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Home My WebLink About225-024 Hunter Van Wyhe Furie Operating Alaska, LLC Operations Engineer 433 W 9 th Avenue, Anchorage, AK 99501 907.277.3726 Email: h.vanwyhe@furiealaska.com Furie Operating Alaska, LLC | 433 W 9 th Avenue, Anchorage, AK 99501 | 907.277.3726 Date: October 2nd, 2025 To: Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: KLU A-6 PTD: 225-024 API: 50-733-20735-00-00 Alaska E-Line Logs x KLU A-6_pprof_17-Sep-2025_(5658)_Fieldprint (.las/pdf) x KLU A-6_Perf_8-Sep-2025_(5645)_Fieldprint (.las/.pdf) Data transmitted as .zip file via ZendTo shared with: aogcc.data@alaska.gov Meredith Guhl meredith.guhl@alaska.gov Gavin Gluyas gavin.gluyas@alaska.gov Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: 225-024 T40936 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.03 08:34:18 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?KLU A-6 Yes No 9. Property Designation (Lease Number): 10. Field: Kitchen Lights Unit Beluga Undefined Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,131'N/A Casing Collapse Structural Conductor 2,520 psi Surface 2,260 psi Intermediate 4,760 psi Production Liner 10,530 psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): See attached schematic. Baker S-5 BXCE SCSSV 5K psi working pressure. See attached schematic 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Hunter Van Wyhe Hunter Van Wyhe Contact Email: Contact Phone:(907) 378-3354 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng September 3rd, 2025 9,105'3,839' 3-1/2" 8,060' Perforation Depth MD (ft): L-80 20" 13-3/8" 351' 9-5/8" 2,954' 5,443' 3-1/2" See attached schematic MD 6,870 psi5,443' 2,954' 351' 2,923' 4,800' 351' Proposed Pools: 8,060' 8,036' 2,454 psi MPSP (psi): TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 389197 225-024Furie Operating Alaska, LLC Will perfs require a spacing exception due to property boundaries? Current Pools: Kitchen Lights Unit AOGCC USE ONLY 10,160 psi Perforation Depth TVD (ft): See attached schematic Operations Engineer Subsequent Form Required: Suspension Expiration Date: 433 W. 9th Avenue, Anchorage, AK 99502 50-733-20735-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY 9,105'N/A 4,240 psi 5,020 psi Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Grade: Tubing MD (ft): h.vanwyhe@furiealaska.com Length Size 5,266' MD m n P 2 6 5 6 t _ c N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 08/21/2025 325-508 By Grace Christianson at 12:29 pm, Aug 22, 2025 BJM 9/3/25 Perforate SFD 8/27/2025 DSR-8/26/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.04 08:18:25 -08'00'09/04/25 RBDMS JSB 090425 August 21st, 2025 Bryan McLellan Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Furie Operating Alaska KLU A-6 (PTD 225-024) 10-403 Add Beluga Perforations Mr. McLellan, Enclosed is a 10-403 for adding Beluga perforations to the KLU A-6 well with attached the Wellbore Schematic, Summarized Operations Plan, and table of Proposed Perforations. Operations are expected to commence approximately September 3rd, 2025. If you have questions, please feel free to contact me at 907-378-3354. Hunter Van Wyhe Operations Engineer Furie Operating Alaska, LLC Current Wellbore Schematic See perforation table attached for perforation intervals Perforation Table KLU A-6 MPSP Calculation: Interval: 7,257’-7,265’ MD (6,372’-6,379’ TVD) Estimated Reservoir Pressure at Top Perf: 2,804 psi Gas Gradient (Based on KLU 3 Static Gradient Survey): 0.055 psi/ft MPSP = (2,804 psi – (0.055 * 6,372’ TVD) = 2,454 psi KLU A-6 Perforation Procedure Summary 1. Rig up Eline for perforating operations. Pressure test PCE to 250 psi low and 3,000 psi high. a. (Note: PCE must be tested each time it is broken apart.) 2. RIH and perforate Beluga intervals. 3. RD Eline equipment. Turn well over to production. Well Formation MD Top (ft) MD Base (ft) MD Thickness (ft) TVD Top (ft) TVD Bottom (ft) KLU A-6 Beluga 5598 5610 12 4909.5 4918.5 KLU A-6 Beluga 5634 5663 29 4936 4958 KLU A-6 Beluga 5751 5760 9 5028 5035.5 KLU A-6 Beluga 6009 6024 15 5248 5262.5 KLU A-6 Beluga 6121 6137 16 5350 5364.5 KLU A-6 Beluga 6181 6201 20 5404 5422.5 KLU A-6 Beluga 7257 7265 8 6372 6379 Total 109 Gas Gradient (Based on KLU 3 Static Gradient Survey): 0.055 psi/ft 1 From:Dan Robertson <d.robertson@furiealaska.com> Sent:Wednesday, September 3, 2025 4:18 PM To:McLellan, Bryan J (OGC) Cc:Hunter Van Wyhe; Trey Kendrick Subject:Re: [EXT] Fwd: KLU A-6 (PTD 225-024) perf sundry Bryan, The reservoir pressure history for KLU A-6 is a bit unusual. A static pressure survey was performed immediately after the deepest perf interval was shot. A flowing production log a couple of weeks later with multiple zones open indicated a higher flowing bottomhole pressure than the original measured static pressure. More details below. On 7/10/25 the deepest interval in well KLU A-6 was perforated, 8483-8503 MDBKB (referenced to 7/6/25 Ak Eline CBL) . A electric line deployed pressure survey (image below) was performed immediately after perforating the first interval on 7/10/25. This pressure survey indicated 3302 psi, 128 F at 8300 MDBKB, 7309 TVDBKB, or 0.45 psi/ft, 8.7 ppg EMW. Perforating continued after the pressure survey with another 6 perf intervals added for a total of 7 perforation intervals. A flowing production log was performed 7/25/25. This log indicated 3656 psi, 120 F, at 8300 MDBKB, 7309 TVDBKB or 0.5 psi/ft, 9.6 ppg EMW. It is uncertain why the measured flowing bottomhole pressure was higher than the previously measured reservoir pressure. One explanation is that the deepest perf interval in the well was not the highest-pressure interval i.e. one or more other perf intervals added later were at a higher pressure. A 2-day pressure build up was conducted 8/9-11/25. The shut-in wellhead pressure at the end up the pressure build up time period was 2380 psi. Assuming gas to the top perforation at 7653 MDBKB, 6725 TVDBKB, the estimated reservoir pressure at the top perforation was 2750 psi (= 2380 psi SITP + (0.055 psi/ft * 6725 TVDBKB)). Estimated gradient of 0.41 psi/ ft (=2750 psi/ 6725 TVDBKB), 7.9 ppg EMW. Let me know if any additional information is needed. Thanks, Dan 7/10/25 KLU A-5 Static pressure survey after first interval perforated (8483-8503 MDBKB): 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 3 KLU A-6 7/25/25 Flowing Production Log with 7 intervals perforated: Well KLU A-6 Scada wellhead pressure data indicating 2379 psi shut in wellhead pressure 8/11/2025: 4 5 From: Dan Robertson <dbrobertson907@gmail.com> Sent: Friday, August 29, 2025 2:03 PM To: Dan Robertson <d.robertson@furiealaska.com> Subject: [EXT] Fwd: KLU A-6 (PTD 225-024) perf sundry ---------- Forwarded message --------- From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Date: Fri, Aug 29, 2025 at 13:25 Subject: KLU A-6 (PTD 225-024) perf sundry To: Dan Robertson <dbrobertson907@gmail.com>, Hunter Van Wyhe <h.vanwyhe@furiealaska.com> Dan, Same issue as for the other wells with requested perfs being above shallowest available. In this case Furie will only be able to add the deepest 3 sets of perfs requested in the sundry, nothing above ~5350’ TVD. Will need to plug off deepest perfs or prove they are depleted before adding perfs above this depth. Regards 6 Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 7 ***External Email*** Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. Hunter Van Wyhe Furie Operating Alaska, LLC Operations Engineer 433 W 9 th Avenue, Anchorage, AK 99501 907.277.3726 Email: h.vanwyhe@furiealaska.com Furie Operating Alaska, LLC | 433 W 9 th Avenue, Anchorage, AK 99501 | 907.277.3726 Date: August 13th, 2025 To: Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: KLU A-6 PTD: 225-024 API: 50-733-20735-00-00 Alaska E-Line CBL Data transmitted as .zip file via ZendTo shared with: aogcc.data@alaska.gov Meredith Guhl meredith.guhl@alaska.gov Gavin Gluyas gavin.gluyas@alaska.gov Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: 225-024 T40769 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.13 15:04:50 -08'00' Hunter Van Wyhe Furie Operating Alaska, LLC Operations Engineer 433 W 9 th Avenue, Anchorage, AK 99501 907.277.3726 Email: h.vanwyhe@furiealaska.com Furie Operating Alaska, LLC | 433 W 9 th Avenue, Anchorage, AK 99501 | 907.277.3726 Date: August 12th, 2025 To: Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: KLU A-6 PTD: 225-024 API: 50-733-20735-00-00 Alaska E-Line Perforating Logs – Initial Beluga Perforations x Gun 1 Correlation Pass (.pdf/.las) x Gun 2 Correlation Pass (.pdf/.las) x Gun 3 Correlation Pass (.pdf/.las) x Gun 4 Correlation Pass (.pdf/.las) x Gun 5 Correlation Pass (.pdf/.las) x Gun 6 Correlation Pass (.pdf/.las) Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: 225-024 T40765 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.12 09:23:37 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20270707 1444 APPROVAL to perf KLU A-6 (PTD (225-024) CBL Date:Monday, July 7, 2025 2:44:59 PM Attachments:image001.png image002.png From: Rixse, Melvin G (OGC) Sent: Monday, July 7, 2025 2:19 PM To: Michael Duncan <m.duncan@furiealaska.com> Cc: Hunter Van Wyhe <h.vanwyhe@furiealaska.