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Home My WebLink About224-103 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-1A PTD: 224-103 API: 50-733-20656-01-00 Alaska E-Line Perforating Logs 1. Correlation Pass (.las) 2. Correlation Pass (.pdf) 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: 224-103 T40935 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.02 14:47:23 -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-1A 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): 8,817'N/A Casing Collapse Structural Conductor 2510 psi Surface 2,670 psi Intermediate Production 6,620 psi Liner 10,540 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: Contact Email: Contact Phone: 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. Hunter Van Wyhe (907) 378-3354 September 3rd, 2025 8,816'4,851' 3-1/2" MD 1,906' 386' 2,172' Perforation Depth MD (ft): 9-5/8" 2,172' 384' 7,431' 20" 13-3/8" 386' CO 724 7,431' 7,348' 1,879 psi MPSP (psi): Plugs (MD): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 389197, 389198 224-103Furie Operating Alaska, LLC Will perfs require a spacing exception due to property boundaries? Current Pools: Proposed Pools: AOGCC USE ONLY 10,160 psi Perforation Depth TVD (ft): See attached schematic Operations Engineer L-80 Subsequent Form Required: Suspension Expiration Date: 433 W. 9th Avenue, Anchorage, AK 99502 50-733-20656-01-00 Tubing Size: PRESENT WELL CONDITION SUMMARY 8,721'N/A 1500 psi Kitchen Lights Unit Length Size 3,240'4,100' Burst 8,816' MD TVD 7,930 psi 5380 psi Authorized Name and Digital Signature with Date: Tubing Grade: Tubing MD (ft): h.vanwyhe@furiealaska.com 4100' 3-1/2" See attached schematic 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 iEi 08/21/2025 325-506 By Grace Christianson at 12:18 pm, Aug 22, 2025 10-404 SFD 8/27/2025BJM 9/3/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.04 08:16:58 -08'00'09/04/25 RBDMS JSB 090425 August 21st, 2025 Bryan McLellan Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Furie Operating Alaska KLU A-1A (PTD 224-103) 10-403 Add Beluga Perforations Mr. McLellan, Enclosed is a 10-403 sundry for adding Beluga perforations to the KLU A-1A well with attached 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 Perforation TablePerforation Table See perforation table attached for proposed perforation interval Formation Top MD ft Base MD ft Length MD ft Top TVD ft Base TVD ft Beluga 6053 6073 20 5009 5026 Total:20 KLU A-1A Perforation Procedure Summary 1. Ensure SCSSV is open, blocked in. 2. Rig up Eline. Pressure test PCE to 250 psi low and 2,500 psi high. 3. RIH perforate Beluga interval. 4. RD Eline equipment. Turn well over to production. KLU A-1A MPSP Calculation: Interval: 6,053’-6,073’ MD (5,009’-5,026’ TVD) Estimated Reservoir Pressure at Top Perf: 2,154 psi Gas Gradient (Based on KLU 3 Static Gradient Survey): 0.055 psi/ft MPSP = (2,154 psi – (0.055 * 5,009’ TVD) = 1,879 psi 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 5:21 PM To:McLellan, Bryan J (OGC) Cc:Hunter Van Wyhe; Trey Kendrick Subject:Fw: [EXT] Fwd: KLU A-1A (PTD 224-103) Shallowest allowable perf Attachments:KLU A-1A Current Wellbore Schematic 041525.pdf Bryan, On 11/21/24 the deepest interval in well A-1a was perforated (8450-8560 MDBKB, 7100 TVDBKB to top perf). A electric line pressure survey indicated 3655 psi at this depth, or 0.515 psi/ft, 9.9 ppg EMW hours after perforating (log image below). These were the only perforations in the well until April 2025. Twelve additional perforation intervals were added 4/5-9/25. Shut in tubing pressure just prior to adding perforations indicated the reservoir pressure of the initial perforation interval 8450-8460 MD had declined to 1750 psi, 0.25 psi/ft, 4.7 ppg EMW. The 12 additional perforation intervals were incapable of natural flow after they were completed. Some seawater was pumped during the perforating to help manage underbalance, and the add perf intervals turned out to be producing 90 bwpd i.e. it was loaded up when perforating was completed. The inability to flow with 8.5 ppg water in the wellbore indicates less than an 8.5 ppg EMW reservoir pressure for the added perforation intervals. Gas lift valves were installed, used to unload the well and establish natural flow. Some relevant points in well history are pasted in below. Let me know if any additional information or supporting data is needed. Thanks, Dan 11/21/24 A-1a Pressure Temperature Survey After initial perforation interval: CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 3 4 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-1A (PTD 224-103) Shallowest allowable perf ---------- Forwarded message --------- From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Date: Fri, Aug 29, 2025 at 13:14 Subject: KLU A-1A (PTD 224-103) Shallowest allowable perf To: Dan Robertson <dbrobertson907@gmail.com>, Hunter Van Wyhe <h.vanwyhe@furiealaska.com> Dan, Hunter, Same issue for this well as for KLU A-5. The perfs Furie is requesting are above the shallowest allowable. Need to either plug deepest perfs or prove they are depleted before opening perfs requested in the sundry application. 5 Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 6 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. 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. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Furie Operating Alaska, LLC Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,817 feet N/A feet true vertical 7,431 feet N/A feet Effective Depth measured 8,721 feet 3,965 feet true vertical 7,348 feet 3,130 feet Perforation depth Measured depth See attached feet True Vertical depth See attached feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 3,965' MD 3,130' TVD Packers and SSSV (type, measured and true vertical depth) See attached well diagram 447' MD 445' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Kitchen Lights Unit: Beluga Undefined Gas Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Hunter Van Wyhe Contact Name:Hunter Van Wyhe Contact Email:h.vanwyhe@furiealaska.com Authorized Title: Operations Engineer Contact Phone: Production Liner 4,100' 4,851' Casing Structural 3,240' 3-1/2" 4,100' 8,816' 7,431' 2172' 1,906' 20" 13 3/8" Size 10,160 psi 9 5/8"6,620 psi 1,500 psi 5,380 psi 7,930 psi measured TVD Plugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 224-103 50-733-20656-01-00433 W. 9th Avenue, Anchorage AK 995013. Address: KLU A-1A MD Burst Collapse measured true vertical Packer GR Perforating Logs and GPT Log submitted. See Data Transmittal 04/18/2025. 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 389197, 389198 Kitchen Lights Unit: Sterling & Beluga Undefined Gas Pools Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 12240 Length 386' 2,172' 386'Conductor Surface Intermediate 2,510 psi 2,670 psi 384' 325-081 and 325-209 Sr Pet Eng: 10,540 psi Sr Pet Geo: Sr Res Eng: WINJ WAG 3149 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. (907) 378-3354 Gas-Mcf 40 IA/OA: 810/5 psi3573 1047 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 IA/OA: 2100/5 psi p k ft t Fra O s O 224 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Sr Pet Geo: C C ect to the best of my knowledge. By Grace Christianson at 10:01 am, Apr 25, 2025 BJM 6/26/25 RBDMS JSB 050125 DSR-4/29/25 Furie Operating Alaska, LLC | 433 W 9 th Avenue, Anchorage, AK 99501 | 907.277.3726 April 24, 2024 Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Furie Operating Alaska KLU A-1A (PTD 224-103) Add Beluga Perforations 10-404 Sundry TO WHOM IT MAY CONCERN, Furie Operating Alaska (Furie) submits this completed 10-404 sundry for additional Beluga perforations to the KLU A-1A wellbore previously submitted and approved in AOGCC 10-403 sundries 325-081 and 325-209. The perforation intervals added are listed below; x 6,512-6,526’ MD (5,400-5,412' TVD)(Beluga) added 4/9/2025 x 6,648-6,662’ MD (5,517-5,529' TVD)(Beluga) added 4/9/2025 x 6,702-6,712’ MD (5,563-5,572' TVD)(Beluga) added 4/9/2025 x 7,053-7,067’ MD (5,869-5,881' TVD)(Beluga) added 4/9/2025 x 7,183-7,193’ MD (5,983-5,992' TVD)(Beluga) added 4/8/2025 x 7,223-7,233’ MD (6,018-6,026' TVD)(Beluga) added 4/9/2025 x 7,239-7,246’ MD (6,033-6,039' TVD)(Beluga) added 4/8/2025 x 7,480-7,486’ MD (6,243-6,248' TVD)(Beluga) added 4/5/2025 x 7,655-7,661’ MD (6,395-6,400' TVD)(Beluga) added 4/6/2025 x 7,822-7,832’ MD (6,540-6,549' TVD)(Beluga) added 4/6/2025 x 8,100-8,110’ MD (6,785-6,794' TVD)(Beluga) added 4/6/2025 x 8,347-8,357’ MD (7,007-7,016' TVD)(Beluga) added 4/7/2025 Enclosed is an updated wellbore schematic and daily operations summary. If you have any questions or require further information, please contact me at (907) 378-3354. 