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Home My WebLink About225-023 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-5 PTD: 225-023 API: 50-733-20734-00-00 Alaska E-Line Logs x KLU A-5_PERF_5-SEP-2025_(5639)_FieldPrint (.las/.pdf) x KLU A-5_PPROF_16-Sep-2025_(5655)_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: 225-023 T40934 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.02 14:45:37 -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-5 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): 9,310'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 9,290' MD Suspension Expiration Date: 433 W. 9th Avenue, Anchorage, AK 99502 50-733-20734-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY 9,290'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 225-023Furie Operating Alaska, LLC Will perfs require a spacing exception due to property boundaries? Current Pools: Kitchen Lights Unit Proposed Pools: 8,168' 8,148' 2,116 psi MPSP (psi): TVD BurstMD 6,870 psi5,630' 2,931' 346' 2,911' 4,858' 346' 2,931' 5,630' 3-1/2" See attached schematic 20" 13-3/8" 346' 9-5/8" September 3rd, 2025 9,290'3,874' 3-1/2" 8,148' 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 08/21/2025 325-507 By Grace Christianson at 12:25 pm, Aug 22, 2025 DSR-8/26/25 10-404 SFD 8/27/2025BJM 9/2/25 Re-perforation of intervals previously authorized under previous sundries are authorized under this sundry, in addition to those intervals requested herein. See attached email. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.02 16:13:01 -08'00'09/02/25 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-5 (PTD 225-023) 10-403 Add Beluga Perforations Mr. McLellan, Enclosed is Ă 10-403 ƐƵŶĚƌǇfor adding Beluga perforations to the KLU A-5 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 Unit: Kitchen Lights Unit Well Number: KLU A-5 Self-Closing SCSSV Baker - Set at 456' MD/TVD Ser: 4753288-01. 5K psi working pressure. Opening pressure at SCSSV=1,800 psi + SITP Gas Lift Mandrels 6 1,244' MD 1,240' TVD CIM 1,589' MD 1,581' TVD 5 2,013' MD 2,002' TVD 4 2,693' MD 2,676' TVD 3 3,338' MD 3,309' TVD 2 4,083' MD 3,952' TVD Depth MD: 1 5,194' MD 4,621' TVD Depth TVD: X Nipple at 5,397' MD / 4,732' MD Liner Top Packer at 5,416' MD / 4,743' TVD Intermediate Hole: termediate Casing: Depth MD: Depth TVD: ` Beluga Perforation 7,033'-7,053' MD. Added 7/24/2025 Beluga Perforation 7,240'-7,260' MD. Added 7/24/2025 Beluga Perforation 7,411'-7,417' MD. Added 7/24/2025 Beluga Perforation 7,464'-7,482' MD. Added 7/23/2025 Beluga Perforation 7,920'-7,931' MD. Added 7/23/2025 Beluga Perforation 7,947'-7,968' MD. Added 7/23/2025 Beluga Perforation 8,729'-8,735' MD. Added 7/22/2025 Beluga Perforation 8,951'-8,971' MD. Added 7/22/2025 12.25" 9 5/8", 47 lb/ft, L-80 BTC 5,630' KLU A-5 Wellbore Schematic TD: 9,310' MD / 8,168' TVD 13 3/8", 68lb/ft L-80 BTC 2,931' Conductor: 20" x .8125" Depth: 346' RKB Surface Hole: 16" Date: 8/1/2025 Depth MD: 9,290' Depth TVD: 8,148' Production Hole: 8.5" Production Casing: 3.5", 9.2 lb/ft, L-80 JFE Lion 2,911' 4,858' Surface Casing: See perforation table attached for perforation intervals Perforation Table KLU A-5 MPSP Calculation: Interval: 6,585’-6,590’ MD (5,494’-5,498’ TVD) Estimated Reservoir Pressure at Top Perf: 2,418 psi Gas Gradient (Based on KLU 3 Static Gradient Survey): 0.055 psi/ft MPSP = (2,418 psi – (0.055 * 5,494’ TVD) = 2,116 psi KLU A-5 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-5 Beluga 5869 5913 44 4988 5013 KLU A-5 Beluga 5981 5993 12 5052 5059 KLU A-5 Beluga 6027 6042 15 5079 5087.5 KLU A-5 Beluga 6094 6130 36 5118.5 5141.5 KLU A-5 Beluga 6348 6359 11 5295 5303.5 KLU A-5 Beluga 6458 6464 6 5383 5388 KLU A-5 Beluga 6560 6583 23 5472 5492 KLU A-5 Beluga 6585 6590 5 5494 5498 Total 152 Original reservoir pressure from deepest perfs has 0.47 psi/ft gradient or less, per attached email from Dan Robertson. -bjm Gas Gradient (Based on KLU 3 Static Gradient Survey): 0.055 psi/ft 1 From:Dan Robertson <d.robertson@furiealaska.com> Sent:Tuesday, September 2, 2025 12:22 PM To:McLellan, Bryan J (OGC) Subject:Re: [EXT] Fwd: KLU A-5 (PTD 225-023) perf sundry Bryan, Looks like an error in the TVDBKB depth of the pressure measurement in the job log. The correct depths are 8951 MDBKB, 7812 TVDBKB. 3688 psi/ 7812' TVDBKB= 0.47 psi/ft The depth in the original 7/22/25 job log was 7182 TVDBKB, now corrected to 7812 TVDBKB. Images from the directional survey and 7/22/25 pressure temperature survey are attached for reference. 2 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, September 2, 2025 11:53 AM To: Dan Robertson <d.robertson@furiealaska.com> Subject: RE: [EXT] Fwd: KLU A-5 (PTD 225-023) perf sundry Dan, Could you double check your numbers from the 7/22/25 service report. I get 3688 psi @ 7182’ TVD = 0.514 psi/ft. The job log says it is 0.472 psi/ft. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 3 From: McLellan, Bryan J (OGC) Sent: Tuesday, September 2, 2025 11:34 AM To: Dan Robertson <d.robertson@furiealaska.com> Cc: Hunter Van Wyhe <h.vanwyhe@furiealaska.com>; Trey Kendrick <t.kendrick@furiealaska.com> Subject: RE: [EXT] Fwd: KLU A-5 (PTD 225-023) perf sundry Dan, With the deepest perfs having 0.47 psi/ft or less, Furie can perforate all the requested intervals without concern of fracturing the formation at the shoe. I’ll submit the sundry for approval today and you should have it by CoB today or tomorrow latest. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Dan Robertson <d.robertson@furiealaska.com> Sent: Friday, August 29, 2025 4:14 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Hunter Van Wyhe <h.vanwyhe@furiealaska.com>; Trey Kendrick <t.kendrick@furiealaska.com> Subject: Re: [EXT] Fwd: KLU A-5 (PTD 225-023) perf sundry Bryan, The estimated reservoir pressure gradient to the deepest perforation intervals in well KLU A-5 prior to drilling and perforating was 0.52 psi/ft. There was uncertainty in this estimate as these particular deeper zones had never had a direct pressure measurement taken in the northern fault block of the Kitchen Lights Unit. The estimate was based on measured pressures in the southern fault block. A electric line deployed pressure survey was run in well A-5 just hours prior to initial perforating to confirm the hydrostatic pressure of the liquid in the wellbore. This pressure survey indicated a 0.47 psi/ft liquid gradient in the wellbore prior to perforating. Two intervals were perforated and the surface pressure remained at zero, indicating something less than a 0.47 psi/ft initial reservoir pressure gradient as opposed to the original estimate of 0.52 psi/ft. The well has been on sustained production for 2-3 weeks. Flowing tubing pressure has declined from around 2000 psi to 300 psi along with a steady decline in gas rate. A slickline drift was performed 8/25/25 to check for fill that might be causing the pressure decline. The slickline drift got to below the 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. 