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: KLU A-6 (PTD (225-024) CBL Michael, Furie is approved to perforate as per approved sundry 325-377. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Michael Duncan <m.duncan@furiealaska.com> Sent: Monday, July 7, 2025 12:01 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Hunter Van Wyhe <h.vanwyhe@furiealaska.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: KLU A-6 (PTD (225-024) CBL Mel - Please see the attached CBL for the KLU A-6. There is a snip from the interval with the liner hanger/packer and just below. Its easy to see good cement from about 5450 and below. I believe there some damping/cement above that and up to the packer at 5,325. Either way, there is good isolation of the zone and covers the span of perforations (listed in the table below. Please note, there are also perforations approved between 8,345 and 8,355 MD). We seek your permission to proceed with perforations. Thank you, Michael Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. Hunter Van Wyhe Furie Operating Alaska, LLC Operations Engineer 433 W 9 th Avenue, Anchorage, AK 99501 907.277.3726 Email: h.vanwyhe@furiealaska.com Furie Operating Alaska, LLC | 433 W 9 th Avenue, Anchorage, AK 99501 | 907.277.3726 Date: June 26th, 2025 To: Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: KLU A-6 PTD: 225-024 API: 50-733-20735-00-00 Geolog Final Data CD Halliburton LWD Final Data CD 1. CGM 2. Definitive Survey 3. EMF 225-024 T40624 Hunter Van Wyhe Furie Operating Alaska, LLC Operations Engineer 433 W 9 th Avenue, Anchorage, AK 99501 907.277.3726 Email: h.vanwyhe@furiealaska.com Furie Operating Alaska, LLC | 433 W 9 th Avenue, Anchorage, AK 99501 | 907.277.3726 4. LWD Data 5. PDF 6. TIFF Folder Structure: Data transmitted as .zip file via ZendTo shared with: aogcc.data@alaska.gov Meredith Guhl meredith.guhl@alaska.gov Gavin Gluyas gavin.gluyas@alaska.gov Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date:Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.26 14:14:26 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Hunter Van Wyhe Subject:RE: KLU A-6 (PTD 225-024) 10-403 Sundry Initial Beluga Perforations 06.20.25 Date:Wednesday, June 25, 2025 3:11:00 PM Attachments:image002.png Hunter, Additional perf interval is approved. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Hunter Van Wyhe <h.vanwyhe@furiealaska.com> Sent: Friday, June 20, 2025 4:11 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Re: KLU A-6 (PTD 225-024) 10-403 Sundry Initial Beluga Perforations 06.20.25 Bryan, Could we please add the interval from 8345 ft MD to 8355 ft MD (7349-7357 ft TVD) in KLU A-6 to the perforating Sundry submittal? Let me know if you have any questions or need additional information. Thank you, Hunter Van Wyhe Operations Engineer signature_1720928910 433 W. 9th Avenue Anchorage AK 99501 Cell: (907) 378-3354 From: Hunter Van Wyhe Sent: Friday, June 20, 2025 1:30 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Subject: KLU A-6 (PTD 225-024) 10-403 Sundry Initial Beluga Perforations 06.20.25 Good afternoon, Attached is a 10-403 for adding initial Beluga perforations to the KLU A-6 well with attached the Wellbore Schematic, Summarized Operations Plan, and table of Proposed Perforations. The KLU A-6 well was recently drilled and is awaiting perforating operations. Furie Operating Alaska, LLC plans to move a Eline unit onto the Julius R Platform once the Spartan 151 rig leaves location. A CBL will be run and recorded. Selected Beluga intervals will then be perforated. The well will then be placed on production. Operations are expected to commence approximately June 28th, 2025. If you have questions, please feel free to contact me at 907-378-3354. Thank you, Hunter Van Wyhe Operations Engineer signature_1720928910 433 W. 9th Avenue Anchorage AK 99501 Cell: (907) 378-3354 Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?KLU A-6 Yes No 9. Property Designation (Lease Number): 10. Field: Kitchen Lights Unit Beluga Undefined Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,131'N/A Casing Collapse Structural Conductor 2,520 psi Surface 2,260 psi Intermediate 4,760 psi Production Liner 10,530 psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): See attached schematic. Baker S-5 BXCE SCSSV 5K psi working pressure. See attached schematic 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Hunter Van Wyhe Hunter Van Wyhe Contact Email: Contact Phone:(907) 378-3354 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Grade: Tubing MD (ft): h.vanwyhe@furiealaska.com Length Size 5,266' MD Suspension Expiration Date: 433 W. 9th Avenue, Anchorage, AK 99502 50-733-20735-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY 9,105'N/A 4,240 psi 5,020 psi Plugs (MD): AOGCC USE ONLY 10,160 psi Perforation Depth TVD (ft): See attached schematic Operations Engineer Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 389197 225-024Furie Operating Alaska, LLC Will perfs require a spacing exception due to property boundaries? Current Pools: Kitchen Lights Unit Proposed Pools: 8,060' 8,036' 3,464 psi MPSP (psi): TVD BurstMD 6,870 psi5,443' 2,954' 351' 2,923' 4,800' 351' 2,954' 5,443' 3-1/2" See attached schematic 20" 13-3/8" 351' 9-5/8" June 28th, 2025 9,105'3,839' 3-1/2" 8,060' Perforation Depth MD (ft): L-80 m n P 2 6 5 6 t _ c N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:54 am, Jun 23, 2025 325-377 Submit CBL to AOGCC and obtain approval before perforating. A.Dewhurst 23JUN25 DSR-6/23/25BJM 6/23/25 10-407 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.25 11:18:30 -08'00'06/25/25 RBDMS JSB 062625 June ϮϬth, 2025 Bryan McLellan Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Furie Operating Alaska KLU A-6 (PTD 225-024) 10-403 Initial Beluga Perforations Mr. McLellan, Enclosed is the 10-403 for adding initial Beluga per forations to the KLU A-6 well with attached the Wellbore Schematic, Summarized Operations Plan, and table of Proposed Perforations. The KLU A-6 well was recently drilled and is awaiting perforating operations. Furie Operating Alaska, LLC plans to move a Eline unit onto the Julius R Platform once the Spartan 151 rig leaves location. A CBL will be run and recorded. Selected Beluga intervals will then be perforated. The well will then be placed on production. Operations are expected to commence approximately June 28 th, 2025. If you have questions, please feel free to contact me at 907-378-3354. Hunter Van Wyhe Operations Engineer Furie Operating Alaska, LLC Current Wellbore Schematic Unit: Kitchen Lights Unit Well Number: KLU A-6 Self-Closing SCSSV Baker - Set at 435' MD/TVD Ser: 108301893SN04 5K psi working pressure. Opening pressure at SCSSV=1,800 psi + SITP Gas Lift Mandrels 6 1,243' MD 1,236' TVD CIM 1,583' MD 1,572' TVD 5 1,993' MD 1,977' TVD 4 2,646' MD 2,621' TVD 3 3,320' MD 3,277' TVD 2 4,155' MD 3,950' TVD Depth MD: 1 5,116' MD 4,591' TVD Depth TVD: X Nipple at 5,256' MD / 4,680' MD Liner Top Packer at 5,266' MD / 4,687' TVD Intermediate Hole: termediate Casing: Depth MD: Depth TVD: ` Surface Casing: 13 3/8", 68lb/ft L-80 BTC 2,954' Conductor: 20" x .8125" Depth: 351' RKB Surface Hole: 16" 12.25" 9 5/8", 47 lb/ft, L-80 BTC 5,443' 4,800' KLU A-6 Wellbore Schematic TD: 9,131' MD / 8,060' TVD Date: 6/18/2025 Depth MD: 9,105' Depth TVD: 8,036' Production Hole: 8.5" Production Casing: 3.5", 9.2 lb/ft, L-80 JFE Lion 2,923' See perforation table attached for perforation intervals Perforation Table KLU A-6 MPSP Calculation: Interval: 8,458’-8,478’ MD (7,447’-7,464’ TVD) Estimated Reservoir Pressure at Top Perf: 3,873 psi Gas Gradient (Based on KLU 3 Static Gradient Survey): 0.055 psi/ft MPSP = (3,873 psi – (0.055 * 7,447’ TVD) = 3,464 psi KLU A-6 Perforation Procedure Summary 1. Rig up Eline for CBL. Pressure test PCE to 250 psi low and 2,500 psi high. a. (Note: PCE must be tested each time it is broken apart.) 