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MU gun #2 (6' X 2-3/8"). Stab on / MU for PT. Pressure test to 3,500/250 psi. Good test. RIH gun #2 (CCL-TS=15.2'). Correlate and spot on depth. Shoot interval #2 from 7,655'-7,661' MD. OOH. MU gun #3 (10' X 2-3/8"). RIH gun #3 (CCL-TS=15.2'). Correlate and spot on depth. Shoot interval #3 from 7,822'-7,823' MD. OOH. MU gun #4 (10' X 2-3/8"). RIH gun #4 (CCL-TS=15.2'). Correlate and spot on depth. Shoot interval #4 from 8,100'-8,110' MD. OOH. LDFN. PJSM. MU gun #5 (10' X 2-3/8"). Stab on / MU for PT. Pressure test to 3,500/250 psi. Good test. RIH gun #5 (CCL-TS=15.2'). Correlate and spot on depth. Shoot interval #5 from 8,347'-8,357' MD. OOH. Attempt to bring well online. Rig up and run GPT log to acquire BHT and fluid level data. Decision made to add more perforation intervals. LDFN and wait on additional guns. Additional intervals covered under 10-403 sundry 325-209. PJSM. Mobilize additional guns to location. MU gun #6 (10' X 2-3/8"). Stab on / MU for PT. Pressure test to 3,500/250 psi. Good test. RIH gun #6 (CCL-TS=13.2'). Correlate and spot on depth. Shoot interval #6 from 7,183'-7,193' MD. OOH. MU gun #7 (7' X 2-3/8"). RIH gun #7 (CCL- TS=13.2'). Correlate and spot on depth. Shoot interval #7 from 7,239'-7,246' MD. OOH. LDFN. PJSM. MU gun #8 (10' X 2-3/8"). Stab on / MU for PT. Pressure test to 3,500/250 psi. Good test. RIH gun #8 (CCL-TS=13.2'). Correlate and spot on depth. Shoot interval #8 from 7,223'-7,233' MD. OOH. MU gun #9 (14' X 2-3/8"). RIH gun #9 (CCL-TS=13.2'). Correlate and spot on depth. Shoot interval #9 from 7,053'-7,067' MD. OOH. MU gun #10 (10' X 2-3/8"). RIH gun #10 (CCL-TS=13.2'). Correlate and spot on depth. Shoot interval #10 from 6,702'-6,712' MD. OOH. MU gun #11 (14' X 2-3/8"). RIH gun #11 (CCL-TS=13.2'). Correlate and spot on depth. Shoot interval #11 from 6,648'-6,662' MD. OOH. MU gun #12 (14' X 2-3/8"). RIH gun #12 (CCL-TS=13.2'). Correlate and spot on depth. Shoot interval #12 from 6,512'-6,526' MD. OOH. Rig down E-Line. SUMMARY Perforations added under 10-403 sundry 325-081. PJSM. Adjust wellhead pressure to 1,250 psi to achieve 300 psi underbalance. Note: decision made to shoot top down to avoid excessive underbalance while perforating. MU gun #1 (6' X 2-3/8"). Stab on / MU for PT. Pressure test to 3,000/250 psi. Good test. RIH gun #1 (CCL-TS=15.2'). Correlate and spot on depth. Shoot interval #1 from 7,480'-7,486' MD. OOH. LDFN. 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: April 24th, 2025 To: Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: KLU A-1A PTD: 224-103 API: 50-733-20656-01-00 Alaska E-Line Perforating Logs 1. GPT Survey (.LAS) 2. Correlation Pass 1-12 (.LAS) 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: 224-103 T40340 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.28 08:57:39 -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-1A 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): 8,817'N/A Casing Collapse Structural Conductor 2510 psi Surface 2,670 psi Intermediate Production 6,620 psi Liner 10,540 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: Contact Email: Contact Phone: 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 Perforation Depth MD (ft): 9-5/8" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Hunter Van Wyhe (907) 378-3354 April 8th, 2025 8,816'4,851' 3-1/2" 7,431' 20" 13-3/8" 386' MD L-80 4100' 3-1/2" See attached schematic 2,172' 384' 1,906' 386' 2,172' Proposed Pools: CO 724 7,431' 7,348' 2,371 psi MPSP (psi): Plugs (MD): TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 389197, 389198 224-103Furie 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 8,816' MD Subsequent Form Required: Suspension Expiration Date: 433 W. 9th Avenue, Anchorage, AK 99502 50-733-20656-01-00 Tubing Size: PRESENT WELL CONDITION SUMMARY 8,721'N/A 1500 psi 5380 psi Authorized Name and Digital Signature with Date: Tubing Grade: Tubing MD (ft): h.vanwyhe@furiealaska.com Length Size 3,240'4,100' Burst 7,930 psi 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 ti E i 325-209 By Grace Christianson at 1:11 pm, Apr 07, 2025 SFD 4/7/2025 Apr 07, 2025 DSR-4/7/25VTL 4/7/2025 10-407 RUSH SFD Shallowest perf allowable under this sundry is 6257' MD/5200' TVD. April 8th, 2025 Perforate *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.07 15:20:17 -08'00'04/07/25 RBDMS JSB 040825 April 7th, 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-1A (PTD 224-103) 10-403 Re-approval - Add Beluga Perforations Mr. McLellan, Enclosed is a 10-403 sundry for adding Beluga perforations to the KLU A-1A well with attached wellbore schematic, summarized operations plan, and table of proposed perforations. These proposed perforations were previously approved under 10-403 Sundry 324-625. A copy of the approved Sundry is attached for reference. The KLU A-1A well was drilled in October 2024. Following drilling activities, one Beluga perforation was added from 8,449.5’-8,459.5’ MD. Five additional perforation intervals were added between 4/5/2025- 4/7/2025. It is desired to continue adding perforation intervals to the well while equipment is still mobilized on the platform. Operations are expected to commence approximately April 8th, 2025. If you have questions, please feel free to contact me at 907-378-3354. Hunter Van Wyhe Operations Engineer Furie Operating Alaska, LLC adding Beluga perforations Current Wellbore Schematic See perforation table attached for perforation intervals See pepeepepepeeepppepppppepppppppppeeeeeeeeppppppppeeeeeeeepeeeeeepepppeeppeeppppppeeeeeeepppeeeeeeppeeeerfrrrrrfffffrrrrrrrffffffrrrrffffffrrffffffffrrrrrfffrffrrrrrrfffffrffrrffffffrrrrrfffffffrrrfforoooooroooooooorooooooooooorrrrrroroooooooorrrrrrrrooorrrrrorrooooorroorrorooorrrrrooorrrooooooorrataaataaaaaaaaaataaaaaaaaaaaaattttttttaaaaaataatttttttttaaaaaatttttttttaatatattttttattttttaattttttttattttttaaaaatttttttttioooiooooioioooooiooooioiiiiiiooooooooooiooiiiiiiooooooooooiooioioooooooiiioooiiiiooooooiiiioooooooooooiiioooooooooiioooooooooonnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnn tatttatatattaaaaaaaatttattaaaaaaaaaatttttaaaaaaaaattttaaaaaaaatatatttaaaaaaaataaaaaaaataaaaaattttaaaaaaaaaattaaaaaaattttaaaaaaablbbbbbbbbbbbblbbbbbbbbblbbbbbbblbbbbbbbbbbbbbbbbllllbbbbbbbbbbbbbbbbbbbbbbbbe eeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee atattttttataaaaaaaaatttttaaaaaaaaaatttttaaaaaaattaaaaataaaaataaatattataaaatataattttattaaaaaaaatttttaaaattttaaattttatatttataaaataaaaatttttaaataaaataatataaaaaaaataaaaaaaaatttttaaaaaattttaaaaattaaaatttaaaattaaataaachccchchcchcchchccchhhhhhchcchchccchhhhhhccchccchhhhhhcccccchhhcchccchhhchhhhhhhhhhhhhccccchhhhhhhhhhccccchhhhhhhccchhhhhhhhhhhededddeddedeeededeeededededdddeeededeeeddededdddeeedeeeeddddddeeedeeeeeeddddddeeeeeeeedddeeeeeedddddeeedddddeeeeeeedddddeeddeed ffffffffffffffffffffffffffffffffffffffffffffffffffffffffffffffffffforooooororororrorrrooooororororrorrrooorrrooorrrorororrrrororororrororroooooororororrrrrorooooororororrooorororroo perforatatatattttatttttttttttttttttttttttaatttttttttiiiioiiiiiiiiiiioiiiiiiioiiiiooooooooooonnnnn n iiiiniiniiiiiniiniiiiiiiiinnnnnnnnnnntettetttetttttttttttttttttttetetettteeeeeerrvrrrrvvvvvvvvvalalaalallllllllllalallllllllllllaaaaaaasssss Perforation Table Formation Top MD ft Base MD ft Length MD ft Top TVD ft Base TVD ft Beluga 6481 6490 9 5374 5382 Beluga 6518 6533 15 5406 5418 Beluga 6595 6605 10 5471 5480 Beluga 6653 6674 21 5521 5539 Beluga 6708 6719 11 5568 5578 Beluga 6794 6800 6 5642 5648 Beluga 6825 6832 7 5669 5675 Beluga 6972 6977 5 5798 5802 Beluga 7057 7073 16 5872 5886 Beluga 7188 7198 10 5988 5996 Beluga 7228 7244 16 6023 6037 Beluga 7246 7250 4 6039 6042 Beluga 7271 7285 14 6061 6073 Beluga 7381 7386 5 6157 6161 Total:149 KLU A-1A Perforation Procedure Summary 1. Ensure SCSSV is open, blocked in. 2. Rig up Eline. Pressure test PCE to 250 psi low and 3,000 psi high. 3. RIH perforate Beluga intervals. 4. RD Eline equipment. Turn well over to production. KLU A-1A MPSP Calculation: Interval: 7,381’-7,386’ MD (6,157’-6,161’ TVD) Estimated Reservoir Pressure at Top Perf: 2,709 psi Gas Gradient (Based on KLU 3 Static Gradient Survey): 0.055 psi/ft MPSP = (2,709 psi – (0.055 * 6,157’ TVD) = 2,371 psi 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-1A 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): 8,817'N/A Casing Collapse Structural Conductor 2510 psi Surface 2,670 psi Intermediate Production 6,620 psi Liner 10,540 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: Contact Email: Contact Phone: 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. Hunter Van Wyhe (907) 378-3354 0DUFK 1VW, 2025 8,816'4,851' 3-1/2" 7,431' Perforation Depth MD (ft): L-80 4100' 3-1/2" See attached schematic 9-5/8" 20" 13-3/8" 386' MD 2,172' 384' 1,906' 386' 2,172' Proposed Pools: CO 724 7,431' 7,348' 3,083 psi MPSP (psi): Plugs (MD): TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 389197, 389198 224-103Furie 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 8,816' MD Subsequent Form Required: Suspension Expiration Date: 433 W. 9th Avenue, Anchorage, AK 99502 50-733-20656-01-00 Tubing Size: PRESENT WELL CONDITION SUMMARY 8,721'N/A 1500 psi 5380 psi Authorized Name and Digital Signature with Date: Tubing Grade: Tubing MD (ft): h.vanwyhe@furiealaska.com Length Size 3,240'4,100' Burst 7,930 psi 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 325-081 By Gavin Gluyas at 8:48 am, Feb 18, 2025 BJM 2/26/25 Perforate SFD 2/26/2025 10-404 DSR-2/18/25*&: 2/27/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.27 09:28:29 -09'00' RBDMS JSB 022725 February 12th, 2024 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-1A (PTD 224-103) 10-403 ĚĚ Beluga Perforations Mr. McLellan, Enclosed is a 10-403 sundry for adding Beluga perforations to the KLU A-1A well with attached wellbore schematic, summarized operations plan, and table of proposed perforations. The KLU A-1A well was drilled in October 2024. Following drilling activities, one Beluga perforation was added from 8,449.5’-8,459.5’ MD. It is planned to add two additional Beluga perforations from 8,346’- 8357’ MD and 8,100’-8,111’ MD. Operations are expected to commence approximately DĂƌĐŚ 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 Formation Top MD ft Base MD ft Top TVD ft Base TVD ft Length MD ft Beluga 8100 8111 6785 6795 11 Beluga 8346 8357 7006 7016 11 Totals:22 KLU A-1A Perforation Procedure Summary 1. Ensure SCSSV is open, blocked in. 2. Rig up Slickline. Pressure test PCE to 250 psi low and 3500 psi high. a. (Note: PCE must be tested each time it is broken apart.) 