991,144.94 409,769.6818,212.7 -12,729.20.00 0.00 70° 23' 7.993 N 150° 44' 1.814 W - plan hits target center - Point NDB-022 Fault Block-4,078.1 5,990,762.93 409,989.7317,833.0 -12,505.10.00 0.00 70° 23' 4.262 N 150° 43' 55.237 W - plan hits target center - Point NDB-022 Fault Block-4,093.1 5,990,545.93 410,114.7317,617.3 -12,377.90.00 0.00 70° 23' 2.142 N 150° 43' 51.502 W - plan hits target center - Point NDB-022 Fault Target 4,105.0 5,990,291.92 410,262.0317,364.8 -12,228.00.00 0.00 70° 22' 59.662 N 150° 43' 47.100 W - plan hits target center - Point NDB-022 Heel Rev 1.4,145.6 5,986,524.82 412,441.5813,620.1 -10,009.30.00 0.00 70° 22' 22.866 N 150° 42' 42.009 W - plan hits target center - Polygon -104.7Point 1 5,986,415.87 412,851.644,145.6 411.2 True 5,003.5Point 2 5,991,554.68 409,878.404,145.6 -2,615.4 True 4,697.1Point 3 5,991,253.66 409,359.404,145.6 -3,131.3 True -411.1Point 4 5,986,114.86 412,332.644,145.6 -104.7 True Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 20" Conductor Driven128.0128.0 20 20 13-3/8" Surface Casing2,385.53,065.0 13-3/8 16 9-5/8" Intermediate Liner3,380.612,000.0 9-5/8 12-1/4 7" Intermediate Liner4,062.918,090.0 7 8-1/2 4-1/2" x 6-1/8"3,999.923,946.2 4-1/2 6-1/8 15/10/2025 10:50:14 COMPASS 5000.17 Build Page 9 Santos Ltd Planning Report - Geographic Well B-22Local Co-ordinate Reference:Database:EDM DF @ 70.0usftTVD Reference:Santos NAD27 ConversionCompany: DF @ 70.0usftMD Reference:PikkaProject: TrueNorth Reference:NDBSite: Minimum CurvatureSurvey Calculation Method:B-22Well: NDB-022Wellbore: Plan NDB-022 Rev F.1Design: Measured Depth (usft) Vertical Depth (usft) Dip Direction (°)Name Lithology Dip (°) Formations 1,061.1 Upper Schrader Bluff1,048.0 1,157.8 Base Ice Bearing Permafrost1,140.0 1,432.3 Base Permafrost Transition1,394.0 1,849.0 Middle Schrader Bluff1,744.0 2,438.9 MCU2,135.8 3,228.1 Tuluvak Shale2,432.5 3,645.9 Tuluvak Sand2,498.4 6,469.1 TS_7902,796.5 9,898.6 Seabee3,158.7 15,687.0 Nanushuk3,770.0 16,189.1 NT8 MFS3,823.0 16,539.6 NT7 MFS3,860.0 17,003.9 NT6 MFS3,909.0 17,250.2 NT5 MFS3,935.1 17,629.1 NT4 MFS3,975.1 23,884.0 NT3 MFS Toe up4,016.8 18,018.3 NT3 MFS4,043.2 23,688.0 NT3.2 Top Reservoir Up4,057.3 18,197.2 NT3.2 Top Reservoir4,093.2 22,953.0 NDB-022_Fault4,105.0 15/10/2025 10:50:14 COMPASS 5000.17 Build Page 10 South(-)/North(+) True Vertical Depth 15 October, 2025 Anticollision Summary Report Santos Pikka NDB B-22 NDB-022 Plan NDB-022 Rev F.1 Santos Ltd Anticollision Summary Report Well B-22 - Slot B-22Local Co-ordinate Reference:SantosCompany: DF @ 70.0usftTVD Reference:PikkaProject: DF @ 70.0usftMD Reference:NDBReference Site: TrueNorth Reference:0.9 usftSite Error: Minimum CurvatureSurvey Calculation Method:B-22Reference Well: Output errors are at 2.79 sigmaWell Error:0.5 usft Reference Wellbore NDB-022 Database:EDM Offset DatumReference Design:Plan NDB-022 Rev F.1 Offset TVD Reference: Interpolation Method: Depth Range: Reference Error Model: Scan Method: Error Surface: Filter type: ISCWSA Closest Approach 3D Combined Pedal Curve GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refere MD Interval 25.0usft Unlimited Maximum centre distance of 2,589.9usft Plan NDB-022 Rev F.1 Results Limited by: SigmaWarning Levels Evaluated at:2.79 ISCWSA TESTCasing Method: From (usft) Survey Tool Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 15/10/2025 SDI_KPR_gyroMWD+SAGSDI Keeper gyroMWD + SAG47.0 1,000.0 Plan NDB-022 Rev F.1 (NDB-022) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag1,000.0 3,065.0 Plan NDB-022 Rev F.1 (NDB-022) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag3,065.0 12,000.0 Plan NDB-022 Rev F.1 (NDB-022) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag12,000.0 18,073.0 Plan NDB-022 Rev F.1 (NDB-022) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag18,073.0 23,946.2 Plan NDB-022 Rev F.1 (NDB-022) Offset Well - Wellbore - Design Reference Measured Depth (usft) Offset Measured Depth (usft) Between Centres (usft) Between Ellipses (usft) Separation Factor Warning Summary Site Name Distance NDB CCB-09 - NDB-09 - Plan: NDB-09 Slot Saver 461.0 461.0 260.3 250.0 43.617 ESB-09 - NDB-09 - Plan: NDB-09 Slot Saver 575.0 574.6 260.5 249.5 40.510 SFB-09 - NDB-09 - Plan: NDB-09 Slot Saver 975.0 966.1 288.6 274.8 33.134 CCB-10 - NDB-010 - NDB-010 517.0 516.5 237.8 227.7 40.543 ESB-10 - NDB-010 - NDB-010 550.0 548.6 237.9 227.6 39.939 SFB-10 - NDB-010 - NDB-010 8,675.0 8,429.2 2,543.7 2,298.0 13.062 CCB-10 - NDB-010 - Plan: NDB-010 Rev G.0 517.0 516.3 237.8 227.7 40.543 ESB-10 - NDB-010 - Plan: NDB-010 Rev G.0 550.0 548.4 237.9 227.6 39.939 SFB-10 - NDB-010 - Plan: NDB-010 Rev G.0 8,675.0 8,429.0 2,543.7 2,298.0 13.062 CCB-11 - NDB-011 - NDB-011 639.7 645.6 218.7 208.0 34.773 ESB-11 - NDB-011 - NDB-011 650.0 655.9 218.7 208.0 34.491 SFB-11 - NDB-011 - NDB-011 900.0 894.6 240.0 227.5 30.909 CCB-12 - NDBi-012 - Plan: NDBi-012 Slot Saver 450.0 449.8 200.6 190.6 35.176 ESB-12 - NDBi-012 - Plan: NDBi-012 Slot Saver 550.0 549.5 200.7 190.4 