2. Perform CBL (approved under 10-401 Sundry 225-024). 3. Rig up Eline for perforating operations. Pressure test PCE to 250 psi low and 4,000 psi high. a. (Note: PCE must be tested each time it is broken apart.) 4. RIH and perforate Beluga intervals. 5. RD Eline equipment. Turn well over to production. Formation MD Top (ft) MD Base (ft) MD Thickness (ft) TVD Top (ft) TVD Bottom (ft) TVD Thickness (ft) Beluga 7,635 7,650 15 6,711 6,725 14 Beluga 7,789 7,805 16 6,849 6,864 15 Beluga 7,865 7,878 13 6,918 6,928 10.5 Beluga 7,975 7,982 7 7,016 7,021 5 Beluga 8,278 8,294 16 7,287 7,300 13.5 Beluga 8,458 8,478 20 7,447 7,464 17.5 Total: 87 �? FR R IAELLC Date: June 12th, 2025 aaS- 02� Hunter Van Wyhe Furie Operating Alaska, LLC 1 3 Operations Engineer 433 W 91h Avenue, Anchorage, AK 99501 907.277.3726 Email: h.vanwyhe@furiealaska.com To: Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: KLU A-6 PTD:225-024 API: 50-733-20735-00-00 RECEIVED JUN 12 2025 AOGCC Geolog Mud Logging: Washed and Dried Cuttings Set 1 Shipping box containing 7 boxes of samples (1 complete set) Data delivered to: Alaska Oil and Gas Conservation Commission (AOGCC) C/O Meredith Guhl 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Geological Sample Manifest/Inventory Operator: Frtde Opeming Abska, LL[ Dina: AIM 11ig25 Well Nam: KLU A-6 PmPued OV: lab 328 CooAmerkm Ise bg API: SP73}i0735-0D00 907-Ml-240 All Off" Laation: Cook Inlet Pbtform Julius R Refeis2d BY: Zap Fallon Set Owner Shipping gdx gox 4wmby Of Sample Type Sampling sample Interval Shipping Address gags Frequenry 1 30- 346 2960 2 30' 2%0 4680 Wrie Operating Abska, LLC 3 30' 40S0 - 51% C 1 of 1 433 W.9th Ave 4 ofpried &32 30 51% - b300 AOGCCed& Anchorage,Ad 5 30' 6300 7410 99501 6 30- 7410 - 6520 ATIN:7rey kentlrid 7 30' g520 9131 ig1-217-11g4 Total eoxes : 1 7 Apprax Weight Each: 34.4 4.9 roa Tonal Weight: 34.4 Ibs nanhanrdous Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: ��t�17,S �,f3'DIV�S Furie Operating Alaska, LLC 1 433 W 9th Avenue, Anchorage, AK 99501 1 907.277.3726 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KLU A-6 JBR 08/01/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Methane sensor (lel) needed calibrated on Rig Floor.-FP Test Results TEST DATA Rig Rep:Norman MitchellOperator:Furie Operating Alaska, LLC Operator Rep:Tim Ashley Rig Owner/Rig No.:Hilcorp 151 PTD#:2250240 DATE:6/9/2025 Type Operation:DRILL Annular: 250/2500Type Test:BIWKLY Valves: 250/4500 Rams: 250/4500 Test Pressures:Inspection No:bopAGE250617102449 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6.5 MASP: 3856 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 2 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8" X 5"P #2 Rams 1 Blind P #3 Rams 1 5"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"P Kill Line Valves 1 3 1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3020 Pressure After Closure P1650 200 PSI Attained P64 Full Pressure Attained P182 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P16@2100 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P FPMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P12 #1 Rams P12 #2 Rams P9 #3 Rams P9 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2        Test charts attached jbr BOPE - Hilcorp 151 KLU A-6 PTD 2250240 AOGCC Insp# bopAGE250617102449 6/9/2025 BOPE - Hilcorp 151 KLU A-6 PTD 2250240 AOGCC Insp# bopAGE250617102449 6/9/2025 -S-->,�1/� NC pt � AH / I\) BOPE - Hilcorp 151 KLU A-6 PTD 2250240 AOGCC Insp# bopAGE250617102449 6/9/2025 BOPE - Hilcorp 151 KLU A-6 PTD 2250240 AOGCC Insp# bopAGE250617102449 6/9/2025 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Bob Laule Cc:Mike Stefanov; Michael Duncan Subject:RE: Draft for your review and comment. Date:Thursday, May 29, 2025 9:53:00 AM Attachments:KLU A6 Casing Safety Factors 9.625 40lb.docx Bob, Furie’s below plan to install 40# casing at the bottom of the Intermediate casing string is approved. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Bob Laule <b.laule@furiealaska.com> Sent: Wednesday, May 28, 2025 3:36 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Mike Stefanov <m.stefanov@furiealaska.com>; Michael Duncan <m.duncan@furiealaska.com> Subject: Draft for your review and comment. Bryan Furie is currently drilling the intermediate hole section on the KLUA6 well( PTD # 225-024) and the geological horizons and coming in 40’-60’ deeper than planned. This parallels the recent KLU A-5 results. We have a sufficient amount of 47# casing for the planned TD but may need to supplement it with several joints of 40# to accommodate a deeper TD. We would place the 40# in the lower portion of the string but above the liner setting area. Attached are the casing safety factor for 40# casing option. Furie is requesting AOGCC approval of this option. Sincerely, Bob Laule Sr Drilling Engineer Furie Operating Alaska LLC. 433W 9th Ave Anchorage Alaska 99501 Cell 734 276 6506 b.laule@furiealaska.com Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. KLU-A6 Casing Safety factors for 9-5/8’ 40# L80 05/28/2025 9-5/8" 40# L80 Butt 5.750 psi 3,090 psi 916,000# Burst SF 13.2 ppg (frac press)*.052*4,859’ TVD RKB = 3,335 psi less gas column .055psi/ft * 4,859' = 267 psi 3,067 psi 5,750/3,067= 1.87 SF Collapse SF Assume Annulus full of 15.3 ppg cement & casing with seawater (15.3-8.4 ppg)* 4,859' * .052 = 1,743psi 3,090/1,743= 1.77 SF Tension SF 5,808’* 47#/ft = 272,976 .87 bouy 237,489 916,000/237,938= 3.85 SF STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION DIVERTER Test Report for: Reviewed By: P.I. Suprv Comm ________KLU A-6 JBR 05/14/2025 MISC. INSPECTIONS: GAS DETECTORS: DIVERTER SYSTEM:MUD SYSTEM: P/F P/F P/F Alarm Visual Alarm Visual Time/Pressure Size Number of Failures:2 Remarks:Rig Floor methane visual/audible FP-antenna interface-reposition sensor for a pass. TEST DATA Rig Rep:Norman MitchellOperator:Furie Operating Alaska, LLC Operator Rep:Tim Ashley Contractor/Rig No.:Hilcorp 151 PTD#:2250240 DATE:4/14/2025 Well Class:DEV Inspection No:divSAM250416132627 Inspector Austin McLeod Inspector Insp Source Related Insp No: Test Time:2 ACCUMULATOR SYSTEM: Location Gen.:P Housekeeping:P Warning Sign P 24 hr Notice:P Well Sign:P Drlg. Rig.P Misc:NA Methane:FP FP Hydrogen Sulfide:P P Gas Detectors Misc:NA NA Designed to Avoid Freeze-up?P Remote Operated Diverter?P No Threaded Connections?P Vent line Below Diverter?P Diverter Size:21.25 P Hole Size:16 P Vent Line(s) Size:16 P Vent Line(s) Length:57 P Closest Ignition Source:90 P Outlet from Rig Substructure:34 P Vent Line(s) Anchored:P Turns Targeted / Long Radius:NA Divert Valve(s) Full Opening:P Valve(s) Auto & Simultaneous: Annular Closed Time:18 P Knife Valve Open Time:5 P Diverter Misc:0 NA Systems Pressure:P3050 Pressure After Closure:P2100 200 psi Recharge Time:P22 Full Recharge Time:P104 Nitrogen Bottles (Number of):P16 Avg. Pressure:P2050 Accumulator Misc:NA0 P PTrip Tank: P PMud Pits: P PFlow Monitor: NA NAMud System