4 bottom perforation and noted a liquid level of 7970 MDBKB. Current estimated reservoir pressure calculations based the slickline determined liquid level and shut in wellhead pressure are below, indicating a 0.21 psi/ft reservoir pressure gradient for the existing perforations as of 8/25/25. The well was shut in for about 8 hours on both 8/25/25 and 8/26/25 and the shut in wellhead pressure built up to ~1100 psi both days, still on a gradually increasing trend. The apparent rapid decline in reservoir pressure for the current perforations is the reason additional perforations are planned to restore rate. Let me know if you would like any of the supporting well service reports, logs, SCADA pressure trends, etc. thanks, Dan 907-529-5818 Well history summary for days of interest: 7/22/2025 Ran GPT Log for BHP/Gradient Data prior to perforating to confirm average equivalent mud weig depth of deepest planned perf interval (3688 psi at 8951 MDBKB, 7 182 TVDBKB, 0.472 psi/ft, 9.1 8973.5'. Pressure before shoot was bled down from 363 psi to 0 psi. After shot, 30 minutes later 66 psi. After shot and 1.5 hours later it was 0 psi. Lack of surface pressure increase after perfora 5 8/25/2025 Drift and Tag on A-5 for planned Production Log. Ran 2.5" x 6' Bailer and tagged obstruction at 70 8983' MD. This is 5' higher than last tag on 8-9-25. Ran 2.5" GR thru obstruction and tagged TD at Continued to TD. Found Fluid Level at 7930' slm, 7970' MD. Found TD again at 8942' 8982' MD. F decline in flowing tubing pressure over 15 day time period. Current reservoir pressure estimate Fluid level at 7970 MDBKB, 6844 TVDBKB is about midway through the perforations Current reservoir pressure based on this fluid level = (0.055 psi/ft x 6844 ft) + 1100 psi shut in tu 1476 psi/ 6844' TVDBKB= 0.21 psi/ ft gradient, 4.1 ppg EMW Original estimated reservoir pressure at 6844 TVDBKB was 3080 psi assuming a 0.45 psi/ft gradi Indicates reservoir pressure decline of 1600 psi after ~15 days of production, ~66 MMSCF cumu 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-5 (PTD 225-023) perf sundry ---------- Forwarded message --------- From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Date: Fri, Aug 29, 2025 at 12:58 Subject: KLU A-5 (PTD 225-023) perf sundry To: Dan Robertson <dbrobertson907@gmail.com>, Hunter Van Wyhe <h.vanwyhe@furiealaska.com> Dan, Hunter, With this style of gas completion, there is a limit to how much TVD of perfs can be open at once because of the risk of shut-in pressure from the deepest set of perfs fracking the shallowest set of perfs. In the case of this well, the shallowest allowable perfs would be approximately 5250’ TVD, based on where the deepest perf interval is and the LOT pressure at the shoe. In order to perf shallower, you will either need to plug some of the deepest perfs or prove that the reservoir pressure in those deepest perfs is depleted. I’m attaching a pore pressure frac gradient analysis that shows how we determine the shallowest allowable perf depths so you can see what I’m looking at. For this well I have a 0.52 psi/ft reservoir pressure gradient for the deepest set of perfs and a 13.9 ppg frac gradient based on LOT at the casing shoe. Furie won’t be permitted to add the requested perf intervals above 5295’ TVD without taking some other action. 6 Let me know if you want to discuss. 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. ***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. 1 From:McLellan, Bryan J (OGC) Sent:Friday, August 29, 2025 1:05 PM To:Hunter Van Wyhe Cc:Dan Robertson; AOGCC Permitting (CED sponsored) Subject:RE: KLU A-5 10-403 Sundry Add Beluga Perforations 08.21.25 Hunter, The reperf intervals mentioned in your email below will be included with the sundry 325-507. I’ll attach this email to the sundry when we issue it for approval. 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, August 29, 2025 11:57 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dan Robertson <d.robertson@furiealaska.com>; AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Subject: Re: KLU A-5 10-403 Sundry Add Beluga Perforations 08.21.25 Bryan, Thank you for the time today. Please direct any questions on the perforating sundries for KLU A-5/A-1A/A-6 to Dan Robertson (cc'd above) and include him on sundry approvals. I will be out next week. As discussed, we may elect to reperforate intervals in KLU A-5 previously approved and added under sundry 325- 358.Please confirm we have approval for the reperforations. Have a great weekend, Hunter Van Wyhe Operations Engineer 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 The linked image cannot be displayed. The file may have been moved, renamed, or deleted. Verify that the link points to the correct file and location. 433 W. 9th Avenue Anchorage AK 99501 Cell: (907) 378-3354 From: Hunter Van Wyhe Sent: Friday, August 22, 2025 11:08 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Subject: KLU A-5 10-403 Sundry Add Beluga Perforations 08.21.25 Good morning, Please see attached 10-403 for adding Beluga perforations to the KLU A-5 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. Thank you, Hunter Van Wyhe Operations Engineer 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 3 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-5 PTD: 225-023 API: 50-733-20734-00-00 Alaska E-Line CBL and Perforation_Logs Data transmitted as .zip file via ZendTo shared with: 225-023 T40768 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 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: 2025.08.13 15:03:43 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KLU A-5 JBR 06/11/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 5" joint. Test Results TEST DATA Rig Rep:Hebert/BoydOperator:Furie Operating Alaska, LLC Operator Rep:Wall/Davis Rig Owner/Rig No.:Hilcorp 151 PTD#:2250230 DATE:5/2/2025 Type Operation:DRILL Annular: 250/2500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopSAM250506195955 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 3901 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"x5-1/2"P #2 Rams 1 Blinds 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 3 3-1/8"/3-1/16 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1850 200 PSI Attained P28 Full Pressure Attained P145 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 PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P15 #1 Rams P12 #2 Rams P12 #3 Rams P12 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9 9999 9 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; Rixse, Melvin G (OGC) Cc:Michael Duncan; Bob Laule Subject:RE: KLU A-5 CBL (PTD 225-023) - Review for Approval to Perforate Date:Tuesday, July 22, 2025 8:55:00 AM Attachments:image002.png Hunter, Furie has approval to proceed with perforations per sundry 225-023. 