3. PU/MU Dummy gun assy on Slickline. RIH to PBTD at 8,721'. POOH. RD Slickline. 4. Rig up Eline. Pressure test PCE to 250 psi low and 3500 psi high. a. (Note: PCE must be tested each time it is broken apart.) 5. RIH perforate Beluga intervals. 6. RD Eline equipment. Turn well over to production. See additional perf intervals requested by Hunter Van Whye 2/26/25 email attached. -bjm 1 Gluyas, Gavin R (OGC) From:Hunter Van Wyhe <h.vanwyhe@furiealaska.com> Sent:Wednesday, February 26, 2025 11:15 AM To:McLellan, Bryan J (OGC) Subject:Re: KLU A-1A (PTD 224-103) perf sundry Bryan, See below MPSP calculations for KLU A-1A. Also included are the revised perforation intervals for the sundry. KLU A-1A MPSP Calculation: Interval: 8,346’-8,357’ MD (7,006’-7,016’ TVD) Estimated Reservoir Pressure at Top Perf: 3,468 psi Gas Gradient (Based on KLU 3 Static Gradient Survey): 0.055 psi/ft MPSP = (3,468 psi – (0.055 * 7,006’ TVD) = 3,083 psi Revised KLU A-1A Perforation Intervals 02/26/2025: Formation Top MD ft Base MD ft Top TVD ft Base TVD ft Length MD ft Beluga 7482 7489 6245 6251 7 Beluga 7657 7663 6396 6402 6 Beluga 7825 7835 6542 6551 10 Beluga 8100 8111 6785 6795 11 Beluga 8346 8357 7006 7016 11 Totals: 45 Thank you for the help, Hunter Van Wyhe Operations Engineer 433 W. 9th Avenue Anchorage AK 99501 Cell: (907) 378-3354 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, February 24, 2025 1:40 PM To: Hunter Van Wyhe <h.vanwyhe@furiealaska.com> Subject: [EXT] KLU A-1A (PTD 224-103) perf sundry Hunter, Please send your basis for calculating MPSP in the sundry application. Reservoir pressure @ TVD, minus 0.1 psi/ft gas gradient. Thanks 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. 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. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Furie Operating Alaska, LLC Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9.Logs (List logs and submit electronic data per 20AAC25.071): 10.Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,817 feet N/A feet true vertical 7,431 feet N/A feet Effective Depth measured 8,721 feet 3,965 feet true vertical 7,348 feet 3,130 feet Perforation depth Measured depth 8,449.5-8,459.5 feet True Vertical depth 7,100-7,107 feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 3,965' MD 3,130' TVD Packers and SSSV (type, measured and true vertical depth) See attached well diagram 447' MD 445' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Kitchen Lights Unit: Beluga Undefined Gas Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Hunter Van Wyhe Contact Name:Hunter Van Wyhe Contact Email:h.vanwyhe@furiealaska.com Authorized Title: Operations Engineer Contact Phone: Production Liner 4,100' 4,851' Casing Structural 3,240' 3-1/2" 4,100' 8,816' 7,431' 2172' 1,906' 20" 13 3/8" Size 10,160 psi 9 5/8"6,620 psi 1,500 psi 5,380 psi 7,930 psi measured TVD Plugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 224-103 50-733-20656-01-00433 W. 9th Avenue, Anchorage AK 995013. Address: KLU A-1A MD Burst Collapse measured true vertical Packer GR Perforating Logs and GPT Log submitted. See Data Transmittal 12/12/2024. 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 389197, 389198 Kitchen Lights Unit: Sterling & Beluga Undefined Gas Pools Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure Length 386' 2,172' 386'Conductor Surface Intermediate 2,510 psi 2,670 psi 384' 324-625 Sr Pet Eng: 10,540 psi Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. (907) 378-3354 Gas-Mcf 0 IA/OA: 1775/5 psi2500 2527 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 p k ft t Fra O s O 224 6.A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov C ect to the best of my knowledge. Sr Pet Geo: By Grace Christianson at 10:20 am, Jan 15, 2025 BJM 2/5/25 RBDMS JSB 011625 DSR-1/16/25SFD 2/8/2025 Perforate Furie Operating Alaska, LLC | 433 W 9 th Avenue, Anchorage, AK 99501 | 907.277.3726 January 1ϱ, 2024 Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Furie Operating Alaska KLU A-1A (PTD 224-103) Add Beluga Perforations 10-404 Sundry TO WHOM IT MAY CONCERN, Furie Operating Alaska (Furie) submits this completed 10-404 sundry for additional Beluga perforations to the KLU A-4 wellbore previously submitted and approved in AOGCC 10-403 sundry 324-625. The perforation intervals added are listed below; x 8,449.5-8,459.5MD (7,100-7,107' TVD) Enclosed is an updated wellbore schematic and daily operations summary. If you have any questions or require further information, please contact me at (907) 378-3354. Sincerely, Hunter Van Wyhe Operations Engineer Furie Operating Alaska, LLC ^^^s /D &ƵƌŝĞKƉĞƌĂƚŝŶŐůĂƐŬĂ <ŝƚĐŚĞŶ>ŝŐŚƚƐhŶŝƚͲϭ ϭϬͲϰϬϰ^ƵŶĚƌǇ^ĐŚĞŵĂƚŝĐ ϯ͘ϱΗ&ƌŽŶƚŝĞƌůĂŶĚŝŶŐĐŽůůĂƌϴ͕ϳϮϬΖD< ϯ͘ϱ:ϵ͘Ϯ<>ͲϴϬ:&>ŝŽŶ;ϴ1ϴϭϲ9D KƉĞŶ,ŽůĞ3ϴ͕ϴϭϳΖ ͕ϳ͕ϯϭϳΖds^^͕ϳ͕ϰϯϭΖds< ϭϮͬϭϯͬϮϬϮϰ ϮϬΗϬ͘ϴϭϮΗĂƚϯϴϲΖDͬϯϴϰΖds;ϭϴϭΖWĞŶĞƚƌĂƚŝŽŶͿ ϭϮƉƉŐ>ŝƚĞĐƌĞƚĞdKΛϭ͕ϱϵϬΖDŝŶϵͲϱͬϴΗǆϭϯͲϯͬϴΗĂŶŶƵůƵƐ ϭϯͲϯͬϴΗϳϮη>ͲϴϬΛϮ͕ϭϳϮΖDͬϭ͕ϵϬϲΖds'>D '>D '>D '>D A4ϴ@B:Ăƚϯ͕ϵϬϲΖD >ŝŶĞƌdŽƉWĂĐŬĞƌƐĞƚĂƚϯ͕ϵϲϱΖD ϯͲϭͬϮΗϵ͘ϮΗ>ͲϴϬ:&>ŝŽŶ͕ǁŝƚŚƐĞĂůĂƐƐĞŵďůǇďĞůŽǁƚŚŝƐ ŝŶƐĞƌƚĞĚŝŶƉĂĐŬĞƌƐĞĂůďŽƌĞ͕ŵƵůĞƐŚŽĞ ϵͲϱͬϴΗϱϯ͘ϱη>ͲϴϬΛϰ͕ϭϬϬΖD ĂŬĞƌ^Ͳϱy^^^sƐĞƚĂƚϰϰϳΖD͘ ^ͬE͗ϭϬϴϰϳϴϲϱϴͲϬϭ͘ϱ͕ϬϬϬƉƐŝǁŽƌŬŝŶŐƉƌĞƐƐƵƌĞ͘ KƉĞŶŝŶŐƉƌĞƐƐƵƌĞĂƚ^^^sсϭ͕ϴϬϬƉƐŝн^/dW ĞůƵŐĂWĞƌĨŽƌĂƚŝŽŶϴ͕ϰϰϵ͘ϱͲϴϰϱϵ͘ϱΖD;ϳ͕ϭϬϬΖͲϳ͕ϭϬϳΖdsͿ ĚĚĞĚϭϭͬϮϭͬϮϬϮϰϮͲϯͬϴΗZyŐƵŶ͕ϭϭŐƌĂŵ͕ϱ^W&͘ 111/21/2024SUMMARYPJSM. MU gun #1 (10' X 2-3/8"). Stab on / MU for PT. Pressure test to 3500/250. Good test. RIH gun #1 (CCL-TS=9.7'). Correlate and spot on depth. Shoot interval #1 from 8,449.5'-8,459.5' MD. OOH. MU GPT and log from surface to TD. OOH. Rig down E-line. AOGCC Sundry 324-625Daily Well Work Summaries for KLU# A-1ADATEDAY Hunter Van Wyhe Furie Operating Alaska, LLC Operations Engineer 433 W 9th Avenue, Anchorage, AK 99501 907.277.3726 Email: h.vanwyhe@furiealaska.com Furie Operating Alaska, LLC | 433 W 9th Avenue, Anchorage, AK 99501 | 907.277.3726 Date: Dec 12th, 2024 To: Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: KLU A-1A PTD: 224-103 API: 50-733-20656-01-00 Geolog Mud Log Final Data CD 1. Daily Reports 2. Final Well Report 3. LAS Data 4. Log PDF’s 224-103 T39860 Hunter Van Wyhe Furie Operating Alaska, LLC Operations Engineer 433 W 9th Avenue, Anchorage, AK 99501 907.277.3726 Email: h.vanwyhe@furiealaska.com Furie Operating Alaska, LLC | 433 W 9th Avenue, Anchorage, AK 99501 | 907.277.3726 5. LOG TIFFs 6. Sample Photo 7. Show Reports Hunter Van Wyhe Furie Operating Alaska, LLC Operations Engineer 433 W 9th Avenue, Anchorage, AK 99501 907.277.3726 Email: h.vanwyhe@furiealaska.com Furie Operating Alaska, LLC | 433 W 9th Avenue, Anchorage, AK 99501 | 907.277.3726 Halliburton LWD Final Data CD 1. CGM 2. Definitive Survey 3. EMF 4. LWD Data Hunter Van Wyhe Furie Operating Alaska, LLC Operations Engineer 433 W 9th Avenue, Anchorage, AK 99501 907.277.3726 Email: h.vanwyhe@furiealaska.com Furie Operating Alaska, LLC | 433 W 9th Avenue, Anchorage, AK 99501 | 907.277.3726 5. PDF 6. TIFF Alaska E-Line CBL Final Data CD Alaska E-Line Perforating Logs 1. Correlation Pass (.PDF and .LAS) 2. Post Gun Pressure/Temperature Survey (.PDF and .LAS) Folder Structure: Hunter Van Wyhe Furie Operating Alaska, LLC Operations Engineer 433 W 9th Avenue, Anchorage, AK 99501 907.277.3726 Email: h.vanwyhe@furiealaska.com Furie Operating Alaska, LLC | 433 W 9th Avenue, Anchorage, AK 99501 | 907.277.3726 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: 2024.12.12 13:22:18 -09'00' Ao�?F RIE aa�I-1o3 t�►►� Hunter Van Wyhe Furie Operating Alaska, LLC op' N , Al ASKA Operations Engineer 433 W 91h Avenue, Anchorage, AK 99501 907.277.3726 Email: h.vanwyhe@furiealaska.com Date: Dec 4th, 2024 To: Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: KLU A-1A PTD:224-103 API: 50-733-20656-01-00 Geolog Mud Logging: Washed and Dried Cuttings Set 1 Shipping box containing 4 boxes of samples (1 complete set) RECEIVED DEC 0 4 2024 AOGCC Furie Operating Alaska, LLC 1 433 W 91h Avenue, Anchorage, AK 99501 1907.277.3726 eO:weo�,�?F„�ALASKRI,F Hunter Van Wyhe Furie Operating Alaska, LLC Operations Engineer 433 W 9th Avenue, Anchorage, AK 99501 907.277.3726 Email: h.vanwyhe@furiealaska.com GEOLOG OIOU CU 1111l3S SAMPLE MANIFEST WELL NAME: KLU A-1A - - WELL API: -----50-733-20e56-011-00 - --- Date DOW . FRCJ%V IW1512024 M tgd24t2024 Afea&owlion . Kenai PeninaA 9omug►dCoak Inlet OVEN DRIED SAMPLES (SETS A, B, C) B" i Box 2 Sox 3 Box 4 t 4130 6300 6470 7640 2 4160 5330 ! 6500 7670 3 4190 6360 6a30 7M 4 4220 6390 6a60 7730 .9 4250 5420 6a90 7760 i 4U- 0 5460 8620 77" _ 7 a 4310 5480 ( 6660 7820 8 4340 Salo 6680 7850 9 4370 5540 6710 7880 10 4400 Si* 6740 0 7910 11 4430 S600 _. 5770 y 7940 f 12 - 4"0 5630 6800 7970 13 4490 54W 8830 I $000 14 4520 $690 6860 $030 15 4550 5720 6m $060 { 16 j 45M 5750 v GM $090 # 17 4610 5780 6950 $120 4646 E 5816 6980 8150 i18 19 4670 5840 7010 $180 20 4700 6970 7040 8210 21 4730 5900 -- 7M __..B"o 22 4760 6930 —7100 -- -- RZ70 23 4790 5960 7130 8366 24 4820 5996 - -4160 8330 -1 25 41350 6020 -.