Misc: 9 9 9 9 9Methane:FP FP 2 Rig Floor methane visual/audible FP 05/21/25 05/21/25 RBDMS JSB 052325 JLC 5/21/2025 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 Michael Duncan Drilling Manager Furie Operating Alaska, LLC 433 W. 9th Avenue Anchorage AK, 99501 Re: Kitchen Lights Unit, Undefined Sterling and Beluga Gas Pools, KLU A-6 Furie Operating Alaska, LLC Permit to Drill Number: 225-024 Surface Location: 339' FSL, 898' FWL, Sec 24, T10N, R11W Bottomhole Location: 3744' FSL, 261' FEL, Sec 23, T10N, R11W Dear Mr. Duncan Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED this 11th day of April, 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.11 09:46:16 -08'00' 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: 9,553' TVD: 8,296' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date: 4/15/2025 Total Depth:9. Acres in Property: 14. Distance to Nearest Property: 3+ Miles (non-Furie) 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 114.10' 15. Distance to Nearest Well Open Surface: x-2536130.20 y- 294,327.20 Zone- 4 to Same Pool: See attachments 16. Deviated wells: Kickoff depth: 425 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 55.59 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD Conductor 20" 169 #/ft X-65 XLC-S 400 0 0 400' 400' Surface 13.375" 68 #/ft L-80 Buttress 2,939' 0 0 2,939' 2909' Intermediate 9.625" 47 #/ft L-80 Buttress 5,808' 0 0 5,808' 4859' Production 3.5" 9.2 #/ft L-80 JFE Lion 4,238' 5,300' 4,572' 9,548' 8,291' 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 Diverter Sketch Seabed Report Contact Name: Michael Duncan Michael Duncan Contact Email:m.duncan@furiealaska.com Drilling Manager Contact Phone: (817) 240-3865 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 776' FSL, 598' FWL, Sec 24, T10N, R11W 3744' FSL, 261' FEL, Sec 23, T10N, R11W Time v. Depth Plot Drilling Fluid Program Shallow Hazard Analysis 20 AAC 25.050 requirements Conductor/Structural LengthCasing KLU A-6 Kitchen Lights Unit Undefined Sterling and Beluga Gas Pools Total Depth MD (ft): Total Depth TVD (ft): 3145524168 Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) Driven See attached program STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 See attached program 3,986 psi 433 W. 9th Avenue, Anchorage AK, 99501 Furie Operating Alaska, LLC 339' FSL, 898' FWL, Sec 24, T10N, R11W ADL 389197 2,560 18. Casing Program:Top - Setting Depth - BottomSpecifications 4,443 psi Authorized Title: Authorized Signature: Production Liner Intermediate Authorized Name: Commission Use Only See cover letter for other requirements. 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): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): See attached program Effect. Depth MD (ft): Effect. Depth TVD (ft): essss N ype of W l 1b S Class: os N essss NNooo s N Nooo 168 o s: well is G AAC 2 esss NNooos No S G y E S esss NNooo Ye o Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Drilling Manager API Number: 3/17/2025 By Grace Christianson at 9:10 am, Mar 17, 2025 3895 5658 4774 9553' -bjm 351 351 351 Intial BOP test to 4500 psi. Subsequent BOP tests to 4500 psi. All annular tests to 2500 psi. Submit FIT/LOT data within 24 hrs of obtaining results. See additional prod csg and tubing pressure test requirements written into the procedure. A.Dewhurst 07APR25 50-733-20735-00-00225-024 BJM 4/11/25 DSR-3/25/25*&: 4/11/2025 4/11/2025Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.11 09:46:38 -08'00' RBDMS JSB 041425 1 March 14, 2025 Commissioner Jessie Chmielowski Commissioner Greg Wilson Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Furie Operating Alaska KLU A-6 Permit to Drill (10-401) Submittal Dear Commissioners, Please see attached application for a permit to drill for well KLU A-6. The well will be completed with a 3-1/2” gas lift tie-back completion. A separate sundry notice will be submitted for perforating operations. Please be advised that Furie plans to submit a Form 10-403 Application for Sundry Approvals, as we have a two well program and plan to set surface casing on the KLU A-6 well and then move over to the KLU A-5 well conductor and drill that well to total depth. This will allow Furie to set both string of surface casing with the same diverter set up. The surface casing will be set above any known productive zones and we plan to set a temporary packoff in the wellhead. Drilling operations are expected to commence approximately April 15, 2025. Regards, Michael Duncan Drilling Manager Furie Operating Alaska, LLC ga s, 2 KLU A-6 10-401 Permit to Drill Julius R Platform March 14, 2025 3 Contents 1. Well Information...................................................................................................................................4 2. Tubular Program...................................................................................................................................4 3. Drill Pipe Information............................................................................................................................4 4. Formation Tops.....................................................................................................................................5 5. Proposed Wellbore Schematic..............................................................................................................6 6. Property Plat.........................................................................................................................................7 7. Mandatory Regulatory Compliance / Notifications..............................................................................8 8. Drilling Summary.................................................................................................................................10 9. KLU A-6 Pore Pressure/Frac Gradient Estimate..................................................................................16 10. Anticipated Drilling Hazards............................................................................................................17 11. LOT/FIT Procedure..........................................................................................................................19 12. Diverter Information.......................................................................................................................20 13. BOP Schematic................................................................................................................................22 14. Choke Manifold Schematic.............................................................................................................23 15. Tubing Hanger.................................................................................................................................25 16. Wellhead Schematic.......................................................................................................................26 17. Rig Information...............................................................................................................................27 18. Casing Design Information..............................................................................................................30 19. Permit to Drill Kick Tolerance Evaluation........................................................................................32 20. Time vs. Depth................................................................................................................................36 21. KLU A-6 Fluid Program....................................................................................................................37 22. KLU A-6 Directional Program (wp05)..............................................................................................52 23. Cementing Calculations ..................................................................................................................65 4 1. Well Information Well Name KLU A-6 Drilling Rig Spartan 151 Slot Name Inner Caisson Directional