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: Tuesday, July 22, 2025 7:13 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Michael Duncan <m.duncan@furiealaska.com>; Bob Laule <b.laule@furiealaska.com> Subject: KLU A-5 CBL (PTD 225-023) - Review for Approval to Perforate Importance: High Good morning, See attached CBL for KLU A-5. We will be moving forward with perforating operations today once you have a chance to review and approve. 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. 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-5 PTD: 225-023 API: 50-733-20734-00-00 Geolog Final Data CD 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. 225-023 T40623 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 Received By: Date:Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.26 13:42:08 -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: June 18th, 2025 To: Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: KLU A-5 PTD: 225-023 API: 50-733-20734-00-00 Halliburton LWD Final Data CD 1. CGM 2. Definitive Survey 3. EMF 4. LWD Data 5. PDF 225-023 T40565 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 6. TIFF Folder Structure: Data transmitted as .zip file via ZendTo shared with: 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: 2025.06.18 10:00:59 -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-5 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): 9,310'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 June 25th, 2025 9,290'3,874' 3-1/2" 8,148' Perforation Depth MD (ft): L-80 20" 13-3/8" 346' 9-5/8" 2,931' 5,630' 3-1/2" See attached schematic MD 6,870 psi5,630' 2,931' 346' 2,911' 4,858' 346' Proposed Pools: 8,168' 8,148' 3,621 psi MPSP (psi): TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 389197 225-023Furie 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 50-733-20734-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY 9,290'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 9,290' 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 Hunter Van Wyhe foregoing is true and the procedure proved herein will not be 325-358 By Grace Christianson at 1:26 pm, Jun 12, 2025 BJM 6/16/25 Submit CBL to AOGCC and obtain approval before perforating. 10-407 included with drilling report DSR-6/18/25A.Dewhurst 18JUN25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.20 13:01:49 -08'00'06/20/25 RBDMS JSB 062325 June 12th, 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-5 (PTD 225-023) 10-403 Initial Beluga Perforations Mr. McLellan, Enclosed is the 10-403 for adding initial Beluga per forations to the KLU A-5 well with attached the Wellbore Schematic, Summarized Operations Plan, and table of Proposed Perforations. The KLU A-5 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 be perforated. The well will then be placed on production. Operations are expected to commence approximately June 25 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 See perforation table attached for perforation intervals Perforation Table KLU A-5 MPSP Calculation: Interval: 8,951’-8,972’ MD (7,797’-7,818’ TVD) Estimated Reservoir Pressure at Top Perf: 4,055 psi Gas Gradient (Based on KLU 3 Static Gradient Survey): 0.055 psi/ft MPSP = (4,055 psi – (0.055 * 7,797’ TVD) = 3,621 psi KLU A-5 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 225-023). 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) Thickness (ft) Beluga 7,033 7,055 22 5,904 5,925 21 Beluga 7,239 7,262 23 6,105 6,127 22 Beluga 7,410 7,417 7 6,273 6,280 6.5 Beluga 7,464 7,482 18 6,344 6,326 18 Beluga 7,920 7,932 12 6,777 6,788 11 Beluga 7,947 7,968 21 6,802 6,823 21 Beluga 8,728 8,735 7 7,577 7,584 7 Beluga 8,951 8,972 21 7,797 7,818 21 Total 131 PTD 1 Dewhurst, Andrew D (OGC) From:Guhl, Meredith D (OGC) Sent:Wednesday, 18 June, 2025 07:44 To:Trey Kendrick; Dewhurst, Andrew D (OGC); Hunter Van Wyhe Cc:McLellan, Bryan J (OGC); Gluyas, Gavin R (OGC) Subject:RE: KLU A-5 Perf Sundry (325-358) Trey and Hunter, State OIT does not allow us to accept thumb drives. You may transmit the final log data complement for A-5 using ZendTo to aogcc.data@alaska.gov. The data Andrew needs for the perf sundry is the recorded mode LAS (surface to TD, or each separate run) and the directional survey in excel or text format, which should be small enough to be sent by email. AOGCC email accepts up to 50 MB of data. Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: Trey Kendrick <t.kendrick@furiealaska.com> Sent: Tuesday, June 17, 2025 4:17 PM To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Hunter Van Wyhe <h.vanwyhe@furiealaska.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: RE: KLU A-5 Perf Sundry (325-358) Andrew, For the tops we have the following: A-6 Top Sterling @ 2950 ft MD A-6 Top Beluga @5439 ft MD A-5 Top Sterling @2955 ft MD A-5 Top Beluga @5657 ft MD 2 Let me know if you need anything else. Thanks, Trey From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Tuesday, June 17, 2025 3:56 PM To: Hunter Van Wyhe <h.vanwyhe@furiealaska.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Trey Kendrick <t.kendrick@furiealaska.com> Subject: [EXT] RE: KLU A-5 Perf Sundry (325-358) Hunter, Excellent. If you could fit the requested items in an email, that would help us expedite the sundry review (no need to use ZendTo for this request unless it’s too big for an email). And yes, it will help to include the same information with the A-6 perf sundry. Please continue with the 10-407 process as you described. Thanks, Andy From: Hunter Van Wyhe <h.vanwyhe@furiealaska.com> Sent: Tuesday, 17 June, 2025 15:50 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Trey Kendrick <t.kendrick@furiealaska.com> Subject: Re: KLU A-5 Perf Sundry (325-358) Hi Andrew, Thank you for reaching out. I am currently working on the 10-407 submittal for KLU A-5 and Trey will be working on the data transmittal for the final LWD logs. We can certainly provide the requested information in the meantime for the sundry review. Would you like us to provide the information via a ZendTo submittal? I am also working on the perforating sundry for KLU A-6 as well as the 10-407. We will send the same information in with the perforating sundry for KLU A-6. Hunter Van Wyhe Operations Engineer 433 W. 9th Avenue 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. 