33.447 SFB-12 - NDBi-012 - Plan: NDBi-012 Slot Saver 900.0 893.8 220.6 208.2 28.753 CCB-13 - NDB-013 - Plan: NDBi-013 Slot Saver 443.1 442.9 180.5 170.6 31.740 ESB-13 - NDB-013 - Plan: NDBi-013 Slot Saver 550.0 549.5 180.7 170.3 30.069 SFB-13 - NDB-013 - Plan: NDBi-013 Slot Saver 900.0 893.8 201.7 189.2 26.164 CCB-14 - NDBi-014 - NDBi-014 445.5 445.7 160.1 150.1 27.897 ESB-14 - NDBi-014 - NDBi-014 475.0 475.0 160.1 150.0 27.455 SFB-14 - NDBi-014 - NDBi-014 850.0 848.7 184.2 171.9 24.043 CCB-15 - NDB-015 - Plan: NDB-015 Rev A.0 778.3 782.9 135.3 123.1 17.967 ESB-15 - NDB-015 - Plan: NDB-015 Rev A.0 825.0 830.0 135.5 122.9 17.316 SFB-15 - NDB-015 - Plan: NDB-015 Rev A.0 11,900.0 11,592.0 2,148.7 1,720.6 6.305 CCB-16 - NDBi-016 - NDBi-016 702.5 705.0 115.8 104.7 17.347 ESB-16 - NDBi-016 - NDBi-016 775.0 778.9 115.9 104.5 16.619 SFB-16 - NDBi-016 - NDBi-016 18,575.0 18,628.1 1,807.2 1,217.6 3.842 CCB-17 - NDB-017 - NDB-017 Slot Saver 410.0 410.0 100.0 90.3 17.848 ESB-17 - NDB-017 - NDB-017 Slot Saver 500.0 499.9 100.1 90.0 16.987 SFB-17 - NDB-017 - NDB-017 Slot Saver 750.0 747.8 108.5 97.1 15.623 CCB-18 - NDBi-018 - NDBi-018 582.5 582.5 79.9 69.5 12.981 ESB-18 - NDBi-018 - NDBi-018 625.0 625.4 80.0 69.5 12.685 SFB-18 - NDBi-018 - NDBi-018 12,675.0 13,105.0 1,436.8 1,069.1 4.907 CCB-19 - NDBi-019 - Plan: NDBi-019 Rev A.0 379.0 379.1 60.1 50.1 10.352 ESB-19 - NDBi-019 - Plan: NDBi-019 Rev A.0 425.0 424.9 60.1 50.0 10.094 SFB-19 - NDBi-019 - Plan: NDBi-019 Rev A.0 525.0 523.7 61.8 51.2 9.703 CCB-20 - NDBi-020 - Plan: NDBi-020 Rev A.0 645.8 646.1 39.9 28.6 5.630 ESB-20 - NDBi-020 - Plan: NDBi-020 Rev A.0 725.0 725.5 40.1 28.3 5.308 15/10/2025 10:28:34 COMPASS 5000.17 Build CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 2 Santos Ltd Anticollision Summary Report Well B-22 - Slot B-22Local Co-ordinate Reference:SantosCompany: DF @ 70.0usftTVD Reference:PikkaProject: DF @ 70.0usftMD Reference:NDBReference Site: TrueNorth Reference:0.9 usftSite Error: Minimum CurvatureSurvey Calculation Method:B-22Reference Well: Output errors are at 2.79 sigmaWell Error:0.5 usft Reference Wellbore NDB-022 Database:EDM Offset DatumReference Design:Plan NDB-022 Rev F.1 Offset TVD Reference: Offset Well - Wellbore - Design Reference Measured Depth (usft) Offset Measured Depth (usft) Between Centres (usft) Between Ellipses (usft) Separation Factor Warning Summary Site Name Distance NDB SFB-20 - NDBi-020 - Plan: NDBi-020 Rev A.0 23,946.2 23,724.0 1,805.1 1,108.0 3.243 CCB-21 - NDB-021 - Plan:NDB-021 Rev A.0 357.0 357.0 20.0 10.2 3.206 ESB-21 - NDB-021 - Plan:NDB-021 Rev A.0 400.0 400.0 20.0 10.1 3.158 SFB-21 - NDB-021 - Plan:NDB-021 Rev A.0 425.0 424.9 20.2 10.1 3.134 CCB-23 - NDB-023 - NDB-023 Slot Saver 325.0 325.0 20.1 10.5 3.338 ESB-23 - NDB-023 - NDB-023 Slot Saver 425.0 425.0 20.2 10.4 3.230 SFB-23 - NDB-023 - NDB-023 Slot Saver 475.0 474.9 20.5 10.5 3.189 CCB-24 - NDB-024 - NDB-024 549.2 548.4 38.6 28.3 6.002 Take Immediate Action, EB-24 - NDB-024 - NDB-024 18,025.0 18,029.0 117.1 -6.2 1.191 CCB-24 - NDB-024PB1 - NDB-024PB1 549.2 548.4 38.6 28.1 5.976 ESB-24 - NDB-024PB1 - NDB-024PB1 575.0 574.0 38.7 28.1 5.909 SFB-24 - NDB-024PB1 - NDB-024PB1 900.0 892.9 45.3 32.3 5.311 CCB-25 - NDB-025 - NDB-025 50.0 49.5 59.5 50.4 12.273 ESB-25 - NDB-025 - NDB-025 200.0 199.3 59.8 50.6 11.473 SFB-25 - NDB-025 - NDB-025 500.0 498.0 62.7 52.6 10.426 CCB-26 - NDBi-026 - Plan: NDBi-026 Rev A.0 472.6 472.4 79.4 69.1 12.940 ESB-26 - NDBi-026 - Plan: NDBi-026 Rev A.0 575.0 574.3 79.5 68.7 12.130 SFB-26 - NDBi-026 - Plan: NDBi-026 Rev A.0 23,946.2 24,102.9 1,803.1 1,115.4 3.284 CCB-27 - NDB-027 - NDB-027 304.2 304.0 98.7 88.7 16.843 ESB-27 - NDB-027 - NDB-027 375.0 374.3 98.8 88.5 16.210 SFB-27 - NDB-027 - NDB-027 11,175.0 10,857.0 2,426.4 1,887.5 5.650 CCB-27 - NDB-027 MWD - NDB-027 MWD 304.0 303.8 98.7 88.7 16.941 ESB-27 - NDB-027 MWD - NDB-027 MWD 375.0 374.4 98.8 88.5 16.294 SFB-27 - NDB-027 MWD - NDB-027 MWD 11,875.0 11,481.6 2,573.8 2,110.4 6.975 CCB-27 - NDB-027 PB1 - NDB-027 PB1 304.2 304.1 98.7 88.7 16.843 ESB-27 - NDB-027 PB1 - NDB-027 PB1 375.0 374.4 98.8 88.5 16.210 SFB-27 - NDB-027 PB1 - NDB-027 PB1 3,100.0 3,000.1 397.9 318.0 6.399 CCB-28 - NDBi-028 - Plan NDBi-028 Rev A.0 325.0 325.0 120.2 110.4 21.627 ESB-28 - NDBi-028 - Plan NDBi-028 Rev A.0 425.0 424.8 120.3 110.2 20.604 SFB-28 - NDBi-028 - Plan NDBi-028 Rev A.0 650.0 639.4 129.5 118.2 18.994 CCB-29 - NDB-029 - NDB-29 Slot Saver 325.0 325.0 140.3 130.7 25.851 ESB-29 - NDB-029 - NDB-29 Slot Saver 500.0 499.9 140.4 130.3 23.911 SFB-29 - NDB-029 - NDB-29 Slot Saver 950.0 942.1 151.9 139.2 19.217 CCB-30 - NDBi-030 - NDBi-030 1,248.3 1,235.2 154.2 140.6 17.733 ESB-30 - NDBi-030 - NDBi-030 1,275.0 1,260.4 154.2 140.5 17.505 SFB-30 - NDBi-030 - NDBi-030 17,150.0 17,529.0 1,919.0 1,349.1 4.221 CCB-31 - NDB-031 - NDB-031 50.0 49.6 179.2 170.1 38.128 ESB-31 - NDB-031 - NDB-031 250.0 249.1 179.4 170.1 34.411 SFB-31 - NDB-031 - NDB-031 700.0 674.1 207.4 196.4 31.567 CCB-32 - NDB-032 - NDB-032 1,170.4 