- 7190 8360__ 26 4880 7220 8390 22 4910 1 6080 7250 $420 29 4940 6110 8460 29 4970 6140 - _7280 7310 8A80 30 6000 6170 7340 Oslo 81 6030 i- 6200 7370 8540 32 6060 6230 7400 8570 » -- 90 50 6260 7430 8Soo 34 _.._ 5120 6290 7460 OW 25 { $150 6320 7490 8060 39 6100 ` 6350 7520 8690 37 ! 6210 ' 6380 7550 8720 38 ( 5240 6410 - 7680 8760 Jig { S270 6-W 7610 0780 9817 Furie Operating Alaska, LLC 1 433 W 9th Avenue, Anchorage, AK 99501 1907.277.3726 FRIE Hunter Van Wyhe Furie Operating Alaska, LLC C ERAT , ALASKA 11CeAoeo,�? Operations Engineer 433 W 9th Avenue, Anchorage, AK 99501 P g g 907.277.3726 Email: h.vanwyhe@furiealaska.com Data delivered to: Alaska Oil and Gas Conservation Commission (AOGCC) C/O Meredith Guhl 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Please acknowledi;e receipt by sieniniz and returning one copv of this transmittal. Received By: Date: ' Zhu Furie Operating Alaska, LLC 1 433 W 91h Avenue, Anchorage, AK 99501 1 907.277.3726 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:Ben Christianson To:Regg, James B (OGC) Subject:KLU-A1A flow line modification Date:Tuesday, December 3, 2024 10:59:49 AM Attachments:image001.png Hey Jim, I just tried calling. I was just going to give you a heads up that we will be modifying KLU-A1A flow line to be able to route flow through a line heater before stepping the pressure down. This is the well that we just completed with the Spartan 151 jack up rig. Engineering will update P&IDs to reflect proposed flow line modification and I will send over to you. KLU-A1A is currently shut-in and will remain shut-in until line heater is installed. Hope you had a good Thanksgiving! Let me know if I’m missing anything. Thanks for everything Jim! Thanks, Ben Christianson Operations Superintendent Phone: 907-398-6588 Email:B.christianson@furiealaska.com Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. 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-1A 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): 8,817'N/A Casing Collapse Structural Conductor 2510 psi Surface 2,670 psi Intermediate Production 6,620 psi Liner 10,540 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:Mike Stefanov Contact Email: Contact Phone: (907) 252-3565 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 November 2nd, 2024 3,965'4,851' 3-1/2" 3,121' Perforation Depth MD (ft): 4100' 3-1/2" See attached schematic 9-5/8" 20" 13-3/8" 386' 2,172' 384' 1,906' 386' 2,172' 3,240'4,100' L-80 TVD Burst 8,816' MD 7,930 psi MDLength Size Proposed Pools: CO 724 7,431' 7,348' 3,486 psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 389197, 389198 224-103Furie Operating Alaska, LLC AOGCC USE ONLY 10,160 psi Perforation Depth TVD (ft): See attached schematic Drilling Manager Subsequent Form Required: Suspension Expiration Date: 433 W. 9th Avenue, Anchorage, AK 99502 50-733-20656-01-00 Tubing Size: PRESENT WELL CONDITION SUMMARY 8,721'N/A 1500 psi 5380 psi Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (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): m.stefanov@furiealaska.com Kitchen Lights Unit 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 324-625 By Grace Christianson at 8:49 am, Nov 01, 2024 7,431'8,816' SFD 11/1/2024 Submit CBL and obtain approval from AOGCC before adding perfs. Shallowest perf allowable under this sundry is 6257' MD/5200' TVD. BJM 11/1/24 SFD 10-407 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.04 08:04:15 -09'00'11/04/24 RBDMS JSB 110424 October 31st, 2024 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-1A (PTD 224-103) 10-403 Initial Beluga Perforations Mr. McLellan, Enclosed is the 10-403 for adding Beluga perforations to the KLU A-1A well with attached the Wellbore Schematic, Summarized Operations Plan, and table of Proposed Perforations. The KLU A-1A well was recently drilled and is awaiting perforating operations. Furie Operating Alaska, LLC hereby plans to move a Eline unit onto the Spartan 151. A CBL will be run and recorded. The CBL will be sent to AOGCC for review. Once approval is received to proceed with perforating operations, we will run in and perforate the selected Beluga intervals. The well will then be placed on production. Operations are expected to commence approximately November 2nd, 2024. If you have questions, please feel free to contact me at 907-252-3565. Mike Stefanov Drilling Manager Furie Operating Alaska, LLC Current Wellbore Schematic See perforation table attached for perforation intervals Perforation Table Formation Top TVD ft Base TVD ft Top MD ft Base MD ft Length MD ft Beluga 4798 4805 5818 5825 7 Beluga 4993 5002 6035 6045 10 Beluga 5009 5026 6053 6073 20 Beluga 5156 5161 6224 6231 7 Beluga 5374 5382 6481 6490 9 Beluga 5406 5418 6518 6533 15 Beluga 5471 5480 6595 6605 10 Beluga 5501 5506 6630 6635 5 Beluga 5521 5539 6653 6674 21 Beluga 5568 5578 6708 6719 11 Beluga 5642 5648 6794 6800 6 Beluga 5669 5675 6825 6832 7 Beluga 5798 5802 6972 6977 5 Beluga 5872 5886 7057 7073 16 Beluga 5988 5996 7188 7198 10 Beluga 6023 6037 7228 7244 16 Beluga 6039 6042 7246 7250 4 Beluga 6061 6073 7271 7285 14 Beluga 6096 6099 7311 7315 4 Beluga 6157 6161 7381 7386 5 Beluga 6199 6202 7429 7433 4 Beluga 6206 6210 7438 7442 4 Beluga 6245 6251 7482 7489 7 Beluga 6396 6402 7657 7663 6 Beluga 6405 6409 7667 7671 4 Beluga 6426 6430 7691 7696 5 Beluga 6542 6551 7824.5 7834.5 10 Beluga 6785 6795 8100 8111 11 Beluga 7006 7016 8346 8357 11 Beluga 7100 7107 8450 8458 8 Totals:272 Shallowest perf allowable under this sundry application is 5200' TVD or 6257' MD. -bjm KLU A-1A Perforation Procedure Summary 1. Ensure SCSSV is open, blocked in. 2. Rig up Slickline. Pressure test PCE to 250 psi low and 3500 psi high. a. (Note: PCE must be tested each time it is broken apart.) 3. PU/MU Dummy gun assy on Slickline. RIH to PBTD at 8,721'. POOH. RD Slickline. 4. Rig up Eline. Pressure test PCE to 250 psi low and 3500 psi high. a. (Note: PCE must be tested each time it is broken apart.) 5. Perform CBL. 6. Send CBL to AOGCC for approval. Do not proceed with perforating operations until approval is received from AOGCC. 7. RIH perforate Beluga intervals. 8. RD Eline equipment. Turn well over to production. From:McLellan, Bryan J (OGC) To:Mike Stefanov Cc:Trey Kendrick; Dan Robertson; Bob Laule Subject:RE: Pressure Test Charts and CBL Log Verbal Approval Request to AOGCC for Perforating the KLU A-1A Well Permit to Drill 224-103 Date:Monday, November 4, 2024 12:46:00 PM Mike, Thank you for sending the CBL. Furie has approval to proceed with the perforations that have been approved in Sundry 324-625. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Mike Stefanov <m.stefanov@furiealaska.com> Sent: Monday, November 4, 2024 11:33 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Mike Stefanov <m.stefanov@furiealaska.com>; Trey Kendrick <t.kendrick@furiealaska.com>; Dan Robertson <d.robertson@furiealaska.com>; Bob Laule <b.laule@furiealaska.com> Subject: Pressure Test Charts and CBL Log Verbal Approval Request to AOGCC for Perforating the KLU A-1A Well Permit to Drill 224-103 Bryan, Please see last pressure test charts for the tubing ( 3,500 psi) and 3-1/2” by 9-5/8” annulus ( 2,500 psi). Also attached is the CBL log. Note that the CBL tool string only got down to 8393 MD, 65’ MD above the bottom planned perforation interval. It is currently planned to bail out fill down to the desired depth with slickline to allow perforating. Regards, Mike Stefanov Drilling Manager Furie Operating Alaska LLC Tel Alaska +1 907 252 3565 Tel. +1 615 738 8596 E-Mail: m.stefanov@furiealaska.com Alternate E-Mail: mistefanov@my.lonestar.edu 433 W 9th Avenue Anchorage, AK 99501 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, November 1, 2024 4:22 PM To: Mike Stefanov <m.stefanov@furiealaska.com> Cc: Hunter Van Wyhe <h.vanwyhe@furiealaska.com>; Bob Laule <b.laule@furiealaska.com>; Dan Robertson <d.robertson@furiealaska.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXT] RE: Verbal Approval Request to AOGCC for Perforating the KLU A-1A Well Permit to Drill 224-103 Mike, Furie has verbal approval to proceed with the steps listed in your email below on the following conditions: 1. Furie provides written confirmation of successful pressure tests on the tubing and Inner Annulus. Tubing and inner annulus pressure test charts attached. 2. AOGCC reviews the results of the CBL and provides further written or verbal approval to proceed with perforating per your email. CBL is attached. Note that the CBL tool string only got down to 8393 MD, 65’ MD above the bottom planned perforation interval. It is currently planned to bail out fill down to the desired depth with slickline to allow perforating. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Mike Stefanov <m.stefanov@furiealaska.com> Sent: Friday, November 1, 2024 3:58 PM 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. To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Mike Stefanov <m.stefanov@furiealaska.com>; Hunter Van Wyhe <h.vanwyhe@furiealaska.com>; Bob Laule <b.laule@furiealaska.com>; Dan Robertson <d.robertson@furiealaska.com> Subject: Verbal Approval Request to AOGCC for Perforating the KLU A-1A Well Permit to Drill 224- 103 Bryan, Furie would like to request verbal approval to proceed with the four lower Beluga formation perforations in the KLU A-1A well following the acquisition of the CBL. The proposed steps are as follows: 1. Run CBL log with pressure/temperature tool to obtain static bottomhole pressure. 