3 Anchorage AK 99501 Cell: (907) 378-3354 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Tuesday, June 17, 2025 3:41 PM To: Hunter Van Wyhe <h.vanwyhe@furiealaska.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: [EXT] KLU A-5 Perf Sundry (325-358) Hunter, To help us review the sundry application for KLU A-5, would you please provide field copies of the following: x Directional survey (.txt, .xlsx, etc.) x LWD logs (.las) x A list of formation tops encountered with MD depths Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 ***External Email*** Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. 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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. aaS- 023 I F U Ri„E Date: June 12th, 2025 Hunter Van Wyhe Operations Engineer To: Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: KLU A-5 PTD:225-023 API: 50-733-20734-00-00 Furie Operating Alaska, LLC 19 'N 433 W 9th Avenue, Anchorage, AK 99501 907,277.3726 Email: h.vanwyhe@furiealaska.com Geolog Mud Logging: Washed and Dried Cuttings Set RECEIVED JUN 12 2025 AOGCC 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 Opentw: Ftuie Operating Alaska, LLC Date: WeN Name 1 KLDAl pseWretl By: teb 32025 lab32B-116s Geoft ,IM M: W733.2073600.00 907-561-2465 AK Offue office Lotaeon: Conk Inlet platform hdiu R Received BY: lan set Owner "P9he Boa Quantity Of sample Type Sampting samplehde.l shipping Address Bags ireyuency 1 of 7 _ 30 23W 2 of T 37>A _ 295E 4070 Furie Opeotkc Alaska, LLC 3 of ] 37 37 4C7C 51£0 C 1 cf 1 Washed & 433 W. 9th Ave 4 of 7 37 3-3 c16C 6250 AOG[C W�OMd Anchorage, Al( 5 of7 3i 3C 629E 7400 99s01 6 of 7 3] 30 740c - £510 ATTN: Trey KerMrick ] of i 27 30 ES1C 6310 281-217-IIB4 Total Bmes: 1 7 Appma Weight Each: 313 4S Ibe Total Weight: 32.0 Ms tnn hetardous Please ackrim Received By: and returning one copy of this transmittal. Date: Furie Operating Alaska, LLC 1 433 W 9th Avenue, Anchorage, AK 99501 1907.277.3726 P.I. SupvComm:Rig Coil Tubing Unit? NoRig Contractor Rig RepresentativeOperator Operator RepresentativeWell Permit to Drill # 2250230 Sundry Approval # NAOperation Inspection LocationWorking Pressure, W/H Flange P Pit Fluid Measurement P Working Pressure PP Flow Rate Sensor P Operating Pressure PP Mud Gas Separator P Fluid Level/Condition PP Degasser P Pressure Gauges PP Separator Bypass P Sufficient Valves PP Gas Detectors P Regulator Bypass PP Alarms Separate/Distinct P Actuators (4-way valves) PP Choke/Kill Line Connections PBlind Ram Handle CoverPP Reserve Pits NA Control Panel, Driller PP Trip Tank P Control Panel, Remote PPFirewallPP2 or More Pumps PP Kelly or TD Valves PIndependent Power SupplyPP Floor Safety Valves P N2 Backup PP Driller's Console P Condition of Equipment PPFlow MonitorPFlow Rate Indicator PPit Level Indicators P Valves PPPE P Gauges P Remote Hydraulic Choke PWell Control Trained P Gas Detection Monitor P FOV Upstream of Chokes PHousekeeping P Hydraulic Control Panel P Targeted Turns PWell Control Plan P Kill Sheet Current P Bypass Line PFAILURES:0CORRECT BY:COMMENTSInspection done during initial BOPE test to rated pressure (5000psi). Changes/modifications to the rig since last well work fall 2024: 1) enlarged doghouse; 2) BOP control panel is now touch screen (blind rams takes 2 commands to initiate closure); 3) rig now has the TDS 11 top drive that was previously on the Steelhead platform. No issues noted.CHOKE MANIFOLDJulius R PlatformMUD SYSTEMKLU A-5DrillingCLOSING UNITALASKA OIL AND GAS CONSERVATION COMMISSIONRIG INSPECTION REPORTHCR Valve(s)Manual ValvesAnnular PreventerWorking Pressure, BOP StackStack AnchoredChoke LineKill LineTargeted TurnsPipe RamsBlind RamsHebert/BoydWall/DavisLocking Devices, RamsBOP STACKAustin McLeod5/1/2025INSPECT DATEAOGCC INSPECTORHilcorp 151RidgelineFurie Operating AK, LLCMISCELLANEOUSFlange/Hub ConnectionsDrilling Spool OutletsFlow NippleControl LinesRIG FLOOR2025-0501_Rig_Hilcorp151_KLU_A-5_am rev. 4-19-20239999999Changes/modifications to the rigpenlarged doghousep(BOP control panel is now touch screenTDS 11 top driveggJames B. ReggDigitally signed by James B. Regg Date: 2025.05.16 09:56:01 -08'00' 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 Field, Undefined Sterling and Beluga Gas Pool, KLU A-05 Furie Operating Alaska, LLC Permit to Drill Number: 224-023 Surface Location: 332' FSL, 892' FWL, Sec 24, T10N R11W, Seward Meridian Bottomhole Location: 1614' FSL, 1991' 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. 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 21st day of April 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.21 15:44:51 -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: 9,300' TVD: 8,117' 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- 294330.50 y- 2,536,133.00 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: 56.1 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 2,933' 0' 0' 2,933' 2,914' Intermediate 9.625" 47 #/ft L-80 Buttress 5,412' 0' 0' 5,412' 4,728' Production 3.5" 9.2 #/ft L-80 JFE Lion 4,000' 5300' 9,300' 8,117' 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 See attached program Effect. Depth MD (ft): Effect. Depth TVD (ft): Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Commission Use Only See cover letter for other requirements. Authorized Title: Authorized Signature: Production Liner Intermediate Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 See attached program 3,901 psi 433 W. 9th Avenue, Anchorage AK, 99501 Furie Operating Alaska, LLC 332' FSL, 892' FWL, Sec 24, T10N R11W ADL 389197 2,560 18. Casing Program:Top - Setting Depth - BottomSpecifications 4,347 psi KLU A-5 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 328' FSL, 599' FWL, Sec 24, T10N R11W 1614' FSL, 1991' FEL, Sec 23, T10N, R11W Time v. Depth Plot Drilling Fluid Program Shallow Hazard Analysis 20 AAC 25.050 requirements Conductor/Structural LengthCasing 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 ss 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) Michael Duncan Drilling Manager API N b 3/13/2025 By Grace Christianson at 2:49 pm, Mar 13, 2025 , Seward Meridian SFD BJM 4/21/25 See attached conditions of approval. 8.5" 50-733-20734-00-00 SFD 12.25" DSR-3/24/25SFD 4/7/2025 225-023 16" *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.21 15:45:08 -08'00' 04/21/25 04/21/25 RBDMS JSB 042325 KLU A-5 (PTD 225-023) PĞƌŵŝƚ ƚŽ Dƌŝůů ŽŶĚŝƟŽŶƐ ŽĨ Approval 1. /ŶŝƟal KP ƚĞƐƚ ƚo 5000 pƐŝ. ^ƵďƐĞƋƵĞŶƚ KP ƚĞƐƚ ƚo 4500 pƐŝ. All aŶŶƵlar ƚĞƐƚƐ to 2500 pƐŝ. 2. LKTͬ&/T rĞƐƵltƐ to ďĞ ƐƵďŵŝƩĞĚ to AK' ǁŝtŚŝŶ 24 ŚoƵrƐ oĨ oďtaŝŶŝŶŐ tŚĞ Ěata. 3. 'Ǉro ƐƵrvĞǇƐ ŵƵƐt ďĞ rƵŶ aŌĞr ĚrŝllŝŶŐ ĞvĞrǇ Ε30 Ō ũoŝŶt ƵŶƟl aŶƟ-ĐollŝƐŝoŶ ƐĐaŶ vĞrŝĮĞƐ clearance ĨactorƐ eǆceeĚŝnŐ ĚŝrecƟonal coŵpanǇ ŵŝnŝŵƵŵ paƐƐŝnŐ crŝterŝa. 