Plan WP05 Planned Completion Type 3-1/2” monobore w/ GLM Target Reservoirs KLU Sterling/Beluga Planned Well TD, MD/TVD 9,553’ MD/8,296’ TVD Surface Location (Governmental) 339’ FSL, 898’ FWL, Sec. 24, T10N, R11W, SM Surface Location (NAD 27) X=2536130.2, Y=294327.2 Work String 5” NC-50 19.50# S-135 RT – Mean Sea Level (MSL) 114.1 ft RT – Mud Line (ML) 202 ft Water Depth Tidal Difference - +/- 20’ 88’ ft 2. Tubular Program Hole Section OD WT (#/ft) Couple OD ID Drift Grade Conn Top Bottom Conductor 20” .8125” WT 20” 18.375” 18.188” X-65 XLC-S Surface 400’ 16” 13.375” 68 14.375” 12.415” 12.259” L-80 Buttress Surface 2,934’ 12.5” 9.625” 47 10.625” 8.684” 8.525” L-80 Buttress Surface 5,808’ 8.5” 3.5” 9.2 3.96” 2.949” 2.867” L-80 JFE LION 5,300 9,553’ **Minimum of 100’ overlap required between casing strings 3. Drill Pipe Information OD ID TJ ID TJ OD WT (#/ft)Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) 5” 4.276” 3.687” 6.625” 19.5 S-135 NC-50 17,100 15,110 712 351' -bjm 5 Description Size Weight Capacity (bbl/ft) Drill Pipe 5” NC-50 5” 19.5#/ft .01776 Tubing JFE Lion 3.5” 9.2 #/ft .00870 9-5/8” Casing 9.625” 47 #/ft .0732 13-3/8” Casing 13.375” 68 #/ft .14970 20” Conductor 20” 169 #/ft .32800 9-5/8” Csg X 3.5” Tbg Annulus .06130 16” Hole X 13-3/8” Csg Annulus .0749 12-1/4” Hole X 9-5/8” Csg Annulus .0558 8-1/2” Hole X 3-1/2” Annulus .0464 13-3/8” Csg by 9-5/8” Csg Annulus .0597 4. Formation Tops x Top Sterling: 2,940’ MD/ 2,899’ TVDRKB x Top Beluga: 5,793’ MD/ 4,850’ TVDRKB Note: TVD is from rig floor. RT to MSL (Spartan 151) 114.10’ 6 5. Proposed Wellbore Schematicp Superseded 7 6. Property Plat 8 7. Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x BOPs shall be tested at 2-week intervals during drilling and at 1-week intervals during abandonment operations. Ensure to provide AOGCC 48 hours’ notice prior to testing BOPs x The initial test of BOP equipment will be to 250/5,000 psi and subsequent tests of BOP equipment will be to 250/4,500 psi for 5/5 min (annular to 50% rated WP, 2,500 psi on the high test for initial and subsequent tests). o Confirm that these pressures match those specified on the APD. x Minimum required Rated Working Pressure (RWP) of the BOPE and wellhead must exceed: 3,500 psi. The wellhead is rated to 5,000 psi and the BOPS to 5,000 psi. x If the BOP is used to shut in on the well in a well control situation, ALL BOP components utilized for well control must be tested prior to the next trip into the wellbore. This pressure test will be charted same as the 14-day BOP test. x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid system”. x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements” x Review all conditions of approval of the PTD on 10-401 form. Ensure that the conditions of approval are captured in shift handover notes until they are executed and complied with. x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Required AOGCC Notifications: x Well control event (BOPs utilized to shut in the well to control influx of formation fluids). x 48 hour notice prior to full BOPE test. x Any other notifications required in APD conditions of approval. 9 AOGCC Contact Information: x Jim Regg / AOGCC Inspector/ (O): 907-793-1236 / Email: jim.regg@alaska.gov x Bryan McLellan / Petroleum Engineer/ (O): 907-793-1226 / (C): 907-250-9193 / Email: bryan.mclellan@alaska.gov x Melvin Rixse / Petroleum Engineer/ (O): 907-793-1231 Email: melvin.rixse@alaska.gov Primary Contact for Opportunity to Witness: x Test/Inspection notification standardization format: Test Witness Notification - Alaska Oil and Gas Conservation Commission (state.ak.us) x Notification/ Emergency Phone: 907-793-1236 (During normal Business Hours) x Notification/ Emergency Phone: 907-659-2714 (Outside normal Business Hours) 10 8. Drilling Summary KLU A-6 will be drilled to 9,553’ MD. A 3.5” L-80 9.2# JFE Lion production liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 3-1/2” gas lift upper completion tied-back to the 3-1/2” lower completion. Drilling operations are expected to commence approximately April 15, 2025. General sequence of operations pertaining to this drilling operation conducted under 10-401 Sundry: Drill 16” Surface Hole 1. Rig up the 20-3/4” diverter system with 21-1/4” annular preventer beneath the drill floor. 2. M/U and run in the hole with a 16” bit and bottom hole assembly. 3. Displace the conductor to spud mud. 4. Drill ahead to the 13-3/8” casing point. 5. Monitor hole inclination and direction. Utilize gyro surveys until clean MWD surveys can be achieved. 6. At 13-3/8” casing point, circulate a hi vis pill bottoms up and make a short trip to the 20” conductor shoe. 7. Trip back to bottom and note any tight spots and fill on bottom. 8. Circulate and condition mud for running casing. 9. POH to run casing. 10. TIH with casing 11. Land the casing, ensure the wellhead technician is monitoring this operation. 12. Circulate and condition mud for cementing. 13. Pump Spacer, drop bottom plug. 14. Mix and pump cement per design. 13-3/8” Casing Cement Slurry Lead: System Class G + 1.25% FCA250 Accelerant + 1.1% FCE260 Extender Density 12.5 lb/gal Design Volume 367 bbls Yield 2.08 ft3/sk Mixed Water 11.92 gal/sk Expected Thickening 17:29 hr:min API Fluid Loss N/A Additives Code Additives Code Class G Cement 94 lbs/sk 11 Tail: System Class G + .5% FCD200 Dispersant + .2% FFL220 FLAC Density 15.3 lb/gal Design Volume 87 bbls Yield 1.24 ft3/sk Mixed Water 5.57 gal/sk Expected Thickening 6:14 hr:min API Fluid Loss < 100 Additives Code Additives Code Class G Cement 94 lbs/sk 15. Displace cement with mud. 16. Note any cement returns to surface. 17. POOH. Lay down diverter assembly. 18. Make up the wellhead assembly. Test wellhead. BOP N/U and Test 19. N/U to 13-5/8" 5M X 13-5/8” 5M spool. o N/U 13-5/8" x 5M BOP as follows (top down): o 13-5/8" x 5M Shaffer spherical annular BOP. o 13-5/8" Shaffer 5M stack. (2-7/8" X 5" VBR in top cavity, blind ram in bottom cavity). o 13-5/8" mud cross. o 13-5/8" Shaffer 5M stack. (2-7/8" X 5" VBR). o N/U bell nipple, install flowline. o Install (1) manual valve and one hydraulic valve on kill side of mud cross. Manual valve used as inside or "master valve". o Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 20. Test BOPE. o Test BOP to 250/5,000 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min. o Leave "A" section side outlet valves open during BOP testing so pressure does not build up beneath the back pressure valve with plug off tool if there is a leak. Confirm the correct valves are open. o Test VBRs on 5" and 3-1/2” test joint (250/5,000 psi) See attached permit to drill. o Test Annular on 5" test joint (250/2,500 psi). o Ensure gas monitors are calibrated and tested in conjunction w/ BOPE. 12 Drill 12-1/4” Intermediate Hole 21. Make up the 12-1/4” drilling assembly. 22. Wash and ream down to the shoe track. 23. Test the casing to 2,500 psi. 24. Drill through the shoe track, and a minimum of 20 feet of new formation. Spot a 30 bbl pill of viscous mud on bottom. 25. Perform a leak off test. A leak off of 11.5 ppg will be satisfactory. Report results as described in the Permit to Drill (PTD). 26. Drill ahead to the 9-5/8” casing point. 27. After drilling to the 9-5/8” casing point, pump a 50 bbl high vis sweep and circulate bottom up. 28. Short trip to the 13-3/8” casing shoe. 29. While tripping to the 13-3/8” casing shoe, note any tight spots both the depth and lithology and work through them. 30. Trip back to bottom, note amount of fill. 31. Circulate and condition the mud. 32. POH to run 9-5/8” casing. 33. Run Casing 34. Fill casing at least every four joints and monitor mud return volume. 35. Land the casing, ensure the wellhead technician is monitoring this operation. 36. Circulate and condition mud for cementing. 37. Cement casing per cement program. The current plan is to take the cement top to 2,500’ MD. This will provide an option for a shallow sidetrack in the future. 