2. Send results to AOGCC for approval to proceed with perforating operations. 3. Rig up E-line. RIH and shoot 1st perforation interval from 8450'-8458' MD. 4. RIH to 8450' MD and perform Pressure/Temperature survey. Send results to AOGCC. 5. RIH and shoot 2nd perforation interval from 8346'-8357' MD. 6. RIH and shoot 3rd perforation interval from 8100'-8111' MD. 7. RIH and shoot 4th perforation interval from 7824'-7835' MD. 8. Flow well to unload brine. 9. Wait on sundry approval from AOGCC for remainder of perforations. Sincerely, Mike Stefanov Drilling Manager Furie Operating Alaska LLC Telephone: 615 738 8596 E-mail: m.stefanov@furiealaska.com Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. ***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. 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:Mike Stefanov Cc:Hunter Van Wyhe; Bob Laule; Dan Robertson; Rixse, Melvin G (OGC) Subject:RE: Verbal Approval Request to AOGCC for Perforating the KLU A-1A Well Permit to Drill 224-103 Date:Friday, November 1, 2024 4:22:00 PM Mike, Furie has verbal approval to proceed with the steps listed in your email below on the following conditions: 1. Furie provides written confirmation of successful pressure tests on the tubing and Inner Annulus. 2. AOGCC reviews the results of the CBL and provides further written or verbal approval to proceed with perforating per your email. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Mike Stefanov <m.stefanov@furiealaska.com> Sent: Friday, November 1, 2024 3:58 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Mike Stefanov <m.stefanov@furiealaska.com>; Hunter Van Wyhe <h.vanwyhe@furiealaska.com>; Bob Laule <b.laule@furiealaska.com>; Dan Robertson <d.robertson@furiealaska.com> Subject: Verbal Approval Request to AOGCC for Perforating the KLU A-1A Well Permit to Drill 224- 103 Bryan, Furie would like to request verbal approval to proceed with the four lower Beluga formation perforations in the KLU A-1A well following the acquisition of the CBL. The proposed steps are as follows: 1. Run CBL log with pressure/temperature tool to obtain static bottomhole pressure. 2. Send results to AOGCC for approval to proceed with perforating operations. 3. Rig up E-line. RIH and shoot 1st perforation interval from 8450'-8458' MD. 4. RIH to 8450' MD and perform Pressure/Temperature survey. Send results to AOGCC. 5. RIH and shoot 2nd perforation interval from 8346'-8357' MD. 6. RIH and shoot 3rd perforation interval from 8100'-8111' MD. 7. RIH and shoot 4th perforation interval from 7824'-7835' MD. 8. Flow well to unload brine. 9. Wait on sundry approval from AOGCC for remainder of perforations. Sincerely, Mike Stefanov Drilling Manager Furie Operating Alaska LLC Telephone: 615 738 8596 E-mail: m.stefanov@furiealaska.com Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KLU A-1A JBR 12/19/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 LPR 2-7/8"x5-1/2" VBR failed multiple attempts on 3-1/2" test joint. Swapped out to 4-1/2" Solid Body rams and passed retest on 4-1/2" test joint. Lower Kelly valve failed, grease and functioned, passed retest. Test Results TEST DATA Rig Rep:Dave Hebert, Daryl BoyOperator:Furie Operating Alaska, LLC Operator Rep:S.Dambacher, M.Brouillet. Rig Owner/Rig No.:Hilcorp 151 PTD#:2241030 DATE:10/16/2024 Type Operation:DRILL Annular: 250/2500Type Test:WKLY Valves: 250/4500 Rams: 250/4500 Test Pressures:Inspection No:bopJDH241017155525 Inspector Josh Hunt Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 13.5 MASP: 3486 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 FP Ball Type 3 P Inside BOP 1 P FSV Misc 0 NA 13 PNo. Valves 1 PManual Chokes 2 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8" 5K P #1 Rams 1 2-7/8"x5-1/2" P #2 Rams 1 Blinds P #3 Rams 1 2-7/8"x5-1/2" FP #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8" 5K P HCR Valves 2 3-1/8" 5K P Kill Line Valves 3 (1)3-1/8",(2)3 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3100 Pressure After Closure P1825 200 PSI Attained P17 Full Pressure Attained P108 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P16@2000 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P11 #1 Rams P11 #2 Rams P11 #3 Rams P12 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9999 9 9 9 9 9 9 9 FP FP LPR 2-7/8"x5-1/2" VBR failed Lower Kelly valve failed 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:Mike Stefanov Cc:Dan Robertson; Bob Laule; Hunter Van Wyhe Subject:RE: LOT from pason, easily shows a 13.0ppg EMW Date:Wednesday, October 16, 2024 5:28:00 PM Mike, Furie has approval to proceed with drilling per the PTD based on the 13.1 ppg LOT on the condition the rig pumps out of the hole on all trips, including short trips until the bit is back inside casing. It is acceptable to pull out on elevators after the bit is inside casing. Best regards, Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Mike Stefanov <m.stefanov@furiealaska.com> Sent: Wednesday, October 16, 2024 4:21 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Mike Stefanov <m.stefanov@furiealaska.com>; Dan Robertson <d.robertson@furiealaska.com>; Bob Laule <b.laule@furiealaska.com>; Hunter Van Wyhe <h.vanwyhe@furiealaska.com> Subject: LOT from pason, easily shows a 13.0ppg EMW Bryan, Well KLU A-1a sidetrack formation integrity test pressure data from the automated Pason data acquisition system is attached. This is thought to be more accurate pressure data than the gauge readings provided earlier. The pressure data seems to deviate from a straight line at ~650 psi. Revised kick tolerance calculations from 2 different kick tolerance calculators are also attached using 600 psi, or 13.1 ppg EMW at the exit point. Both calculators indicate a kick tolerance on the order of 21-23 bbls. Please advise if this is sufficient to continue drilling, within the next hour if possible so we can plan tonight’s operations, as we are finishing BOP testing at present. Thanks, Mike Stefanov Drilling Manager Furie Operating Alaska LLC Telephone: 615 738 8596 E-mail: m.stefanov@furiealaska.com Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. Confidentiality Notice: This email and its attachments (if any) contain confidential information of the sender. The information is intended only for use by the direct addressees of the original sender of this email. If you are not an intended recipient of the original sender (or responsible for delivering the message to such person), you are hereby notified that any review, disclosure, copying, distribution or the taking of any action in reliance of the contents of and attachments to this email is strictly prohibited. If you have received this email in error, please immediately notify the sender at the address shown herein and permanently delete any copies of this email (digital or paper) in your possession. 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 Mike Stefanov Drilling Manager Furie Operating Alaska, LLC 433 W 9th Avenue Anchorage, Alaska 99501 Re: Kitchen Lights Unit, Undefined Sterling and Beluga Natural Gas Pools, KLU A-1A Permit to Drill Number: 224-112 Surface Location: 883.68 FWL & 341.54 FSL of T10N:R11W; Sec24 Bottomhole Location: 856' FNL & 1772' FWL of T10N:R11W; Sec25 Dear Mr. Stefanov: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED this 13th day of September 2024. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.13 20:59:17 -04'00' 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: 8,772' TVD: 7,414' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date: 10/2/2024 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- 294319.20 y- 2,536,123.89 Zone- 4 to Same Pool: See attachments 16. Deviated wells: Kickoff depth: 4,092' feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 35.84 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 6.75" 3.5" 9.2# L-80 JFE Lion 4,812' 3960' 3,133' 8,772' 7,414' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): N/A TVD 1985' 2104' Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Diverter Sketch Seabed Report Contact Name: Mike Stefanov Mike Stefanov Contact Email:m.stefanov@furiealaska.com Drilling Manager Contact Phone:(615) 738-8596 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 N/A (Driven) 2,176'1934 ft3 12.3 ppg + 692 ft3 15.6 ppg Effect. Depth MD (ft): Effect. Depth TVD (ft): Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 2,172' 13 3/8" 8,420'9 5/8" 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: 979 ft3 13.6 ppg + 901 ft3 15.6 ppgProduction Liner 8,223' Intermediate Authorized Name: See attached well schematic. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Tail: 37 bbls (168 sacks) 15.3 ppg 3,486 psi N/A 433 W. 9th Avenue, Anchorage AK, 99501 Furie Operating Alaska, LLC 883.68 FWL & 341.54 FSL of T10N:R11W; Sec24 ADL 389197, 389198 2,560 18. Casing Program:Top - Setting Depth - BottomSpecifications 3,890 psi KLU A-1A Kitchen Lights Unit Undefined Sterling and Beluga Gas Pools Total Depth MD (ft): Total Depth TVD (ft): 402-081A Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) Lead 1: 83 bbls (197 sacks) 12.0 ppg Lead 2: 109 bbls (256 sacks) 12.0 ppg 8,131' 6,855' 1960' FNL & 831' FWL of T10N:R11W; Sec25 856' FNL & 1772' FWL of T10N:R11W; Sec25 Time v. Depth Plot Drilling Fluid Program Shallow Hazard Analysis 20 AAC 25.050 requirements Conductor/Structural 20"386' 8,234' 6,955' LengthCasing 8,131' See attached well schematic. essss N ype of W l 1b S Class: os N essss NNooo s N Nooo o s: well is G AAC 2 esss NNooos No S G y E S esss NNooo Ye o Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Drilling Manager API Number: Contact E Contact P Permit Approval By Grace Christianson at 8:28 am, Sep 09, 2024 50-733-20656-01-00 Submit CBL to AOGCC and obtain approval before perforating. Perforating steps 123-135 are not approved as part of this PTD. Separate sundry required for perforating. 3,133' 2:41 pm, Sep 10, 2024 3145524168 BJM 9/11/24 Submit side scan seabed survey results to AOGCC before spotting the jackup rig on location. 224-103 DSR-9/11/24 51.3 Initial BOP test to 5000 psi. Subsequent BOP tests to 4500 psi. All annular tests to 2500 psi. Submit FIT/LOT results and obtain approval before drilling 6.75" hole. A.Dewhurst 10SEP24 1985' *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.13 20:59:33 -04'00' 09/13/24 09/13/24 RBDMS JSB 091724 1 September 6, 2024 Bryan McLellan Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Furie Operating Alaska KLU A-1A Permit to Drill (10-401) Submittal Mr. McLellan, Please see the attached application for the permit to drill the above referenced well. Well KLU A-1 is planned to be sidetracked to access Sterling and Beluga formation production. The well will be completed with a 3-1/2” gas lift tie-back completion. Separate sundry notices will be submitted for the KLU A-1 plug back and perforating operations. Drilling operations are expected to commence approximately October 2, 2024. Regards, Mike Stefanov Drilling Manager Furie Operating Alaska, LLC Separate sundry notices will be submitted for the KLU A-1 plug back and perforating operations. 2 KLU A-1A 10-401 Permit to Drill Julius R Platform September 6, 2024 3 Contents 1. Well Information...................................................................................................................................4 2. Tubular Program...................................................................................................................................4 3. Drill Pipe Information............................................................................................................................4 4. Formation Tops.....................................................................................................................................5 5. Current Wellbore Schematic.................................................................................................................6 6. Pre-Sidetrack Schematic .......................................................................................................................8 7. Planned Wellbore Schematic................................................................................................................9 8. Property Plat.......................................................................................................................................10 9. Drilling Summary.................................................................................................................................11 10. Mandatory Regulatory Compliance / Notifications........................................................................23 11. BOP N/U and Test...........................................................................................................................24 12. Attachment 1: KLU A-1 Pore Pressure/Frac Gradient.....................................................................25 13. Attachment 2: Anticipated Drilling Hazards ...................................................................................26 14. Attachment 3 : FIT Procedure.........................................................................................................28 15. Attachment 4: BOP Schematic........................................................................................................29 16. Attachment 5: Choke Manifold Schematic.....................................................................................3 0 17. Attachment 6: Tubing Hanger (Current).........................................................................................32 18. Attachment 7 Wellhead Schematic (Current)................................................................................33 19. Attachment 8: Rig Information.......................................................................................................34 20. Attachment 9: Casing Design Information for Liner.......................................................................37 21. Attachment 10: 6-3/4” Hole Section for MASP ..............................................................................38 22. Attachment 11: Permit to Drill Kick Tolerance Evaluation .............................................................39 23. Attachment 12: Production Drilling Parameters KLU A-1, KLU A-2A, KLU 3...................................40 24. Attachment 13: Time vs. Depth......................................................................................................41 25. Attachment 14: KLU A-1A Fluid Program........................................................................................42 26. Attachment 15: KLU A-1A Directional Program (wp07)..................................................................52 4 1. Well Information Well Name KLU A-1A Drilling Rig Spartan 151 Slot Name Slot D (KLU A-1) Directional Plan WP08 Pad and Old Well Designation Sidetrack of existing KLU A-1 (PTD: 216-063) Planned Completion Type 3-1/2” monobore w/ GLM Target Reservoirs KLU Sterling/Beluga Kick Off Point +/- 4,092’ MD (WP06), Set WS anchor at 4,110’ MD Planned Well TD, MD/TVD 8,772.89’ MD/7,414.10’ TVD Surface Location (Governmental) 884’ FWL, 341.57’ FSL, Sec. 24, T10N, R11W, SM Surface Location (NAD 27) X=294319.2, Y=2536123.89 Work String 4.5” Delta 425 16.60# RT – Mean Sea Level (MSL) 114 ft RT – Mud Line (ML) 202.10 ft Water Depth Tidal Difference - +/- 20’ 88.00’ ft 2. Tubular Program Hole Section OD WT (#/ft) Couple OD ID (in)Drift (in)Grade Conn Top Bottom 6.75” 3.5” 9.2 3.96” 2.949” 2.867” L-80 JFE LION Surface 8,772’ **Minimum of 100’ overlap required between casing strings 3. Drill Pipe Information Hole Section OD ID TJ ID TJ OD WT (#/ft)Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) 6.75” 4.5” 3.826 3.0 5.25 16.6 S-135 Delta 425 17690 16800 468 5 Description Size Weight Capacity ( bbl/ft) Drill Pipe 4-1/2” Delta 425 (from Workstrings International spec sheet) 4.5” 16.6#/ft .0133 Tubing JFE Lion 3.5” 9.2 #/ft .0087 Tubing Hydril 503 3.5” 9.2 #/ft .0087 Tubing Hydril 511 2.375” 4.4 #/ft .00387 Casing 9.625” 53.5 #/ft .0707 9.625 x 3.5” Annulus 53.5# by 3.5” 9.2# .0589 9.625 X 2.375” Annulus 53.5# by 2.375” 4.4# .0653 9.625 X 4.5 Annulus 53.5# by 4.5” DP 16.6# .0511 6.75 x 3.5” Annulus .0324 4. Formation Tops x Top Sterling: 3,732’ MD/ 2,949’ TVD x Top Beluga: 5,761’ MD/ 4,771’ TVD Note: TVD is from rig floor. RT to MSL (Spartan 151) 114.10’ 6 5. Current Wellbore Schematic 7 Well KLU A-1 ZonePerforation Footage, MDPerforation Footage, ft TVTPerforation Date Initial or ReperfGun diameter, inSPF Charge, gmPhasing, DegOrientationFrom (ft MD) To (ft MD) From (ft TVD) To (ft TVD)Upper Sterling4279 429213 7/25/2018 Initial 4.5 5.0 RandomUpper Sterling4389 440011 7/25/2018 Initial 4.5 5.0 RandomUpper Sterling4419 443617 7/25/2018 Initial 4.5 5.0 RandomMiddle Sterling4571 45743 7/25/2018 Initial 4.5 5.0 RandomMiddle Sterling4581 45898 7/25/2018 Initial 4.5 5.0 RandomMiddle Sterling4615 462611 7/25/2018 Initial 4.5 5.0 RandomMiddle Sterling4683 470017 7/25/2018 Initial 4.5 5.0 RandomMiddle Sterling4708 47157 7/25/2018 Initial 4.5 5.0 RandomLower Sterling4865 488520 7/25/2018 Initial 4.5 5.0 RandomLower Sterling5000 50055 7/25/2018 Initial 4.5 5.0 RandomLower Sterling5019 50223 7/25/2018 Initial 4.5 5.0 RandomLower Sterling5030 50377 7/25/2018 Initial 4.5 5.0 RandomBeluga5801 58109 6/4/2019 Initial 2.375 6 Connex 11 60 RandomBeluga6040 60500 10/8/2021 Reperf 2.375 6 11 RDX 60 RandomBeluga6041 60476 6/4/2019 Initial 2.375 6 Connex 11 60 RandomBeluga6194 62000 10/8/2021 Reperf 2.375 6 11 RDX 60 RandomBeluga6195 62005 6/5/2019 Initial 2.375 6 Connex 11 60 RandomBeluga6352 636210 8/23/2023 Initial 2.375 6 11 RDX 60 RandomBeluga6429 643910 6/5/2019 Initial 2.375 6 Connex 11 60 RandomBeluga6422 64320 10/7/2121 Reperf 2.375 6 11 RDX 60 RandomBeluga6429 643910 6/5/2019 Initial 2.375 6 Connex 11 60 RandomBeluga6448 64524 6/5/2019 Initial 2.375 6 Connex 11 60 RandomBeluga6448 64520 9/30/2021 Reperf 2.375 6 11 RDX 60 RandomBeluga6479 649112 6/5/2019 Initial 2.375 6 Connex 11 60 RandomBeluga6480 64900 9/29/2021 Reperf 2.375 6 11 RDX 60 RandomBeluga6531 65376 6/5/2019 Initial 2.375 6 Connex 11 60 RandomBeluga6558 656810 9/30/2021 Initial 2.375 6 11 RDX 60 RandomBeluga6590 660010 9/30/2021 Initial 2.375 6 11 RDX 60 RandomBeluga6665 66705 9/29/2021 Initial 2.375 6 11 RDX 60 RandomBeluga6665 66705 6/5/2019 Initial 2.375 6 Connex 11 60 RandomBeluga6740 67500 9/28/2021 Reperf 2.375 6 11 RDX 60 RandomBeluga6743 67496 6/4/2019 Initial 2.375 6 Connex 11 60 RandomBeluga6772 67900 9/28/2021 Reperf 2.375 6 11 RDX 60 RandomBeluga6773 678916 