4. Kne oĨ tŚe ĨolloǁŝnŐ anƟ-collŝƐŝon ŵeaƐƵreƐ ŵƵƐt ďe taŬen ǁŝtŚ reƐpect to KLU A-4͕ ǁŚŝcŚ ĨaŝleĚ tŚe anƟ-collŝƐŝon ŵŝnŝŵƵŵ clearance ǁŝtŚ tŚe planneĚ traũectorǇ oĨ KLU A-5 at 42ϴ Ō DD͗ a. ^et a plƵŐ ŝn tŚe tƵďŝnŐ oĨ ǁell KLU A-4 anĚ Ŭeep ŝt ŝn place ƵnƟl tŚe ďŝt ŝƐ ďeǇonĚ tŚe collŝƐŝon rŝƐŬ͖ or ď. AŌer ĚrŝllŝnŐ to Ε410 Ĩeet͕ tŚe Ěrŝll ƐtrŝnŐ ŵƵƐt ďe pƵlleĚ oƵt oĨ Śole anĚ tŚe ,A laŝĚ Ěoǁn Ɛo a ŐǇro ƐƵrveǇ can ďe rƵn to TD oĨ tŚe ǁell. A ŐǇro ƐƵrveǇ ŵƵƐt tŚen ďe rƵn ŝnƐŝĚe tŚe Ěrŝll ƐtrŝnŐ to ũƵƐt aďove tŚe ďŝt at 410 Ō DD to verŝĨǇ tŚe ĚŝrecƟon oĨ KLU A5 anĚ ǁellďore ƐeparaƟon Ĩroŵ KLU A4 ŝƐ ƐƵĸcŝent to avoŝĚ collŝƐŝon. 5. PreƐƐƵre teƐt ϵ-5ͬϴ͟ caƐŝnŐ to 3500 pƐŝ͕ 50й oĨ caƐŝnŐ ďƵrƐt͕ ďeĨore ĚrŝllŝnŐ oƵt ƐŚoe. 1 March 13, 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-5 Permit to Drill (10-401) Submittal Dear Commissioners, Please see attached application for a permit to drill for well KLU A-5. 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. Drilling operations are expected to commence approximately April 15, 2025. Regards, Michael Duncan Drilling Manager Furie Operating Alaska, LLC Regards, 2 KLU A-5 10-401 Permit to Drill Julius R Platform March 13, 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-5 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................................................................................................................................34 21. KLU A-5 Fluid Program....................................................................................................................35 22. KLU A-5 Directional Program (wp05)..............................................................................................51 23. Cementing Calculations ..................................................................................................................63 4 1. Well Information Well Name KLU A-5 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 9,300’ MD/8,117’ TVD Surface Location (Governmental) 332’ FSL, 892’ FWL, Sec. 24, T10N, R11W, SM Surface Location (NAD 27) X=294330.5, Y=2536133 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 5,417’ 8.5” 3.5” 9.2 3.96” 2.949” 2.867” L-80 JFE LION 5,300 9,300’ **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 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: 2,933’ MD/ 2,800’ TVDss x Top Beluga: 5,398’ MD/ 4,606’ TVDss Note: TVD is from rig floor. RT to MSL (Spartan 151) 114.10’ 6 5. Proposed Wellbore Schematic 6 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-5 will be drilled to 9,300’ 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 366 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 Verified cement calcs -bjm 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 341 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 Cement volumes are inconsistent with calculations on page 64. -bjm Superseded 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. 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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. Verified cement calcs. 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. Logging 3.5" liner. -bjm 16 9. KLU A-5 Pore Pressure/Frac Gradient Estimate 1616166166616161166 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. plot volume or strokes vs. casing pressure. -bjm 20 12.Diverter Information 21 22 13.BOP Schematic 23 14.Choke Manifold Schematic 24 25 15.Tubing Hanger 25 26 16. Wellhead Schematic 26 27 17.Rig Information 2828 29292929292929 30 18.Casing Design Information 00 31 SFD SFD 32 19.Permit to Drill Kick Tolerance Evaluation KLU A-5 surface shoe 2,934 for intermediate shoe @ 5,420' 33 KLU A-5 intermediate shoe 5,420' with 2,934’ surface shoe 34 20.Time vs. Depth 34 35 21.KLU A-5 Fluid Program 3636336666666666633333366663336666666633633633666666666663333666633336666666333666666336666 3737777777777777777777777777777777777777777777777 3838888888888888888888888 39399999999999999999999999999999999999999 404000000000000000000000000000000000000000000 4141 4242444444444444444 4343333333333333333333333333333333333333 444444444444444444444444444444444444444444444 4545555 4646666666666666666 47474474774474447777744444444777774444444444477777777744444444477777777 484888848444444448488888844444444888844444444488884444444448888888 4949 5050555550000000000055555055050000000005555555500000000505555555050000000055550000000 51 22.KLU A-5 Directional Program (wp05) 51 5252555552555555222222225555555222222225555555522222222555555522222225555555 5353 5454 55555555 56565656 5757 58585858 5959 606000000000000000000000000600000000 61611111111111111111111161111111111111111111111161111161611111111111111111 KLU A-4 is a real well. Other failed anit-collisions are with planned wells, not currently drilled, with the exception of KLU A-2 North, which has ellipse overlap by only 0.04 ft. See anti-collision measures in conditions of approval and attached email from Michael Duncan. -bjm 6262 63 23.Cementing Calculations Superseded 1 McLellan, Bryan J (OGC) From:McLellan, Bryan J (OGC) Sent:Monday, April 21, 2025 10:36 AM To:Michael Duncan Cc:Rixse, Melvin G (OGC); Bob Laule; Mike Stefanov Subject:RE: [EXTERNAL] Fw: KLU A-5 Close approach Michael, I will include a condition of approval requiring either a plug in KLU A-4 or requiring the drillstring be pulled and BHA laid down so that the gyro at approximately 410 ft can be run to the depth of the bit, just above TD. 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: Wednesday, April 16, 2025 1:59 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Bob Laule <b.laule@furiealaska.com>; Mike Stefanov <m.stefanov@furiealaska.com> Subject: Re: [EXTERNAL] Fw: KLU A-5 Close approach Bryan - For the A-5 we can run a directional assembly, without the LWD, for the first 450 feet RKB or so. The idea is that with this assembly we would be able to get a gyro within 35 feet of the bit. The first survey of real interest would be when the bit is at 350 feet RKB or so. This survey would give us the orientation of the conductor. We would then drill for two joints, with early sliding, to approximately 410 feet RKB. The survey here would be while the bit is above the critical point for anti-collision. The survey tool will reach 375' RKB. This survey will show the result of the first 20 feet of slide. The expectation is that the orientation would give comfort that we are headed in the right direction. More importantly, we would be looking to make sure that we aren't headed the wrong way because of an unplanned conductor angle or inability to slide effectively. If there are no concerns, and the collision avoidance looked good, we would proceed. If not, we would notify you and sharpen our pencil. 