1,165.8 183.4 169.9 21.435 ESB-32 - NDB-032 - NDB-032 1,175.0 1,170.0 183.4 169.9 21.394 SFB-32 - NDB-032 - NDB-032 11,550.0 12,381.0 1,110.5 851.2 5.392 CCB-33 - NDB-033 - Plan: NDB-033 Rev A.0 325.0 325.0 220.3 210.6 40.737 ESB-33 - NDB-033 - Plan: NDB-033 Rev A.0 475.0 474.6 220.4 210.3 38.237 SFB-33 - NDB-033 - Plan: NDB-033 Rev A.0 825.0 789.7 242.4 230.6 34.097 CCB-34 - NDBi-034 - Plan: NDBi-034 Rev M.0 325.0 324.8 239.5 229.2 40.289 ESB-34 - NDBi-034 - Plan: NDBi-034 Rev M.0 350.0 349.6 239.5 229.2 39.967 SFB-34 - NDBi-034 - Plan: NDBi-034 Rev M.0 7,675.0 6,973.8 2,580.7 2,342.6 13.684 CCB-35 - NDB-035 - NDB-035 Slot Saver 845.5 841.2 260.3 248.4 36.175 ESB-35 - NDB-035 - NDB-035 Slot Saver 875.0 869.8 260.3 248.3 35.393 SFB-35 - NDB-035 - NDB-035 Slot Saver 1,000.0 989.9 262.5 249.9 33.452 15/10/2025 10:28:34 COMPASS 5000.17 Build CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 3 Santos Ltd Anticollision Summary Report Well B-22 - Slot B-22Local Co-ordinate Reference:SantosCompany: DF @ 70.0usftTVD Reference:PikkaProject: DF @ 70.0usftMD Reference:NDBReference Site: TrueNorth Reference:0.9 usftSite Error: Minimum CurvatureSurvey Calculation Method:B-22Reference Well: Output errors are at 2.79 sigmaWell Error:0.5 usft Reference Wellbore NDB-022 Database:EDM Offset DatumReference Design:Plan NDB-022 Rev F.1 Offset TVD Reference: 0 650 1300 1950 2600 0 4000 8000 12000 16000 20000 24000 Measured Depth Ladder Plot B-09, NDB-09, Plan: NDB-09 Slot Saver V0 B-10, NDB-010, NDB-010 V0 B-10, NDB-010, Plan: NDB-010 Rev G.0 V0 B-11, NDB-011, NDB-011 V0 B-12, NDBi-012, Plan: NDBi-012 Slot Saver V0 B-13, NDB-013, Plan: NDBi-013 Slot Saver V0 B-14, NDBi-014, NDBi-014 V0 B-15, NDB-015, Plan: NDB-015 Rev A.0 V0 B-16, NDBi-016, NDBi-016 V0 B-17, NDB-017, NDB-017 Slot Saver V0 B-18, NDBi-018, NDBi-018 V0 B-19, NDBi-019, Plan: NDBi-019 Rev A.0 V0 B-20, NDBi-020, Plan: NDBi-020 Rev A.0 V0 B-21, NDB-021, Plan:NDB-021 Rev A.0 V0 B-23, NDB-023, NDB-023 Slot Saver V0 B-24, NDB-024, NDB-024 V0 B-24, NDB-024PB1, NDB-024PB1 V0 B-25, NDB-025, NDB-025 V0 B-26, NDBi-026, Plan: NDBi-026 Rev A.0 V0 B-27, NDB-027, NDB-027 V0 B-27, NDB-027 MWD, NDB-027 MWD V0 B-27, NDB-027 PB1, NDB-027 PB1 V0 B-28, NDBi-028, Plan NDBi-028 Rev A.0 V0 B-29, NDB-029, NDB-29 Slot Saver V0 B-30, NDBi-030, NDBi-030 V0 B-31, NDB-031, NDB-031 V0 B-32, NDB-032, NDB-032 V0 B-33, NDB-033, Plan: NDB-033 Rev A.0 V0 B-34, NDBi-034, Plan: NDBi-034 Rev M.0 V0 B-35, NDB-035, NDB-035 Slot Saver V0 L E G E N D Coordinates are relative to: B-22 - Slot B-22 Coordinate System is US State Plane 1983, Alaska Zone 4 Grid Convergence at Surface is: -0.60°Central Meridian is 150° 0' 0.000 W Offset Depths are relative to Offset Datum Reference Depths are relative to DF @ 70.0usft 15/10/2025 10:28:34 COMPASS 5000.17 Build CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 4 Santos Ltd Anticollision Summary Report Well B-22 - Slot B-22Local Co-ordinate Reference:SantosCompany: DF @ 70.0usftTVD Reference:PikkaProject: DF @ 70.0usftMD Reference:NDBReference Site: TrueNorth Reference:0.9 usftSite Error: Minimum CurvatureSurvey Calculation Method:B-22Reference Well: Output errors are at 2.79 sigmaWell Error:0.5 usft Reference Wellbore NDB-022 Database:EDM Offset DatumReference Design:Plan NDB-022 Rev F.1 Offset TVD Reference: 0.00 3.00 6.00 9.00 0 4500 9000 13500 18000 22500 Measured Depth Stop Drilling Caution - Monitor Closely Normal Operations Separation Factor Plot B-09, NDB-09, Plan: NDB-09 Slot Saver V0 B-10, NDB-010, NDB-010 V0 B-10, NDB-010, Plan: NDB-010 Rev G.0 V0 B-11, NDB-011, NDB-011 V0 B-12, NDBi-012, Plan: NDBi-012 Slot Saver V0 B-13, NDB-013, Plan: NDBi-013 Slot Saver V0 B-14, NDBi-014, NDBi-014 V0 B-15, NDB-015, Plan: NDB-015 Rev A.0 V0 B-16, NDBi-016, NDBi-016 V0 B-17, NDB-017, NDB-017 Slot Saver V0 B-18, NDBi-018, NDBi-018 V0 B-19, NDBi-019, Plan: NDBi-019 Rev A.0 V0 B-20, NDBi-020, Plan: NDBi-020 Rev A.0 V0 B-21, NDB-021, Plan:NDB-021 Rev A.0 V0 B-23, NDB-023, NDB-023 Slot Saver V0 B-24, NDB-024, NDB-024 V0 B-24, NDB-024PB1, NDB-024PB1 V0 B-25, NDB-025, NDB-025 V0 B-26, NDBi-026, Plan: NDBi-026 Rev A.0 V0 B-27, NDB-027, NDB-027 V0 B-27, NDB-027 MWD, NDB-027 MWD V0 B-27, NDB-027 PB1, NDB-027 PB1 V0 B-28, NDBi-028, Plan NDBi-028 Rev A.0 V0 B-29, NDB-029, NDB-29 Slot Saver V0 B-30, NDBi-030, NDBi-030 V0 B-31, NDB-031, NDB-031 V0 B-32, NDB-032, NDB-032 V0 B-33, NDB-033, Plan: NDB-033 Rev A.0 V0 B-34, NDBi-034, Plan: NDBi-034 Rev M.0 V0 B-35, NDB-035, NDB-035 Slot Saver V0 L E G E N D Coordinates are relative to: B-22 - Slot B-22 Coordinate System is US State Plane 1983, Alaska Zone 4 Grid Convergence at Surface is: -0.60°Central Meridian is 150° 0' 0.000 W Offset Depths are relative to Offset Datum Reference Depths are relative to DF @ 70.0usft 15/10/2025 10:28:34 COMPASS 5000.17 Build CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 5 Northing (5500 usft/in)Northing (5500 usft/in) 0 30 60 0 450 900 1350 1800 2250 Partial Measured Depth Equivalent Magnetic Distance