9-5/8” Cement Slurry Lead: System Class G + 1.25% FCA Accelerant + 1.1% FCE Extender Density 12.5 lb/gal Design Volume 170 bbls Yield 2.08 ft3/sk Mixed Water 11.92 gal/sk Expected Thickening 17:29 hr:min API Fluid Loss N/A Additives Code Description Concentration Class G Cement 94 lbs/sk 230 bbls per Bob Laule email 4/7/25. -bjm TOC to 2400' MD per Bob Laule email 4/7/25. -bjm 13 Tail: System Class G + .5% FCD200 Dispersant + .2% FFL220 FLAC Density 15.3 lb/gal Design Volume 48 bbls Yield 1.24 ft3/sk Mixed Water 5.57 gal/sk Expected Thickening 6:14 hr:min API Fluid Loss < 100 Additives Code Description Concentration Class G Cement 94 lbs/sk 38. POOH. Drill 8-1/2” Production Hole 39. M/U and run in the hole with a 8-1/2” bit and bottom hole assembly. 40. Trip in hole to several stands above the shoe track. 41. Wash and ream down to the shoe track. 42. Test the casing to 2,500 psi. 43. Drill through the shoe track, and a minimum of 20 feet of new formation. Spot a 30 bbl pill of viscous mud on bottom. 44. Run a leak off test. A leak off of 12.5 ppg will be satisfactory. Report results as described in the PTD 45. Drill ahead to the total depth of the well. 46. After drilling to TD, pump a 50 bbl high vis sweep and circulate bottom up. 47. TOH with drilling assembly, handle BHA as appropriate. 48. Run 3-1/2" production liner in the hole. 49. Set liner 5-10’ off bottom. 50. Ensure liner hanger is set, but do not un-sting from liner 51. Proceed with pre-cement job circulation and cement job. 52. Pump cement per cement program. Test production casing to 3500 psi, 50% of burst, per 20 AAC 25.030(e). -bjm 14 3-1/2” Cement Slurry Lead: System Class G + .85% FCE260 Extender Density 12.5 lb/gal Design Volume 273 bbls (first 150 bbls without LCM) Yield 2.08 ft3/sk Mixed Water 11.92 gal/sk Expected Thickening 4:09 hr:min API Fluid Loss N/A Additives Code Description Concentration Class G Cement 94 lbs/sk Tail: System Class G + .5% FCD200 Dispersant + .2% FFL220 FLAC + .1% FMR210 Retarder Density 15.3 lb/gal Design Volume 42 bbls Yield 1.24 ft3/sk Mixed Water 5.57 gal/sk Expected Thickening 3:50 hr:min API Fluid Loss < 100 ml/30 min Additives Code Description Concentration Class G Cement 94 lbs/sk 53. Monitor returns & pressure closely while circulating. Notify Well Site Supervisor immediately of any changes. Reduce pump rate as required to avoid packoff. 54. Pick up to release liner running tool and set packer. Pressure test down back side to verify packer set 55. Pick up out of PBR 56. Circulate out excess cement 57. Sting back into PBR. Perform a full packer test by pressuring down the backside 3,500 psi for 30 minutes. Record test on chart recorder. 58. Bleed off pressure. TOOH 59. RIH with Polish Mill and polish lower PBR. POH. 15 Run 3-1/2” Upper Completion 60. PU and run tubing with PBR stinger, GLMs, CIM, and SCSSV to liner hanger 61. PU install space out pups one joint below tubing hanger. 62. Terminate control lines and tie into tubing hanger. PT control lines to 5,000 psi. 63. Land tubing hanger. Test SSSV control line and chemical injection line at 5,000 psi. 64. PT annulus to 2,500 psi and record on chart for 30 minutes. 65. Install BPV. 66. ND 13-5/8” BOP. Install plug off tool in BPV. 67. NU and pressure test 4-1/16” 5K tree to 5000 psi. 68. Retrieve BPV and plug off tool. 69. Release to Production. 70. Rig down and move off. Contingent Coiled Tubing Cleanout 71. RU coiled tubing and pressure control equipment. Pressure test BOP’s to 250 psi/4,000 psi. RIH with bit and motor. 72. Cleanout to below deepest planned perforation interval. 73. POH. Rig down coiled tubing. Run Cement Bond Log 74. Contact cementer for impedance value for the cement versus time. 75. R/U E-line and run CBL/ GR/ CCL. Pressure test tubing to MPSP. -bjm 16 9. KLU A-6 Pore Pressure/Frac Gradient Estimate 1616161161616161616111661616161166111616161616161611666661616161611166166611661616666661666 17 10.Anticipated Drilling Hazards Lost Circulation: Drilling depleted reservoir may cause loss circulation events x Maintain sufficient volumes while drilling. x Maintain ability to take on fresh water during drilling phase x If a LC event occurs pumping cement will be the last resort x Ensure 500 lbs. of medium/coarse fibrous material, 500 lbs. SteelSeal (Angular, dual- composition carbon-based material), & 500 lbs. different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. x KLU A-1: No LC events occurred during the original drilling of KLU A1. Mud weights ranged from 9.5 to 10+ ppg. At TD mud weight was reduced to 10. ppg. x KLU A2/A2A: Lost circulation in production hole with a loss rate of 120 bph. Losses cured with 30ppb LCM sweeps. x KLU A-4: Lost circulation in Production hole with a loss rate of 105 bph. Losses cured with 16ppb LCM sweeps. Losses occurred while running 9-5/8” casing and during the second stage of the 9-5/8” casing cement job circulating from the stage tool at 5992’. No losses were reported while drilling 12-1/4” hole or while circulating after casing was on bottom. o 6,282’ MD Well Control: x Prior to drilling into the Sterling or Beluga, hold a pre-reservoir meeting to outline heightened awareness for kick detection and lost circulation. Hydrates and Shallow gas x No hydrates are expected in this area. x No H2S are expected in this area. x Ensure H2S monitoring equipment as specified in 20 AAC 25.065(1) will be functioning on the rig as standard operating procedure. x Ensure products for treating H2S contamination in the drilling mud system will be maintained on the rig. 18 Anticollision: See directional plan for anticollision analysis. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. x Identified by a drilling break (increase in ROP) by drilling 2-3’. Pick up with pumps on or back ream. In offset well the coals are more frequent and thicker the deeper the well is drilled. Coals seams are associated with loss circulation, sloughing, being water wet which can cause packoff and sticking drill pipe. They can also exhibit breathing / ballooning. Observation from previous KLU’s well show the coals have formation pressures by 1-1.5 ppg higher than the sand formations. x Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. Ensure the neutral point is in the heavy weight or BHA. x Use asphalt-type additives to further stabilize coal seams. x Increase fluid density as required to control running coals. x Emphasize good hole cleaning through hydraulics, ROP, frequent sweeps and system rheology. x Minimize swab and surge pressures x Minimize back reaming through coals when possible. x Once in a coal seam, maintain the hydraulic pump pressure and GPM until the bit has been reamed back up and is out of the coal seam, EVEN IF MUD LOSSES ARE EXPERIENCED. Then observe the well and the hydraulics “may” need to be reduced to keep from losing circulation and causing the coals to water wet, which may create sloughing problem in the coals, utilizing the water loss additives and asphaltenes to combat the water wetting aspects. Lost circulation materials (a combination of various sizes of calcium carbonates) should be utilized initially. Tight Hole/ Packoffs: If the hole becomes tight or pack offs, move the drill string in the opposite direction. Depleted Zones: Be aware of previously produced zones, that may a subnormal pore pressure, which will reduce the fracture gradient. Review with the rig crews and be prepared for losses. 19 11.LOT/FIT Procedure Procedure for LOT/FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. Add casing pressure test data to graph if recent and available. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in I-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. casing pressure, per B. Laule 4/7/25. -bjm 20 12.Diverter Information 21 22 13.BOP Schematic 23 14.Choke Manifold Schematic 24 25 15.Tubing Hanger 26 16. Wellhead Schematic 26666222622626626262626262262222262262626666262626622262666662662262622666262666622222226666666662222266266666222622622622266662222622222 27 17.Rig Information 2828 29292929292929 30 18.Casing Design Information Casing Design KLU A6 rev 1 3/6/2025 RBL SF Burst SF Collapse SF Tension 13-3/8" 68#/ft L80 Butt 2.77 2.16 8.9 9-5/8" 47#/ft L80 Butt 2.23 1.32 4.57 3-1/2" 9.2#/ft L80 JFE 2.39 3.53 5.1 Burst Collapse Tension 13-3/8" 68#/ft L80 Butt 5,020 psi 2,260 psi 1,556,000# Burst SF 13.0 ppg(frac press)*.052*2,909 TVD RKB = 1,966 psi less gas column .055psi/ft * 2,909'=160 psi MASP 1806 psi 5020/1806= 2.77 SF Collapse SF Assume Annulus full of 15.3 ppg cement & casing with seawater (15.3-8.4 ppg)* 2909' * .052= 1043psi 2,260/1043= 2.16 SF Assume Annulus full of 15.3 ppg cement & casing with .055psi/ft gas (15.3*2909*.052) -(.055*2909)= 2154 psi 2,260/2154=1.04 SF Tension SF 68#/ft*2,939'= 199,852 .87 bouy 173,871 1,556,000/173,871= 8.9 SF Burst Collapse Tension 9-5/8" 47# L80 Butt 6,870 psi 4,760 psi 1,086,000# Burst SF 13.2 ppg(frac press)*.052*4,859 TVD RKB = 3,335 psi less gas column .055psi/ft * 4,859'= 267 psi 3,067 psi 6,870/3,067= 2.23 SF Collapse SF Assume Annulus full of 15.3 ppg cement & casing with seawater (15.3-8.4 ppg)* 4,859' * .052= 1,743psi 4,760/1,743= 2.7 31 Assume Annulus full of 15.3 ppg cement & casing with .055psi/ft gas (15.3*4,859*.052) -(.055*4,859) = 3,598 4,760/3,598= 1.32 SF Tension SF 5,808* 47#/ft= 272,976 .87 bouy 237,489 1,086,000/237,938= 4.57 Burst Collapse Tension 10,160 psi 10,530 psi 159,090# 3-1/2" 9.3#/ft L80 JFE Lion Burst SF 10.3 ppg *(.052)*8,296'= 4.443 psi less gas column .055psi/ft * 8,296''= 456 psi Surface MASP = 3,986 psi Liner length 9,553-5,658 = 3,895' 150 liner lap MASP @ liner top= Surface MASP + gas column height to liner top. 3986+4,770'*.055 psi/ft= 4,248 psi 10,160/4,248= 2.39 SF Collapse SF Assume Annulus full of 15.3 ppg cement & casing with seawater (15.3-8.4 ppg)*8,296 *.052 = 2,976 psi 10,530 / 2,976 = 3.53 SF Assume Annulus full of 15.3 ppg cement & casing with .055psi/ft gas (15.3*8,296*.052) -(.055*8296) = 6,144 psi 10,530 / 6,144 = 1.71 SF Tension SF 3,895 9.2 #/ft= 35,834 # .87 bouy 31,175 159,090 / 31,175= 5.1 32 19.Permit to Drill Kick Tolerance Evaluation Well: A6 intermediate shoe kick tolerance 5,968'with 2,949 surface shoe <== Data Input Name : Furie KLUA6 <== Data Input Mud Weight (ppg)10.80 <== Data Input Weak point or LOT - Measured depth (ft) 5,808'<== Data Input Weak point or LOT True vertical depth (ft) 4,859'<== Data Input Weak point or LOT - Hole angle (deg) 54.0º<== Data Input Weak point or LOT - Hole size (in) 8.500"<== Data Input Weak point pressure or LOT - EMW (ppg) 12.50 <== Data Input Zone of interest - Measured depth (ft) 9,553'<== Data Input Zone of interest - True vertical depth (ft) 8,295'<== Data Input Zone of interest - Hole angle (deg) 16.0º<== Data Input Zone of interest - Hole size (in) 8.500"<== Data Input Zone of interest - Pore pressure EMW (ppg) 10.80 <== Data Input Gas gradient (psi/ft) 0.06 <== Data Input Bottom hole assembly OD (in) 6.750"<== Data Input Bottom hole assembly length (ft) 188'<== Data Input Drill pipe OD (in) 5.000"<== Data Input BHA annular vol. @ zone of interest (bbl/ft)0.0259 DP annular vol. @ zone of interest (bbl/ft)0.0459 DP annular vol. @ weak point (bbl/ft)0.0459 Additional safety margin (psi) 200.00 <== Data Input Weak point pressure (psi):Plo 3,158 psi Weak point pressure - Safety margin: Pmax 2,958 psi 33 Pmax EMW 11.71 ppg Max anticipated formation pressure (psi):Pf 4,658 psi Weak Pt to Zone of Interest distance (TVD ft): OH {TVD}3,436' Weak Pt to Zone of Interest distance (MD ft):OH {MD}3,745' Maximum influx height at the bit (TVD ft):H {TVD}453' Maximum influx height at the bit (MD ft):H {MD}471' Calc. volume of {H} around BHA:V1bha 4.9 bbl Calc. volume of {H} around drill pipe:V1dp 13.0 bbl Calc. volume that H equals @ initial shut in:V1 17.9 bbl Calc. vol. that H equals @ weak point (MD ft):Vwp 35.4 bbl Calc. volume of Vwp @ initial shut in:V2 22.5 bbl Kick Tolerance: V1 17.9 bbl NOTE: Spreadsheet revised by: G. S. Walz 3/9/99 34 Well: A6 kick tolerance of shallow surface shoe for intermediate shoe@ 5968'<== Data Input Name : Furie KLU A6 <== Data Input Mud Weight (ppg)9.10 <== Data Input Weak point or LOT - Measured depth (ft) 2,939'<== Data Input Weak point or LOT True vertical depth (ft) 2,909'<== Data Input Weak point or LOT - Hole angle (deg) 11.0º<== Data Input Weak point or LOT - Hole size (in) 12.250"<== Data Input Weak point pressure or LOT - EMW (ppg) 11.50 <== Data Input Zone of interest - Measured depth (ft) 5,808'<== Data Input Zone of interest - True vertical depth (ft) 4,859'<== Data Input Zone of interest - Hole angle (deg) 54.0º<== Data Input Zone of interest - Hole size (in) 12.250"<== Data Input Zone of interest - Pore pressure EMW (ppg) 9.10 <== Data Input Gas gradient (psi/ft) 0.06 <== Data Input Bottom hole assembly OD (in) 6.750"<== Data Input Bottom hole assembly length (ft) 188'<== Data Input Drill pipe OD (in) 5.000"<== Data Input BHA annular vol. @ zone of interest (bbl/ft)0.1015 DP annular vol. @ zone of interest (bbl/ft)0.1215 DP annular vol. @ weak point (bbl/ft)0.1215 Additional safety margin (psi) 200.00 <== Data Input Weak point pressure (psi):Plo 1,740 psi Weak point pressure - Safety margin:Pmax 1,540 psi 35 Pmax EMW 10.18 ppg Max anticipated formation pressure (psi):Pf 2,299 psi Weak Pt to Zone of Interest distance (TVD ft): OH {TVD}1,950' Weak Pt to Zone of Interest distance (MD ft):OH {MD}2,869' Maximum influx height at the bit (TVD ft):H {TVD}390' Maximum influx height at the bit (MD ft):H {MD}663' Calc. volume of {H} around BHA:V1bha 19.1 bbl Calc. volume of {H} around drill pipe:V1dp 57.7 bbl Calc. volume that H equals @ initial shut in:V1 76.8 bbl Calc. vol. that H equals @ weak point (MD ft):Vwp 48.3 bbl Calc. volume of Vwp @ initial shut in:V2 32.3 bbl Kick Tolerance: V2 32.3 bbl NOTE: Spreadsheet revised by: G. S. Walz 3/9/99 36 Depth (ftMD)20.Time vs. Depth 37 21.KLU A-6 Fluid Program 37 3838 3939 4040 4141 4242 4343 4444444444 4545555 4646 4747777 4848 4949999999 5050 51511111 52 22.KLU A-6 Directional Program (wp05) 52 53535 545444 5555 565656 575757 58585858 5959 6060 6161 6262 6363 6464 65 23.Cementing Calculations 665656555656556666666666656655555566666666665666555555556666665666666655655555555666666666666556555556666666656656555666666665565556666666666655555555566666666556555555556566666666665655565555666666666665555555555556566666666555555566665 Superseded 1 Gluyas, Gavin R (OGC) From:Michael Duncan <m.duncan@furiealaska.com> Sent:Monday, April 7, 2025 10:00 AM To:McLellan, Bryan J (OGC); Mike Stefanov Cc:Rixse, Melvin G (OGC); Trey Kendrick Subject:Re: KLU A-6 Close approach Bryan - For the KLU A-6. Several wells "failed" the close approach metrics with a CF of less than one. Almost all of those wells (The KLU A-2 NE, KLU A-2 North, Well SE1, Well SSE1) have yet to be drilled. We will be careful with these paths to keep room for future wells but of course there is no risk of collision. The one that exists is the KLU A-4 PB1. This is an older wellbore that was plugged back. It does not have steel in the old wellbore, only cement. In this case we barely overlap with the ellipse of uncertainty (-.46' at a depth of 525'). We still intend to take the same prudent mitigation measures to avoid collision and to avoid creating difficulty for future wells. We will run a gyro every 30' beginning in the structural casing/conductor. We intend to use this gyro to get a tool face orientation before drilling new rock. We then plan to orient and begin with a slide to ensure the proper direction is established right away. Below is a clip of the APD (Pages 63 and 64) that shows the applicable data. Thanks, Michael Duncan 817.240.3865 2 3 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, April 7, 2025 7:42 AM To: Michael Duncan <m.duncan@furiealaska.com>; Mike Stefanov <m.stefanov@furiealaska.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXT] RE: KLU A-6 Close approach Michael, Could you answer the same question but for KLU A-6? Which of the close approach failures represent real wells and what mitigations do you plan to take to prevent a collision with an existing wellbore? Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Michael Duncan <m.duncan@furiealaska.com> Sent: Friday, April 4, 2025 3:06 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Mike Stefanov <m.stefanov@furiealaska.com> Subject: Re: KLU A-5 Close approach Bryan - There are two examples, with existing wells, where we lose the Clearance Factor (CF) of 1, meaning that the ellipse of uncertainty overlaps with another well trajectory. In the case of the KLU A-2 North, we just barely "touch" on the ellipse of uncertainty. You see a -.04' in ellipse separation and a .993 CF. In the case of the KLU A-4, we have more of an overlap (-2.37') at a depth of 420'. To avoid collision in each we will be utilizing a gyro survey, run every 30' until we are clear (CF above 1). In the case of the KLU A-4 in particular, we are planning to take additional measures to avoid. We will use the gyro in the conductor to verify direction and the tool face. Once we have the tool face near the end of the conductor, we will scribe the pipe to orient for a slide to the west. Heading sue west will take us away from the KLU A4. We have roughly 100' to establish this direction and verify movement away from the well. Thanks, Michael 4 From: McLellan, Bryan J (OGC) Sent: Thursday, April 3, 2025 2:10 PM To: Michael Duncan; Mike Stefanov Subject: [EXT] RE: KLU A-5 Close approach Can you address each of these failed close approaches? I believe most of them are planned wells and don’t actually exist, or maybe some are plugged? 5 Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Michael Duncan <m.duncan@furiealaska.com> Sent: Thursday, April 3, 2025 1:54 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Mike Stefanov <m.stefanov@furiealaska.com> Subject: Re: KLU A-5 Close approach Bryan - We will be utilizing the Halliburtons Risk assessment for close approach. Running Gyro in the surface section from conductor to ~1500 taking Gyro surveys every 30' while under a 1 clearance factor and gyro tool-faces for steering separation. Once we are over 1 CF, we will utilize Halliburton's MWD survey tool for qualified survey . Michael 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. 6 From: McLellan, Bryan J (OGC) Sent: Thursday, April 3, 2025 11:32 AM To: Michael Duncan; Mike Stefanov Subject: [EXT] KLU A-5 Close approach Michael, How is Furie planning to address the close approach anti-collision failures? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 ***External Email***f Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. 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If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. 1 McLellan, Bryan J (OGC) From:Michael Duncan <m.duncan@furiealaska.com> Sent:Thursday, April 10, 2025 4:00 PM To:McLellan, Bryan J (OGC); Rixse, Melvin G (OGC) Cc:Mike Stefanov; Bob Laule Subject:Conductor install Bryan - Thank you for the conversation. Here is a quick review of the conductor install and the alignment. 1. The platform is plumb, this is verified and fixed at time of install with sub see jacks and pile latched. Each side that site on a pile is adjusted before permanent pile attachment. 2. Prior to conductor install, a penetration is cut at each deck level on the platform and a "guide" is installed. Here is a drawing of the guide It is a 24" piece of pipe that is installed on i-beams in between deck ibeams. Location is verfied to ensure each deck penetration and guide is centered vertically (plumb) with the other penetrations. 3. Before installing a conductor, we verify the placement with a "drift". Here is a drawing of the drift. 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 It is made to 22" diameter and lowered through each slot with 2 3/8" tubing. When lowered we "tag" (push by hand to bump) piping and anodes on the way down. Here is a drawing of subsea components, and I have circled places where we tag items with the drift to verify subsea locations. After confirming all of this is in place, and the platform slots are where they should be, the conductors are lowered in place. Plumb is verified (by level, and by measurement from known locations at deck penetrations. Once all is verfifed we tag the mud and hammer in place. We watch the guides as we hammer in the conductors. I was personally impressed at how centered the conductors stayed. The conductors are very heavy wall (.812 wall thickness) for driving purposes. The hammer is a 50,000 lbs and hits with 104,000 ft-lbs of energy. We work with the pile driving company to verify conductor strength. 3 Hopefully this review provides the appropriate concepts towards verification that the conductors are installed parallel to each other, and that the material strength is there for all well work. In the past I have installed conductors to a depth of 80' while these are driven well past 100'. In addition to the strength of the conductor, we intend to hold the surface casing in place until cement is placed and set up. This will ensure that the weight of the surface pipe is not fully stacked out on the conductor. We would do this by lowering a small amount of weight on the surface casing landing ring to verify position, but then use the landing joint on slips to hold the majority of the weight. Please let me know if there are further concerns. Thank you, Michael Duncan 817.240.3865 Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. 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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. KITCHEN LIGHTS BELUGA UND GAS and STERLING UND GAS KLU A-6 225-024 WELL PERMIT CHECKLISTCompanyFurie Operating Alaska, LLCWell Name:KLU A-6Initial Class/TypeDEV / PENDGeoArea890Unit11120On/Off ShoreOffProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2250240KITCHEN LIGHTS, STERL UND GAS - 470500 KITCHEN LIGHTS, BLUG UND NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA1 Permit fee attachedYes2 Lease number appropriateYes3 Unique well name and numberYes KITCHEN LIGHTS, STERL UND GAS - 470500 and BLUG UND GAS - 47051 - governed by Statewide Regs4 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)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes21 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 approvedYes26 Adequate wellbore separation proposedYes27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP=3986, BOP rated to 5000 psi (BOP test to 4500 psi)30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)No Plan to batch drill surface holes with KLU6 & KLU5, then return to KLU6 after completing KLU532 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)Yes No H2S are expected in this area.35 Permit can be issued w/o hydrogen sulfide measuresYes Potential depleted gas reservoir at ~5,200' MD. Expected pressure range is 0.281 to 0.561 psi/ft36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate4/7/2025ApprBJMDate4/11/2025ApprADDDate4/7/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA1 Permit fee attachedYes2 Lease number appropriateYes3 Unique well name and numberYes KITCHEN LIGHTS, STERL UND GAS - 470500 and BLUG UND GAS - 47051 - governed by Statewide Regs4 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)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes21 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 approvedYes26 Adequate wellbore separation proposedYes27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP=3986, BOP rated to 5000 psi (BOP test to 4500 psi)30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)No Plan to batch drill surface holes with KLU6 & KLU5, then return to KLU6 after completing KLU532 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)Yes No H2S are expected in this area.35 Permit can be issued w/o hydrogen sulfide measuresYes Potential depleted gas reservoir at ~5,200' MD. Expected pressure range is 0.281 to 0.561 psi/ft36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate4/7/2025ApprBJMDate4/11/2025ApprADDDate4/7/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 4/11/2025