2 As discussed yesterday, we plan to lean on steering just below the 20” Structural pipe to point us away from the well. Assuming this looked good, we would use the practices discussed (watch torque, vibration, cuttings, and the offset A-4 well) and proceed with caution. If there is a concern, we will need to revisit the discussion. Thanks, Michael From: McLellan, Bryan J (OGC) Sent: Tuesday, April 15, 2025 5:15 PM To: Michael Duncan Cc: Rixse, Melvin G (OGC); Bob Laule; Mike Stefanov Subject: [EXT] RE: [EXTERNAL] Fw: KLU A-5 Close approach Michael, Thanks for coming over to discuss the close approach with KLU A4. I have a follow up question. With the Conductor set at 355’ (I think) and the close approach at 428’, the BHA components probably won’t be outside conductor by the time the bit reaches the anti-collision failure at 428’. When you run the gyro, do you plan to POOH, stand back the MWD and run back to bottom so the gyro can reach the drill bit? Please explain the procedure for running the gyro, explaining exactly how deep the gyro will get relative to the bit. Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 3 From: Michael Duncan <m.duncan@furiealaska.com> Sent: Tuesday, April 15, 2025 8:38 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Bob Laule <b.laule@furiealaska.com >; Mike Stefanov <m.stefanov@furiealaska.com> Subject: Re: [EXTERNAL] Fw: KLU A-5 Close approach Bryan - I have a meeting that may spill into the 3:30 time. Could we push it 15-30 minutes? Thank you, Michael From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, April 14, 2025 4:52 PM To: Michael Duncan <m.duncan@furiealaska.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Bob Laule <b.laule@furiealaska.com >; Mike Stefanov <m.stefanov@furiealaska.com> Subject: [EXT] RE: [EXTERNAL] Fw: KLU A-5 Close approach Does 3:30 work for you? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 4 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Michael Duncan <m.duncan@furiealaska.com> Sent: Monday, April 14, 2025 3:57 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Bob Laule <b.laule@furiealaska.com >; Mike Stefanov <m.stefanov@furiealaska.com> Subject: Re: [EXTERNAL] Fw: KLU A-5 Close approach Bryan - We have availability to discuss tomorrow afternoon. What time will work? Here is the data requested 5 6 Cheers, Michael From: McLellan, Bryan J (OGC) Sent: Monday, April 14, 2025 3:16 PM To: Michael Duncan Cc: Rixse, Melvin G (OGC); Bob Laule; Mike Stefanov Subject: [EXT] RE: [EXTERNAL] Fw: KLU A-5 Close approach Michael, 7 Do you have any availability tomorrow to discuss? x What is the current status of A-2 North and A-4? x Do they have signs of sustained casing pressure? x Please send the wellhead pressure (tubing, IA, OA) plots for the past 6 months on these two wells. 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: Monday, April 14, 2025 1:13 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Bob Laule <b.laule@furiealaska.com >; Mike Stefanov <m.stefanov@furiealaska.com> Subject: Re: [EXTERNAL] Fw: KLU A-5 Close approach Bryan - I think we are all set here. Have read things through. When is a good time to discuss this? We have this afternoon open. 8 Thanks, Michael From: McLellan, Bryan J (OGC) Sent: Friday, April 11, 2025 2:15 PM To: Michael Duncan Cc: Rixse, Melvin G (OGC); Bob Laule; Mike Stefanov Subject: [EXT] Re: [EXTERNAL] Fw: KLU A-5 Close approach Michael Have a look at the attached paper and let’s discuss next week wrt KLU A5. Thanks, Bryan Sent from my iPhone On Apr 10, 2025, at 8:40ௗPM, Michael Duncan <m.duncan@furiealaska.com> wrote: Bryan - In discussions with Halliburton, the initial idea as I understand it, was just that another set of data that shows the same path would give even more confidence and verify position. We dont have a reason to question the integrity of the past gyro surverys and believe them sufficient for moving forward. I agree with what you mentioned below; that the best would be to use the same tool for each well. We do have an aversion to shutting in wells right now though. The wells do not 9 have lift and shut in for a gyro would risk losing production. With the rig over the platform we would be even more averse as we would have very limited options to restore a well that is down. You and I spoke briefly about other prudent measures for collision avoidance. Some ones to highlight are below: 1. For the surface hole, a mill-tooth tri-cone bit will be used. This bit does not have side-cutting capability. If the path of the A-5 did encounter that of the A-6 the bit does not have the "teeth" to so to speak to cut into the other well. 2. Where the wells would encounter each other is at the surface casing interval. For the KLU A-4 this interval has 13 3/8" 68# L-80 surface and 9 5/8" 47# L-80 casing. The production casing is cemented to surface. If we were to cut into the well it would take penetration of two strings before compromising the well. Though there are two strings, we wouldnt cut through either. The first indication of collision would be torque issues seen at the motor. We would be watching this constantly. Heaven forbid, if we did cut steel (which we wont), we will have Geolog and PRA wellsite Geos on location watching the returns. We will be looking for cement from the surface casing on the KLU A-4. Ditch magnets will be used and we will be watching for steel. This would be a second indicator of collision that we would see before compromising surface casing of the A-4. I have discussed this with the lead company man (sitting with him now). 3. We discussed this a bit earlier, that Furie plans to slide away from the KLU A-4 from the moment we exit the conductor. Another thing that occurred to me is that if we dont attain the separation from the KLU A-4 that we expect early, we will continue to work towards separation. This would mean that the string would be sliding with the bit pointed away from the KLU A-4 at the times when we are close. This gives me further comfort that all cutting capabilities will be pointed away from the KLU A-4. Please let me know if further information or discussion is needed. This is my top priority and I'll answer the phone at any time. Feel free to call day or night. Thank you again for your efforts to make sure this started the right way. Cheers, Michael Duncan 10 817.240.3865 From: McLellan, Bryan J (OGC) Sent: Thursday, April 10, 2025 5:49 AM To: Michael Duncan; Rixse, Melvin G (OGC) Cc: Bob Laule; Mike Stefanov Subject: [EXT] RE: [EXTERNAL] Fw: KLU A-5 Close approach I think what Halliburton is saying is that if you run new Gyro surveys on those wells using the same gyro tool that is used in KLU A5, it will reduce the positional uncertainty. Can you ask Halliburton about it and let me know what they say? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 <image001.jpg> From: Michael Duncan <m.duncan@furiealaska.com> Sent: Tuesday, April 8, 2025 10:56 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Bob Laule <b.laule@furiealaska.com>; Mike Stefanov <m.stefanov@furiealaska.com> Subject: Fw: [EXTERNAL] Fw: KLU A-5 Close approach Bryan and Mel - 11 Please see the note below. We have gyro surveys for the close approach wells past the depths of concern. Thank you, Michael Duncan From: Benjamin Hand Sent: Tuesday, April 8, 2025 10:52 AM To: Tommie Franklin Renner Cc: Michael Duncan; Bob Laule; Mike Stefanov Subject: [EXT] RE: [EXTERNAL] Fw: KLU A-5 Close approach All, KLU A-4(A) has listed gyro surveys down to ~2000’MD KLU A-2A has gyro surveys down to 600’MD then is MWD surveys on. The survey files used for their surveys are attached. If possible, new Gyro surveys would help prove up the well locations. The AC settings are the standard Halliburton policy of ISCWSA with 2 sigma. It is using the Pedal curve that is still the standard practice. The IPMs are based off of the ISCWSA current set. Screenshot of the current AC settings for Furie. <image004.png> Ben Benjamin Hand Well Designer 12 6900 Arctic Blvd Anchorage, AK 99518 Email: benjamin.hand@halliburton.com Cell: +1 307-460-1901 From: Tommie Franklin Renner <Tommie.Renner@halliburton.com > Sent: Tuesday, April 8, 2025 9:20 AM To: Benjamin Hand <Benjamin.Hand@halliburton.com > Cc: Michael Duncan <m.duncan@furiealaska.com>; Bob Laule <b.laule@furiealaska.com>; Mike Stefanov <m.stefanov@furiealaska.com> Subject: RE: [EXTERNAL] Fw: KLU A-5 Close approach Ben, Can you please verify we have Gyro data on offset wells for Mike. Thanks in advance. From: Michael Duncan <m.duncan@furiealaska.com> Sent: Tuesday, April 8, 2025 8:27 AM To: Tommie Franklin Renner <Tommie.Renner@halliburton.com >; Bob Laule <b.laule@furiealaska.com>; Mike Stefanov <m.stefanov@furiealaska.com> Subject: [EXTERNAL] Fw: KLU A-5 Close approach External Sender: Use caution with links/attachments. Tom - Was a gyro survey done on the other wells? Could you please look at AOGCC questions below? 13 Thank you, Michael From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, April 8, 2025 6:48 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-5 Close approach Michael, What were the survey methods for the offset close approach wells A-2 & A-4, MWD or gyro? The concern is that gyros in your new well may tell you accurately where the new well is, but if the position of the offsets is not precisely known, you might drill into it. Depending on how certain you are of the position of the offsets, we may request a gyro survey be run in those offsets with the same gyro tool you’ll use for KLU A-5. What rules or 3-dimensional probability method do you use for your collision scan? ISCWSA? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 <image001.jpg> 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 14 <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 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 15 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? <image005.png> <image006.png> Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 <image001.jpg> 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 . 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. 16 Michael 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 <image001.jpg> ***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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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:Tuesday, April 8, 2025 8:25 AM To:McLellan, Bryan J (OGC); Rixse, Melvin G (OGC) Cc:Bob Laule; Mike Stefanov Subject:Re: KLU A-5 & A-6 PTD questions Bryan - Yes, the answers below are relevant to both the KLU A-5 and the KLU A-6. There was engineering work done on placement and installation of conductors. But I believe the answer in the spirit of your question is no, there was not an engineering study done on integrating the conductors. The conductors themselves, similar to all past conductors on the platform, are installed within platform guides. The pipe itself is not attached to the platform, just guided. This matches the past 4 wells and the standard for the platform. Thanks, Michael From: McLellan, Bryan J (OGC) Sent: Tuesday, April 8, 2025 6:40 AM To: Michael Duncan; Mike Stefanov Cc: Bob Laule; Rixse, Melvin G (OGC) Subject: [EXT] RE: KLU A-5 & A-6 PTD questions Michael, If all of these questions/answers are relevant to A-6 as well as A-5, I’ll attach to both PTD’s. Please confirm. Also, was there any engineering study done in regards to how the new conductors are integrated with the platform? If so, please send. Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 2 From: Michael Duncan <m.duncan@furiealaska.com> Sent: Friday, April 4, 2025 9:54 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Mike Stefanov <m.stefanov@furiealaska.com> Cc: Bob Laule <b.laule@furiealaska.com> Subject: Re: KLU A-5 PTD questions Bryan - Below are the answers to your questions. A quick thought is that we may have made a vocabulary mistake. Furie first string “ Structural casing” have all met the20 AAC 25.-520 ( c ) (1) Structural casing must be set by driving, jetting, or drilling to a minimum depth of 70 feet in offshore wells to support unconsolidated shallow strata, to provide hole stability for initial drilling operations, and to provide a competent anchor for a diverter system; Our failure is in terminology. Failing in our permit application to differentiate between the terms Structural casing versus Conductor casing as defined in 20 AAC 25.990 (16) “conductor casing” and (68) “structural casing”. We definitely meet the 70' requirement there. Here are the answers to your questions in order: 1. Conductors were driven to refusal using industry standards (100blows per foot) with a pile-driving hammer. 1. All conductors on the Julius R Platform are driven to within 53' of each other. The shallowest is at 114' below mud line, and the deepest is 167' below mud line 1. A diagram of the conductor install is shown below. The new slots are shown in green. For the KLU A-5 we intend to use green slot #2, for KLU a-6 we intend to use the green slot #4 1. The four new conductors are protected from elements as they are installed within the inner caisson. 2. The planned diverter exhaust will stick out from the edge of the platform enough to provide the 75' spacing. We are working with Hilcorp to select which diverter extension is most appropriate to reach this length and have ample support. 