Plan NDB-022 Rev F.1 Ladder View 0 150 300 0 3500 7000 10500 14000 17500 21000 24500 Measured Depth Equivalent Magnetic Distance SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 47.0 1000.0 Plan NDB-022 Rev F.1 (NDB-022) SDI_KPR_gyroMWD+SAG 1000.0 3065.0 Plan NDB-022 Rev F.1 (NDB-022) 3_MWD+IFR2+MS+Sag 3065.0 12000.0 Plan NDB-022 Rev F.1 (NDB-022) 3_MWD+IFR2+MS+Sag 12000.0 18073.0 Plan NDB-022 Rev F.1 (NDB-022) 3_MWD+IFR2+MS+Sag 18073.0 23946.2 Plan NDB-022 Rev F.1 (NDB-022) 3_MWD+IFR2+MS+Sag 10:12, October 15 2025 CASING DETAILS TVD MD Name 128.0 128.0 20" Conductor Driven 2385.5 3065.013-3/8" Surface Casing 3380.6 12000.09-5/8" Intermediate Liner 4062.8 18090.0 7" Intermediate Liner 4000.0 23946.2 4-1/2" x 6-1/8" Attachment 3: BOPE Equipment 21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000# 21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000# 13-5/8" X 5,000#13-5/8" X 5,000#30"13-5/8" X 5,000#186"13-5/8" X 5,000# Choke Linefrom BOPPressure Gauge1502 Pressure SensorPressure TransducerBill of MaterialItemDescriptionTo Panic LineItemDescriptionA 31/8 5,000psi W.P.Remote HydraulicOperated ChokeB 31/85,000 psi W.P.Adjustable ManualChoke1 14 31/8 5,000psi W.P.Manual Gate Valve1521/165 000 i WP1521/165,000psiW.P.Manual Gate ValveTo Mud GasLegendBlind SpareTo Tiger TankSeparatorValve Normally OpenValve Normally Closed Attachment 4: Drilling Hazards 16 Surface Hole Section Hazard Mitigations Conductor Broach Monitor conductor for any indications of broaching. Monitor pit volumes for any losses. Gas Hydrates Keep mud cool, optimize pump rates, minimize any excess circulation. Lost Returns Pump LCM as required (consult prepared lost returns decisions tree), slow pump rates, reduce ROP or trip speed when necessary. Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole if required. Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA, monitor torque and drag trends. Anti-Collision Closely monitor real-time surveys and run GWD in BHA 12-1/4 and 8-1/2 Intermediate Hole Sections Hazard Mitigations Lost Returns Optimal drillpipe sizing. MPD to be used to manage ECD loads (8- 1/2 hole only). Monitor ECD with MWD tools. Pump LCM as required, slow pump rates and RPM, reduce ROP or trip speed when necessary. ECD modelling for optimized cement jobs. Challenging liner runs The Intermediate liner runs requires relatively low OH friction factor to run to TD (hole cleaning and lubricants). Ability to rotate while RIH to overcome drag. Washouts/Hole Enlargement Drill with oil-based mud, maintain mud in specifications, use sufficient mud weight / back-pressure to hold back formations. Tight Hole/Stuck Pipe Hole cleaning and tripping practices, drilling jars included in BHA, monitor torque and drag trends, use sufficient mud weight / back- pressure to hold back formations. Hole Cleaning in 84° Sail Conduct T&D and hydraulics modeling, control ROP limits based on cuttings returns and comparison to the models. Pack Off During Cementing Proper wellbore cleanup procedure prior to running in hole. Stage circulation rates up while running in hole with liner. 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. Wireline Inaccessibility The sail angle on this section is too high for wireline to be run conventionally. If wireline logs are required for operations a tractor will be required. Operational complexity with Mechanical two stage cement equipment (9-5/8 Liner) The 2nd stage of the cement job will be conducted through a mechanically shifted sleeve. This will require the LTP to not be set until the 2nd stage is pumped giving a higher complexity leading to complications with setting the LTP. 6-1/8 Production Hole Section Hazard Mitigations Lost Returns Optimal drillpipe sizing. MPD to be used to control ECD loading. Monitor ECD with MWD tools. Pump LCM as required, slow pump rates and RPM, reduce ROP or trip speed when necessary. Well Control MPD utilized with 7.5-8.0ppg MW to provide adequate dynamic and static overbalance. Normal BOP well control procedures. Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole if required. 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. Wellbore Instability Maintain adequate mud weight / back-pressure for wellbore stability. Monitor cuttings returns, LWD logs, and drilling parameters for signs of washout. MPD to minimize pressure cycles on formation. Challenging liner run The production liner run requires relatively low OH friction factor to run to TD (hole cleaning and lubricants). Ability to rotate while RIH to overcome drag. * Note that no H2S has been encountered on nearby offset wells, and H2S is not anticipated in this well. Attachment 5A: Leak Off Test Procedure (Conventional) 1. Drill out shoe track, cement plus minimum of 20 of new formation. Circulate bottoms up and confirm cuttings are observed at surface. 2. Circulate and condition the mud: a. While circulating the hole clean of cuttings, circulate/ treat the mud to achieve desired mud properties. Consider pulling the bit into the casing shoe to prevent wash out. b. Accurately measure the mud weight with a recently calibrated pressurized mud balance; c. Confirm that mud weight-in is equal to mud weight-out; d. Do not change the mud weight until after the test. 3. Pull the bit back into the casing shoe. 4. Rig up high pressure lines as required to pump down the drill string. Pressure test lines to above expected test pressure. a. Record pressure at surface with calibrated chart recorder. 5. Break circulation down the string. 6. Verify the hole is filled up and close the BOP (annular or upper pipe ram). 7. Perform the LOT or FIT pumping at a constant rate of 0.50bbl/min (or as low as possible). Record pump pressures at 0.25bbl increments (~2 stokes). 8. Record and plot the volume pumped against pressure until leak-off is observed, or until the predetermined limit pressure/EMW has been reached for a FIT. a. Leak-off is defined as the first point on the volume/pressure plot where either the initial static pressure or the final static pressure deviates from the trend observed in the previous observations. b. If the pump pressure suddenly drops, stop pumping but keep the well closed in. This indicates a leak in the system, cement failure or formation breakdown. Record the pressures every minute until they stabilize. If the drop in pressure is related to formation breakdown, this data can be used to derive the minimum in-situ stress. c. If FIT skip step 9. 9. Once a leak off is observed pump an additional 0.75bbls to confirm the leak off. 10. Stop pumping, shut in and record pressures. Monitor shut-in pressure for 10 min. Record initial shut-in pressure 10 seconds after shutting in. Then record pressures at thirty second increments for the first five minutes and then every one minute for the remainder of the shut in period. 11. If the pressure does not stabilize, this may be an indication of a system leak or a poor cement bond. 12. Bleed off pressure (through annulus if a float is in the string) and record the volume returned to establish the volume of mud lost to the formation. Top up and close the annulus valve between the casing and the previous casing string. 13. Open the BOP. Attachment 5B: Leak Off Test Procedure (With MPD) 1. Drill out shoe track and cement. Install MPD Bearing Assembly and drill a minimum of 20 of new formation, holding required EMW using the MPD choke manifold. Circulate bottoms up and confirm cuttings are observed at surface. 2. Circulate and condition the mud: a. While circulating the hole clean of cuttings, circulate/ treat the mud to achieve desired mud properties. Consider pulling the bit into the casing shoe to prevent wash out. b. Accurately measure the mud weight with a recently calibrated pressurized mud balance; c. Confirm that mud weight-in is equal to mud weight-out; d. Do not change the mud weight until after the test. 3. Pull the bit back into the casing shoe, continuing to hold required EMW using the MPD choke. 4. Rig up high pressure lines as required to pump down the drill string. Pressure test lines to above expected test pressure. a. Record pressure at surface with calibrated chart recorder. 5. Break circulation down the string with the MPD chokes closed (i.e. well shut-in). 6. Starting at the MPD set-point pressure (back pressure needed for required baseline EMW), perform the LOT or FIT pumping at a constant rate of 0.50bbl/min (or as low as possible). Record pump pressures at 0.25bbl increments (~2 stokes). 7. Record and plot the volume pumped against pressure until leak-off is observed, or until the predetermined limit pressure/EMW has been reached for a FIT. a. Leak-off is defined as the first point on the volume/pressure plot where either the initial static pressure or the final static pressure deviates from the trend observed in the previous observations. b. If the pump pressure suddenly drops, stop pumping but keep the well closed in. This indicates a leak in the system, cement failure or formation breakdown. Record the pressures every minute until they stabilize. If the drop in pressure is related to formation breakdown, this data can be used to derive the minimum in-situ stress. c. If FIT skip step 9. 8. Once a leak off is observed pump an additional 0.75bbls to confirm the leak off. 9. Stop pumping, shut in and record pressures. Monitor shut-in pressure for 10 min. Record initial shut-in pressure 10 seconds after shutting in. Then record pressures at thirty second increments for the first five minutes and then every one minute for the remainder of the shut in period. 