3. We have done a sonar scan. The placement looks like no material hazards. We are sending down a diver to make sure. Regards, 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. 3 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, April 2, 2025 4:58 PM To: Michael Duncan <m.duncan@furiealaska.com>; Mike Stefanov <m.stefanov@furiealaska.com> Subject: [EXT] KLU A-5 PTD questions Michael, A few questions about this PTD Application: 1. Please provide the justification for your conductor casing set depth since it is proposed at less than the regulatory requirement of >300’ below mud line. 1. How does it compare to other conductor depths? 2. Please provide platform conductor slot diagram indicating the location of this well relative to other slots on the platfrom. 3. Please provide structural analysis for new conductor’s integration with the platform and protection from the elements. 2. Does the planned diverter exhaust vent have the required 75’ spacing from ignition sources per 20 AAC 25.035(c)(2)(C)? 3. Have you done sonar scan of the sea floor for jackup rig placement? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 4 ***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. 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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:Monday, April 7, 2025 2:54 PM To:McLellan, Bryan J (OGC); Rixse, Melvin G (OGC) Cc:Mike Stefanov; Bob Laule Subject:Fw: KLU A5 cement questions from AOGCC Attachments:CementingCalculations20250405.pdf; ProgramModifications20250405.pdf Bryan and Mel - Thank you for your inquiry. 1. 9-5/8” Cement Job: It is our intent to bring the top of cement up to 2,400’ MD, we have corrected the volumes on the attached pages 12 and 13. The lead slurry should be 197.5 bbls and the tail volume should be 47 bbls. 2. 3-1/2” Liner Cement job: We plan to bring the top of the liner lap up to at least 112’ above the 9-5/8” casing shoe. We have adjusted the cement volume as follows: The lead volume will be 285 bbls and the tail will be 42 bbl. 3. The PTD and program FIT/LOT: We have revised the LOT/FIT procedure on page 19 of the PTD submission to show strokes or volume versus casing pressure see attached pages. Sincerely, Michael Duncan From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, April 3, 2025 2:03 PM To: Michael Duncan <m.duncan@furiealaska.com> Cc: Mike Stefanov <m.stefanov@furiealaska.com> Subject: [EXT] KLU A5 cement questions Michael, A few more minor points to clarify 1. In your 9-5/8” cement plan on page 12 of the PTD, you are planning to pump 341 bbls lead + 48 bbls tail = 389 bbls, but in your calculations at the end of the document, assuming 50% OH excess, you correctly calculate 239 bbls bring cement to 2500’ MD. Can you verify the cement volume, lead and tail, for this hole section? 2. Slight discrepancy: On the PTD form, you show only 112’ of liner lap, but in your cement calcs on the last page, you calculate 150’ ft of liner lap. Please confirm where you plan to set the top of the 3.5” liner? 3. For your FIT procedure, you should plot volume or strokes vs. casing pressure. Your current procedure has you plotting it vs DPP. 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 Thanks again Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 ***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. 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KLU A5 Cementing Calculations:4/5/2025MD RKBTVD RKB20" Shoe Depth40013-3/8" Shoe Depth2933291413-3/8" Shoe Track809-5/8" Shoe Depth541247289-5/8" Shoe Track80Liner Lap Length112Liner Top5300Liner Shoe Depth93008117Liner Shoe Track9013-3/8" cement volumebbl/ftLengthbbl cementDisplacement bblsDisplacement bblsAnnular Volumes 20" X 13-3/8" casing0.154240061.68427.0941366.2234leadspacer5016" OH X 13-3/8" casing0.07492533189.721737.45500' of annulusmud377.0941OH Excess100%189.721737.45427.094113-3/8" shoe track0.14978011.97611.976453.099486.876Tail 453.0994total9-5/8" cement volumebbl/ftLengthbbl cementDisplacement bblsAnnular Volume 13-3/8" X 9-5/8"0.059753331.8201390.3024197.4624leadDisplacement bbls12-1/4 OH X 9-5/8" casing0.05582479138.328227.9500' of annulusspacer50OH Excess50%69.164113.95mud340.30249-5/8" shoe track0.0732805.8565.856390.3024245.168447.706Tail 245.1684total3-1/2" cement volumebbl/ftLengthbbl cementAnnular Volume 9-5/8" X3-1/2"0.06131126.8656282.91984lead150 wo LCM ,followed by 135 with LCM8-1/2" OH X 3-1/2"Liner0.05823888226.281629.1500' of annulusOH Excess40%90.5126411.643-1/2" shoe track0.0087900.7830.783324.4428441.523Tail324.44284Displacement bblsDisplacement bbls5" 19.5 ppf DP cap 0.01776 5300 94.128pick up liner wiper plug @93bblwater 34.017liner volume 0.0087 3910 34.017Bump plug 34 bbls after picking up liner wiper dartspacer 50128.145water44.128128.145 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. Beluga Undefined Gas and Sterling Undefined Gas KLU A-5 225-023 Kitchen Lights WELL PERMIT CHECKLISTCompanyFurie Operating Alaska, LLCWell Name:KLU A-5Initial Class/TypeDEV / PENDGeoArea820Unit11120On/Off ShoreOffProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2250230KITCHEN LIGHTS, STERL UND GAS - 470500 KITCHEN LIGHTS, BLUG UND GNA Note: RBDMS glitch causing this line to print out of order. -bjm17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)No1 Permit fee attachedYes Entire Well lies within ADL0389197.2 Lease number appropriateYes3 Unique well name and numberNo Beluga Undefined, Sterling Undefined4 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 servNA15 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)Yes New installation of conductors on platform. See attached emails.18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes Approximately 433' of planned cemented 9-5/8" x 13-3/8" annulus.21 CMT vol adequate to tie-in long string to surf csgYes All OH x casing annuli will be entirely cemented.22 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 approvedNo Close approach to KLU A4 addressed with gyros run every 30' from conductor shoe until clearance factor passes.26 Adequate wellbore separation proposedYes Diverter exhaust will be far enough from ignition sources per attached email from Michael Duncan.27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP = 3901 psi. 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)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 None expected based on nearby wells.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 zonesNA (5.4 to 10.8 ppg EMW). Operator's planned mud program appears sufficient to control37 Seismic analysis of shallow gas zonesNA anticipated pressures and maintain wellbore stability.38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate4/7/2025ApprBJMDate4/21/2025ApprSFDDate4/7/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 4/21/2025