10. If the pressure does not stabilize, this may be an indication of a system leak or a poor cement bond. 11. Bleed off pressure (through MPD choke) down to the starting MPD set-point pressure and record the volume returned to establish the volume of mud lost to the formation. Attachment 6: Cement Summary Surface Casing Cement Casing Size 13-3/8 68# L-80 BTC/TXP-BTC Surface Casing Basis Lead Open hole volume + 150% excess in permafrost / 50% excess below permafrost Lead TOC Surface Tail Open hole volume + 50% excess + 65 ft shoe track Tail TOC 500 ft MD above casing shoe Total Cement Volume Spacer ~80 bbls of 10.5 ppg Tuned Spacer Lead 11.0ppg Lead: 387 bbls, 2172 cuft, 858 sks ArcticCem, Yield: 2.53 cuft/sk Tail 15.3ppg Tail: 66 bbls, 370 cuft, 298 sks HalCem Type I/II 1.24 cuft/sk Temp BHST ~60° F (2.25°/100 TVD below PermaFrost) Verification Method Cement returns to surface Notes Job will be mixed on the fly NDB-022 13-3/8" SURFACE CEMENT JOB Well Details Casing Stick Up on Rig Floor -4 ft MD 16.000 " Float Collar Depth 3000 ft MD 13.375 " Casing Shoe Depth 3065 ft MD 12.415 " TD Hole Depth 3065 ft MD 19.250 " Base Permafrost 1432 ft MD Previous Casing Shoe 128 ft MD Top of Previous Casing/Surface 46 ft MD Tail Cement Calculations Description Top Bottom Length OD ID Capacity Volume Excess Excess Volume Volume + Excess ft MD ft MD ft MD inches inches bbl/ft bbl % bbl bbl 13-3/8" Shoe Track 3000 3065 65 12.415 0.1497 9.7 0% 0 9.7 16" Open Hole x 13-3/8" Casing below base Permafrost 2565 3065 500 16.000 13.375 0.0749 37.5 50% 18.7 56.2 65.9 Lead Cement Calculations Description Top Bottom Length OD ID Capacity Volume Excess Excess Volume Volume + Excess ft MD ft MD ft MD inches inches bbl/ft bbl % bbl bbl 16" Open Hole x 13-3/8" Casing below base Permafrost 1432 2565 1133 16.000 13.375 0.0749 84.9 50% 42.4 127.3 16" Open Hole x 13-3/8" Casing above base Permafrost 128 1432 1304 16.000 13.375 0.0749 97.7 150% 146.5 244.2 Conductor x 13-3/8" Cased Hole 46 128 82 19.250 13.375 0.1862 15.3 0% 0.0 15.3 386.8 Displacement Calculations Description Top Bottom Length OD ID Capacity Volume Excess Excess Volume Volume + Excess ft MD ft MD ft MD inches inches bbl/ft bbl % bbl bbl 13-3/8 68# L-80 BTC/TXP-BTC Surface Casing to Float Colla -4 3000 3004 12.415 0.1497 449.8 449.8 449.8 Previous Casing ID Casing ID Casing OD Hole Size Verified cement calcs. -bjm Intermediate #1 Liner Cement Casing Size 9-5/8 47# L-80 Hydril 563 Intermediate Liner #1 Basis Tail Open hole volume + excess + 85 ft shoe track Tail TOC Stage 1: 1000 MD above the shoe Stage 2: Top of the 9-5/8 Liner Total Cement Volume Spacer ~80 bbls of 12.5 ppg Clean Spacer Tail Stage 1: 30% Open Hole Excess 15.3ppg Tail: 79 bbls, 442cuft, 357sks VersaCem Type I/II 1.24 cuft/sk Stage 2: 100% Open Hole Excess 15.3ppg Tail: 394 bbls, 2214cuft, 1785sks VersaCem Type I/II 1.24 cuft/sk Temp Stage 1 - BHST ~80° F (2.25°/100 TVD below PermaFrost) Stage 2 - BHST ~71° F (2.25°/100 TVD below PermaFrost) Notes Job will be mixed on the fly Verification Method - 1st Stage Cement Job will not be logged, assuming job parameters are as expected (no losses, good lift pressures, FIT / LOT results). - 2nd Stage Cement Job will not be logged, assuming job parameters are as expected (no losses, good lift pressures, circulate cement off top of liner). Justification: - 1st stage is only designed to provide adequate cement integrity around the shoe (i.e. Nanushuk will be isolated with 7 shoe) - Stage tool allows for precise placement of base cement column at base Tuluvak hydrocarbon. - Bond log not required for 2nd Stage per Regulation 20 AAC 25.030(d)(5) - 2nd Stage bond evaluation does not affect 1st Stage bond evaluation and frac decision. - 2nd Stage cement job will isolate Tuluvak with cement and a V0-rated LTP above it as a redundant means of isolation. - Well design allows for the OA annulus to be freeze protected by circulating in place (with Tieback) vs. bullheaded into place. With a sufficient initial LOT/FIT at the surface casing shoe, any potential Tuluvak pressures will be contained by the surface casing shoe and not cross flow into shallower formations. - Tuluvak isolation has been achieved on all historical Pikka development wells. - Seeking to simplify an already complicated operation, saving time/money. NDB-022 9-5/8" Intermediate #1 Liner - Stage 1 Cement Job Well Details Stick Up on Rig Floor -4 ft MD 12.250 " HWDP Length 2100 ft MD Top of Liner 2915 ft MD 9.625 " DP Length 819 ft MD Cflex Depth 6519 ft MD 8.681 " HWDP Capacity 0.0155 bbl/ft Landing Collar Depth N/A ft MD 12.415 " DP Capacity 0.0241 bbl/ft Float Collar Depth 11915 ft MD Casing Shoe Depth 12000 ft MD TD Hole Depth 12000 ft MD Previous Casing Shoe 3065 ft MD Tail Cement Calculations Description Top Bottom Length OD ID Capacity Volume Excess Excess Volume Volume + Excess ft MD ft MD ft MD inches inches bbl/ft bbl % bbl bbl 9-5/8" Shoe Track 11915 12000 85 8.681 0.0732 6.2 0% 0 6.2 12-1/4" Open Hole x 9-5/8" Casing 11000 12000 1000 12.250 9.625 0.0558 55.8 30% 16.7 72.5 78.7 Lead Cement Calculations Description Top Bottom Length OD ID Capacity Volume Excess Excess Volume Volume + Excess ft MD ft MD ft MD inches inches bbl/ft bbl % bbl bbl 0.0 Displacement Calculations Description Top Bottom Length OD ID Capacity Volume Excess Excess Volume Volume + Excess ft MD ft MD ft MD inches inches bbl/ft bbl % bbl bbl 5-7/8" 23.4# S135 Delta576 DP -4 815 819 0.0241 19.7 19.7 5-7/8" x 4" 130ksi Delta576 HWDP 815 2915 2100 0.0155 32.6 32.6 Liner Running Tools 2915 2960 45 2.5 0.0061 0.3 0.3 9-5/8 47# L-80 Hydril 563 Casing to Float/Landing Collar 2960 11915 8955 8.681 0.0732 655.6 655.6 708.1 Hole Size Casing OD Casing ID Previous Casing ID NDB-022 9-5/8" Intermediate #1 Liner - Stage 2 Cement Job Well Details Stick Up on Rig Floor -4 ft MD 12.250 " HWDP Length 2100 ft MD Top of Liner 2915 ft MD 9.625 " DP Length 819 ft MD Cflex Depth 6519 ft MD 8.681 " HWDP Capacity 0.0155 bbl/ft Landing Collar Depth N/A ft MD 12.415 " DP Capacity 0.0241 bbl/ft Float Collar Depth 11915 ft MD Casing Shoe Depth 12000 ft MD TD Hole Depth 12000 ft MD Previous Casing Shoe 3065 ft MD Tail Cement Calculations Description Top Bottom Length OD ID Capacity Volume Excess Excess Volume Volume + Excess ft MD ft MD ft MD inches inches bbl/ft bbl % bbl bbl 12-1/4" Open Hole x 9-5/8" Casing 3065 6519 3454 12.250 9.625 0.0558 192.7 100% 192.7 385.3 13-3/8" Cased Hole x 9-5/8" Casing 2915 3065 150 12.415 9.625 0.0597 9.0 0% 0.0 9.0 394.3 Lead Cement Calculations Description Top Bottom Length OD ID Capacity Volume Excess Excess Volume Volume + Excess ft MD ft MD ft MD inches inches bbl/ft bbl % bbl bbl 0.0 Displacement Calculations Description Top Bottom Length OD ID Capacity Volume Excess Excess Volume Volume + Excess ft MD ft MD ft MD inches inches bbl/ft bbl % bbl bbl 5-7/8" 23.4# S135 Delta576 DP -4 815 819 0.0241 19.7 19.7 5-7/8" x 4" 130ksi Delta576 HWDP 815 2915 2100 0.0155 32.6 32.6 5-7/8" 23.4# S135 Delta576 DP 2915 6519 3604 0.0241 86.9 86.9 139.1 Hole Size Casing OD Casing ID Previous Casing ID Verified cement calcs. -bjm Intermediate #2 Liner Cement Casing Size 7 26# L-80 Hydril 563 Intermediate Liner #2 Basis Lead No Lead planned Lead TOC No Lead Planned Tail Open hole volume + 30% excess + 125 ft shoe track Tail TOC 200 TVD above the top Nanushuk Total Cement Volume Spacer ~80 bbls of 12.5 ppg Clean Spacer Lead No Lead Planned Tail 15.3ppg Tail: 268 bbls, 1502cuft, 1214sks VersaCem Type I/II 1.24 cuft/sk Temp BHST ~99° F (2.25°/100 TVD below PermaFrost) Notes Job will be mixed on the fly Verification Method - LWD Sonic will be used to log the cement job. Justification: - Future hydraulic fracture operations will only be done in the Nanushuk formation. Log verification of the cement job will verify proper isolation has been achieved for frac operations. NDB-022 7" Intermediate #2 Liner Cement Job Well Details Stick Up on Rig Floor -4 ft MD 9.875 " HWDP Length 1000 ft MD Top of Liner 11850 ft MD 7.000 " DP Length 10854 ft MD Landing Collar Depth 17965 ft MD 6.276 " HWDP Capacity 0.0087 bbl/ft Float Collar Depth n/a ft MD 8.681 " DP Capacity 0.0177 bbl/ft Casing Shoe Depth 18090 ft MD TD Hole Depth 18090 ft MD Previous Casing Shoe 12000 ft MD Tail Cement Calculations Description Top Bottom Length OD ID Capacity Volume Excess Excess Volume Volume + Excess ft MD ft MD ft MD inches inches bbl/ft bbl % bbl bbl 9-5/8" Shoe Track 17965 18090 125 6.276 0.0383 4.8 0% 0 4.8 12-1/4" Open Hole x 9-5/8" Casing 13800 18090 4290 9.875 7.000 0.0471 202.2 30% 60.7 262.8 267.6 Lead Cement Calculations Description Top Bottom Length OD ID Capacity Volume Excess Excess Volume Volume + Excess ft MD ft MD ft MD inches inches bbl/ft bbl % bbl bbl 0.0 Displacement Calculations Description Top Bottom Length OD ID Capacity Volume Excess Excess Volume Volume + Excess ft MD ft MD ft MD inches inches bbl/ft bbl % bbl bbl 5" 19.5# S135 Delta544 DP -4 10850 10854 0.0177 192.1 192.1 5" x 3" Delta544 HWDP 10850 11850 1000 0.0087 8.7 8.7 Liner Running Tools 11850 11895 45 2.5 0.0061 0.3 0.3 9-5/8 47# L-80 Hydril 563 Casing to Float/Landing Collar 11895 17965 6070 6.276 0.0383 232.3 232.3 433.3 Hole Size Casing OD Casing ID Previous Casing ID Verified cement calcs. -bjm Attachment 7: Prognosed Formation Tops NDB-022 Prognosed Tops Formation MD (ft) TVD KB (ft) TVDss (ft) Pore Pressure (ppg) Upper Schrader Bluff 1061 1048 978 7.2 Base Permafrost Transition 1432 1394 1324 7.3 Middle Schrader Bluff 1849 1744 1674 7.6 MCU 2439 2136 2066 7.8 Tuluvak Shale 3228 2433 2363 7.9 Tuluvak Sand 3646 2499 2429 10.2 TS_790 6469 2797 2727 9.4 Seabee 9899 3159 3089 9.2 Nanushuk 15687 3770 3700 9.0 NT8 MFS 16189 3823 3753 8.9 NT7 MFS 16540 3860 3790 8.9 NT6 MFS 17004 3909 3839 8.9 NT5 MFS 17250 3935 3865 8.9 NT4 MFS 17629 3975 3905 8.9 NT3 MFS 18018 4043 3973 8.8 NT3.2 Top Reservoir 18197 4093 4023 8.8 Fault 22953 4105 4035 8.8 NT3.2 Top Reservoir 23250 4093 4023 8.8 NT3 MFS 23769 4043 3973 8.8 Attachment 8: Well Schematic Attachment 9: Formation Evaluation Program 16 Surface Hole LWD Gamma Ray Resistivity 12-1/4 Intermediate Hole #1 LWD Gamma Ray Resistivity 8-1/2 Production Hole LWD Gamma Ray Resistivity Density Neutron Sonic (7 Liner Cement Evaluation Only) Mudlogging No mudlogging is planned for NDB-022 Attachment 10: Wellhead & Tree Diagram Attachment 11: Diverter Variance Request NDB Surface Hole Map View Attachment 12: Oil Search Alaska 21-day BOPE Test Schedule Waiver Approval Letter Attachment 13: Managed Pressure Drilling Managed Pressure Drilling (MPD) will be implemented on NDB-022 in both the Intermediate #2 and Production sections of the well. The MPD system will be provided by Beyond Energy Services and Technology with an integrated piping and choke manifold on the Nabors 272 rig. The only MPD equipment located outside of the rig will be the nitrogen rack. The plan in the 8-1/2 x 9-7/8 Intermediate hole will be to drill with a reduced 9.5 - 11.0ppg mud weight and utilize MPD to trap back-pressure in order to manage ECD for losses as well as providing adequate pressures to maintain wellbore stability through the Seabee and Nanushuk formations. Weighted trip fluids will be utilized to maintain downhole pressures for the final trip out and running of the 7 liner without MPD. The plan in the 6-1/8 Production hole will be to drill with a reduced 7.5 8.0ppg mud weight with MPD utilized to trap back-pressure in order to maintain adequate overbalance for pore pressure and wellbore stability and manage ECD for losses through the Nanushuk formations. Weighted trip fluids will be utilized to maintain downhole pressures for the final trip out and running of the 4-1/2 liner without MPD. The production hole will remain statically and dynamically overbalanced at all times using MPD. See below for a schematic of the BOP/MPD stack with the choke flow diagram. Attachment 14: As Staked Survey NDB Well 22 Conductor Final 1 McLellan, Bryan J (OGC) From:Staudinger, Garret (Garret) <Garret.Staudinger@santos.com> Sent:Monday, November 24, 2025 1:41 PM To:McLellan, Bryan J (OGC) Cc:Conwell, Russell (Russell) Subject:RE: NDB-022 PTD Hey Bryan, We plan to use lithological separa on as the primary means of addressing the collision risk between NDB-022 and NDB- 024. The close approach interval occurs near TD of the NDB-022 intermediate 2 hole sec on in which we are s ll in the upper Nanushuk forma ons (above the NT3.2 top reservoir). The collision risk is to the toe of NDB-024 which is located in the NT3.2 reservoir (NDB-024 will also be shut in while drilling NDB-022). We plan to set the NDB-022 intermediate 2 liner above the top of the NT3.2. The an -collision close approach clears up and will not be an issue while drilling produc on hole of NDB-022. Hope this helps and let me know if you need anything else. Regards, Garret Staudinger ERD Team Lead m: +1 (907) 440-6892 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, November 24, 2025 1:17 PM To: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com> Cc: Conwell, Russell (Russell) <Russell.Conwell@santos.com> Subject: ![EXT]: FW: NDB-022 PTD Garret, Can you address the question below in Russels absence. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 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 From: McLellan, Bryan J (OGC) Sent: Monday, November 24, 2025 12:59 PM To: Conwell, Russell (Russell) <russell.conwell@santos.com> Subject: NDB-022 PTD Russell, The Anti-collision scan in the PTD shows a Close approach with well NDB-024. How will Oil Search address this collision risk? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 Santos Ltd A.B.N. 80 007 550 923 Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment before printing this email Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: __________________________ POOL: ____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. PIKKA 225-114 PIKKA NDB-022 NANUSHUK OIL WELL PERMIT CHECKLISTCompanyOil Search (Alaska), LLCWell Name: PIKKA NDB-022Initial Class/TypeDEV / PENDGeoArea890Unit11580On/Off ShoreOnProgram DEVWell bore segAnnular DisposalPTD#:2251140Field & Pool:PIKKA, NANUSHUK OIL - 600100NA1 Permit fee attachedYes ADL392984; ADL393016; ADL393020; ADL391455; ADL393018; ADL393010; ADL3929682 Lease number appropriateYes3 Unique well name and numberYes PIKKA, NANUSHUK OIL - 600100 - governed by CO 8074 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryNA6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes Variance for cement gap between 2-stage cement job Intermediate 1.21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes Close approach risk with NDB-024 at 18025' MD. Well NDB-024 to be shut in while drilling the int 2 hole.26 Adequate wellbore separation proposedYes27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP = 1456 psi, BOP rated to 5000 psi, (BOP test to 3600 psi)30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)Yes H2S measures not required. None anticipated based on nearby wells.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected pressure range is 0.374 to 0.53 psi/ft (7.2 to 10.2 ppg EMW). Tuluvak over-pressure expected.36 Data presented on potential overpressure zonesNA MPD planned for Int #2 & production sections.37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprTCSDate11/3/2025ApprBJMDate11/24/2025ApprTCSDate11/3/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 11/24/2025