6/4/2019 Initial 2.375 6 Connex 11 60 RandomBeluga6846 685812 10/9/2021 Initial 2.375 6 11 RDX 60 RandomBeluga6878 688810 8/23/2023 Initial 2.375 6 11 RDX 60 RandomBeluga7013 70229 6/4/2019 Initial 2.375 6 Connex 11 60 RandomBeluga7010 70150 9/28/2021 Reperf 2.375 6 11 RDX 60 RandomBeluga7015702509/27/2021 Reperf 2.375 6 11 RDX 60 RandomBeluga7108 711810 6/4/2019 Initial 2.375 6 Connex 11 60 RandomBeluga7109 71190 8/23/2023 Reperf 2.375 6 11 RDX 60 RandomBeluga7203 72107 6/4/2019 Initial 2.375 6 Connex 11 60 RandomBeluga7214 72206 6/4/2019 Initial 2.375 6 Connex 11 60 RandomBeluga7228 72335 6/3/2019 Initial 2.375 6 Connex 11 60 RandomBeluga7233 724310 8/23/2023 Initial 2.375 6 11 RDX 60 RandomBeluga7250 72566 6/3/2019 Initial 2.375 6 Connex 11 60 RandomBeluga7433 744310 6/3/2019 Initial 2.375 6 Connex 11 60 RandomBeluga7453 74596 6/3/2019 Initial 2.375 6 Connex 11 60 RandomBeluga7748 776012 6/3/2019 Initial 2.375 6 Connex 11 60 RandomPerforation Intervals, Ref to Perforation Intervals 8 6. Pre-Sidetrack Schematic 9 7. Planned Wellbore Schematic 9 108. Property Plat 11 9. Drilling Summary KLU A-1 is a shut in gas producer. The well is planned to be sidetracked to targets in the Beluga and Sterling formations. A 10-403 sundry for the abandonment of the current KLU A-1 well was submitted separately to this 10-401 submittal. KLU A-1 will be sidetracked, and new wellbore drilled to 8,772’ 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 October 2, 2024. Well plug and abandonment operations to be performed under 10-403 Sundry (324-385). General sequence of operations pertaining to this drilling operation conducted under 10-401 Sundry: Make Up the Baker Mechanical Set Whipstock. 1. A 9-5/8” whipstock anchor will be set at 4,110’ MD and 30 degrees left of high side. Displace well to 9.5 - 10 ppg LSND mud. The window will be milled per Baker Hughes Field Specialist and at least 30’ of new formation. x A bond log and CCL has been recorded over the whipstock anchor setting depth of 4,110’ MD. o 4,110’ MD looks like good cement. (Per SLB IBC-CBL-VDL 6/19/2018) o Set whipstock as close to bottom as possible to 4,110’ MD. o Collars at 4,080’ MD and 4,123’ MD. x Anticipated metal cuttings from window will be about 300 lbs. x Contact AOGCC to witness FIT 48 hours in advance. x Weight of 20,000 lbs has been set on the retainer at approximately 4,110’ MD, note there has been 4 bbls of cement spotted on top of the retainer and washed back to retainer. o Anchor pinned, ~15K to set. Verify 15K can be set with no movement x The whipstock should be set close to the bottom of casing connection. WS Anchor 4,110’ MD and collar at 4,123’ MD. x The whipstock run will be made with an MWD survey tool in the BHA. x Simulation Run BHA prior to running whipstock: o 8-1/2” Bit\Bit Sub\Full Size Watermelon Mill\Scraper\4-3/4” Drill Collar\full drift stabilizer\HWDP\ Jars o Baker 4.5” IF connections 12 o Record parameters when passing through doglegs (pick up, slack off and rotating weight) 2. RIH with Simulation run and tag cement retainer at 4,110’ MD. 3. Reciprocate the assembly across the whipstock setting depth. a. Note any tight spots during this operation and advise Drilling Manager and Drilling Engineer in Anchorage. 4. Circulate bottoms up, to ensure the hole is clean. 5. POOH with Simulation BHA. 6. Make up the Whipstock assembly in the rotary, using the whipstock handling bar. a. Upper Whipstock Milling Assembly: i. Window Mill\Lower Watermelon mill\flex joint\ Upper Watermelon mill\Float Sub\XO b. Lower Whipstock BHA: i. TorqueMaster mechanical set anchor\WindowMaster Whipstock 7. MU MWD tool. 8. MU HWDP(s)\Drill Pipe. 9. Install the milling assembly. 10. Remove the whipstock handling bar, RIH and set the slips on the Drill Collar above the upper watermelon mill. 11. Pick up the MWD assembly. 12. Measure and record MWD tool face from the scribed line from the whipstock shear stud. This will ensure the alignment of the whipstock. 13. Hold a pre-trip meeting with the drilling crew, directional driller, and Baker whipstock hand etc. 14. Run string at 2 to 3 minutes per stand. 15. Baker whipstock hand to be on rig floor during the trip. There are to be two (2) Baker hands on the rig to ensure 24-hour coverage of the operation on the rig floor. 16. Take care running assembly through the BOPs and other potentially tight spots. 17. TIH with whipstock string. Shallow test the MWD. 18. TIH with DP to the whipstock anchor setting depth at 4110’ MD. Exercise caution when RIH and setting slips with whipstock assembly. 19. Fill the drill pipe a minimum of every 10 stands on the trip in the hole with the whipstock assembly. 20. Orient whipstock as directed by the directional driller. The directional plan specifies 30 deg LOHS – confirm with Sperry (Baker prefer to stay within 60, but we are good between 0- 60). 21. Orient at least 30’ - 90’ above retainer. 22. Set the top of the whipstock at 4,080’ MD. WS anchor at 4,110’ MD. a. 13-3/8” 68# L-80 surface casing set at 2,172’ MD. b. 9-5/8" 53.5# L-80 production casing run from surface to 8,223’ MD. c. Ref log: FURIE-KLU_A1_CBL-GR-CCL_ June 19,2018. 13 Mill Window Plus 30' of New Hole (DO NOT EXCEED 50' OF NEW HOLE BEFORE RUNNING THE PLANNED FIT) Avoid taking the FIT in a coal, if possible Flow rate: 200 to 300 gpm RPMs (Baker): Dictated by Baker toolhand based on milling performance o Weight on mill (Baker): start with 1-2K lbs. Increase as needed o Close the manual valve on the choke side of the mud cross just prior to the milling operation to prevent metal cutting entering the HCR and choke line. 23. Use ditch magnets (Spartan/Baker) to collect the metal shavings. Clean regularly. 24. Ensure any personnel working around metal shavings wear proper PPE, including goggles, face shield and Kevlar gloves. 25. Work the upper mill through the window to confirm the window milling is complete and circulate well clean (circulate a minimum of 1-1/2 bottoms up). 26. Pump a high-vis sweep to remove metal shavings and make every effort to remove all of the hi-vis sweep from the mud system as it is circulated to surface. a. Pump sweep every 3-5 feet (10-15 bbls). 27. Condition mud. 28. Pull starter mill into casing above top of whipstock, flow check the well for 10 minutes and conduct a FIT to 15 ppg. a. Baker recommends 30’ of open hole to get upper watermelon mill through window. Notify AOGCC at least 48 hour notice for FIT. b. **Assuming the kick zone is at TD, a FIT of 15 ppg. EMW gives a Kick Tolerance volume of 26.9 bbls with 10.6 ppg mud weight. Perform kick tolerance calculations based on actual FIT results and adjust TVD of well if necessary. c. Monitor 9-5/8 x 13-3/8” annulus during FIT and report any change in pressure. d. Contact AOGCC to witness FIT 48 hours in advance. Submit FIT results to AOGCC. 29. POOH and LD milling assembly. a. Flow check well for 10 minutes to confirm no flow: i. Before pulling off bottom. ii. Before pulling the BHA through the BOPE. 30. Once out of the hole, inspect the gauge of the mills and record. Record weight of milled cuttings recovered. If upper watermelon mill is more than 1/8” under gauge, PU second set of mills (polish BHA). 31. At least one Baker hand to stay on location until milling BHA is pulled out of window and is laid down and drilling and logging assembly is run through the window. 32. Open the manual valve on the choke side of the mud cross. 33. Flush the stack/lines to remove metal debris that may have settled out in these areas. Ensure BOP equipment is operable. 14 Drill 6.75” Hole Section 34. PU 9,300’ of 4.5" Delta 425 drill pipe for drilling 6.75”-hole section. 35. P/U 4.75" Sperry motor with a 1.83-degree bend and drilling cleanout assembly, with no logging tools. 36. Drill ~230’ to have sufficient hole to bury MWD/LWD BHA (length determined by total length of logging tools) with this assembly to ensure hole is clean. 37. POOH and pick up MWD/LWD BHA. a. Ensure BHA components have been inspected previously. b. Caliper and measure all components before makeup. Drift drill pipe. Visually verify no debris inside components that cannot be drifted. c. Ensure tool face offset is measured accurately and entered correctly into the MWD software. d. Have Halliburton Drilling Engineer run hydraulic models to ensure optimum tool TFA for both the bit and LWD optimum performance. e. Plan to pump at 150 - 300 gpm. f. Production section will be drilled with to keep below 4 deg/100 DLS in the build and drop sections of the wellbore. g. Primary bit will be the PDC GTD54DM. Ensure backup PDC bit is available on location. 38. TIH. Clear the rig floor while installing nuclear sources in the Density (ALD) and Neutron (CTN) tools Shallow test MWD/LWD on trip in. Ensure Sperry MWD/LWD service rep on rig floor during this operation. Fill pipe every 10 stands while running in the hole. 39. Circulate well with 9.5 to 10.0 ppg LSND to warm up mud until the mud is the same weight in and out. 40. Drill 6.75" hole to 8,772 MD/7,414 TVD (see BHA attachment). h. Triple combo (DENSITY, POROSITY, RESISTIVITY) will be run. Motor bend of 1.83 deg. TIH. Prior to drilling, circulate until clean. TOH. If any stickiness may need to backream some intervals. Short trips every 600’ to 1,000’. Use caution backreaming due to fragile coals. i. Top of the Sterling is anticipated to be 3,732’ MD and 2,949’ TVD. j. Top of the Beluga is anticipated to be 5,761’ MD and 4,771’ TVD. k. No major faults expected to be encountered, except the potential faulting near the kick off point l. Pump sweeps and maintain mud rheology to ensure effective hole cleaning. m. Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. n. Keep swab and surge pressures low when tripping. Minimize the number of short trips unless wellbore problems such as torque, pickup/slackoff increases. o. See attached mud program for Mud Weight schedule, hole cleaning and LCM strategies. Triple combo (DENSITY, POROSITY, RESISTIVITY) will be run. 15 p. Ensure solids control equipment is functioning properly and utilized to keep LGS to a minimum without excessive dilution. q. Adjust MW as necessary to maintain hole stability. r. Ensure mud engineer set up to perform HTHP fluid loss. s. Maintain API fluid loss < 6 ml/30 minutes. HPHT < 11 ml/30 minutes at 200°F t. Ensure Low Gravity Solids ( LGS ) are maintained at less than 6 %. u. Take MWD surveys every stand drilled. v. Minimize backreaming when working tight hole. w. Drilling fluid i. Use thicker, more viscous milling fluid for window milling. Thin it back for drilling below the casing window with same fluid. ii. Drilling/milling fluids must be approved for discharge. iii. Any different additives must be approved for discharge prior to use. iv. Additives include KCl, amine salt, etc. for inhibition. v. Inhibited polymer mud, seawater based. vi. Review Baroid provided coal drilling recommendations. vii. Mud will include LCM in recipe. x. Mud weight schedule dictated by pore pressure prediction (see KLU A-1 Pore Pressure/Frac Gradient). Mud weight expected to vary from 9.5-10.6 ppg while drilling this interval. y. Directional drilling i. Run a stabilizer right above the motor to prevent hole angle building more than desired. ii. Stay within 100’ radius of directional plan. iii. Controlled drilling at 40-60 ft/hr if losses encountered. iv. Non fibrous LCM limited to no more than 40 lb/bbl. z. Bits i. GTD54DM primary, GT64D backup recommended 1. (5 and 6 refer to number of blades, 5 blade has larger junk slots for coals and clays) ii. WOB 6-10 K lbs, up to 15K+ lbs if needed. iii. RPM 240-380 total bit RPM, string rpm between 50 to 70. iv. Cutters on back of blades to allow for backreaming if desired. v. Optimize to minimize vibration on logging tool. aa. Electric line/Slickline i. Pipe recovery can be prepared for as needed. ii. Unit available that can be used for slickline on platform. iii. Different diameters of E-Line available. bb.Cementing i. Use stop collars on shoe track to keep centralizers in place. May be free floating on rest of liner or can use stop collars 9.5-10.6 ppg 16 ii. Bridgemaker with multiple types and particle sizes of LCM will be added to the tail end of the lead cement slurry to cure losses. Bridgemaker will be mixed with the bulk cement at the bulk plant and sent to platform. 41. At TD pump a sweep and a marker, to be used as a fluid caliper to determine annular volume for cement calculations. CBU and pull a short trip back to the window back to TD. 42. TOH with drilling assembly, handle BHA as appropriate. Run 3-1/2” Production Liner 43. The float shoe, float collar and landing collar should be premade up with thread lock compound, prior to shipment to the rig. Prepare and rack back the liner cement head (Halliburton). 44. Note the liner hanger and running tool have been pre-made up at the Frontier facility in Houston. 45. R/U 3-1/2" liner running equipment including torque turn equipment (Parker) for JFE Lion 3-1/2” 9.2# L-80 tubing. a. Ensure 4.5" Delta 425 to 3-1/2” JFE Lion tubing crossovers are on the rig floor. b. Ensure there are FOSVs on the rig that are pre-made up to crossovers that can be stabbed into the production liner or drill pipe. c. R/U fill up line to fill liner while running. d. Ensure all liner joints have been drifted and tally verified prior to running. e. Be sure to count the total # of joints before running. f. Keep hole covered while R/U casing tools. g. Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. h. Take care while running the production liner to minimize surge pressure that could result in lost returns. 46. P/U shoe joint, visually verify no debris inside joint. 47. Continue to M/U and thread lock shoe track assembly consisting of: i. (1) Shoe joint w/ shoe bucked on & thread locked (coupling also thread locked). ii. (2) Joints with float collar bucked on pin end & thread locked (coupling also thread locked). One centralizer per shoe joints with stop collars to hold centralizer mid joint. iii. Landing collar pup bucked up. iv. One centralizer per joint will be run on 3-1/2" liner. v. Ensure proper operation of float shoe & FC. 48. Continue running 3-1/2" production liner in the hole. i. Run short joints per liner running program. i. Fill liner while running using fill up line on rig floor. j. Use "API Modified" thread compound. Dope pin end only w/ mustache brush. 17 k. Utilize a collar clamp (Hydraulic Collar Clamp, if possible, until weight is sufficient to keep slips set properly. 49. RIH w/ liner no faster than 30 seconds per joint. Watch displacement carefully to avoid surging the hole. Slow down running speed, if necessary, to minimize surge pressures and chances of losing circulation 50. Fill pipe while lowering string every 10 joints. 51. Set string slowly in and pull slowly out of slips. 52. Circulate 1-1/2 string volumes at the 9-5/8” casing window prior to going into open hole. Stage pumps up slowly and monitor for losses. Do not exceed 60 % of the nominal liner hanger setting pressure of 1,930 psi, which is roughly 1,000 psi. 53. Obtain up and down weights of the liner before entering open hole. 54. Run enough liner to provide at least 100' overlap inside casing. Ensure setting sleeve will not be set in a connection. Collar @4,123 MD. 55. Before picking up liner hanger/ packer assembly, count the number of joints on the pipe deck to make sure it coincides with the pipe tally. 56. M/U liner hanger and top packer assembly. Fill liner tieback sleeve with viscous mud, that is thin enough to travel past the running tool down to the packoff. 57. RIH one stand and circulate a minimum of one string volume. Note weight of liner. 58. Check to see that the liner shoe is opposite a competent formation before circulating based on LWD logs. 59. Record weight of liner. This is the approximate weight to be lost when hanger is set. 60. Continue to fill the string every 10 stands while running liner. Do not stop to fill casing. 61. PU the cement stand and tag bottom with the liner shoe. PU 10' off bottom. Note slack-off and pick-up weights. 62. Stage pump rates up slowly to circulating rate without exceeding 1,160 psi (60% of the liner hanger setting pressure of 1,933 psi). Circ and condition mud with the liner on bottom. Reduce the low-end rheology of the drilling fluid by adding water and thinners. 63. Reciprocate if hole conditions allow. Circ until hole and mud is in good condition for cementing. 64. Set liner 5’ off bottom. 65. Release 1.125” setting ball from the liner cement head and displace at 1-3 bbl/min. Pressure up to 1,933 psi to shear the hanger cylinder, hold pressure for one minute. Set the slips by slacking off 30 K lbs. Bleed off pressure. 66. Hold hanger running tool in compression. Pressure up to 2,520 psi to shear setting tool and hold pressure for 2 minutes. Bleed off to 500 psi and pick up to release the running tool. Do not pick up more than 4 feet to ensure that the liner hanger packer is not set. If running tool does not release, pressure up to 2,750 psi, 3,000 psi and 3,200 psi. After each try to confirm release. If running tool does not hydraulically release, it can be mechanically released. Rotate string to the left ¼ turn at tool with 2,550 ft-lbs of torque. After rotation shear, then set down 16,200 lbs to shear. Tool will then be released. 67. Set back down 20K lbs. Pressure up to 3,668 psi to shear out ball seat. 18 68. Proceed pre-cement job circulation and cement job. Cement 3-1/2” Production Liner 69. Hold a pre-job safety meeting for the upcoming cementing operations. 70. Pump 5 bbls of fresh water. 71. Test surface cmt lines to 4,500 psi. 72. Pump 60 bbls 12.0 ppg spacer. Total cement volume 229 bbls w/40 % excess 73. Mix and pump 83 bbls of lead cement without Bridgemaker LCM (Interval Liner top to 3,569’ MD)(based on gauge hole volumes), followed by 109bbls of lead slurry with 5 lb/bbl bridge maker lost circulation material (Interval 4,076 to 7,760 MD), (based on gauge hole volumes), and a tail slurry of 37 bbls of 15.3 ppg tail cement (Interval 7,760’ to 8,902’ MD). (based on gauge hole volumes), Verify cement volume with actual inputs. Ensure cement is pumped at designed weight, using a pressurized mud balance. Job is designed to pump 40 % OH excess (based on caliper), but if wellbore conditions dictate otherwise decrease or increase excess volumes. Ensure cement with Bridgemaker does not make it to liner top. Cement volume is designed to bring cement to TOL. 74. Displacement fluid will +kill weight fluid. Note that the estimated reservoir pressure at 8,902’ MD TD depth is 10.1 ppg. Kill weight fluid would be ~10.3 ppg. Program displacement is estimated at 98 bbls (Drill pipe and liner). Please independently verify with actual inputs. 75. Pump cement at max rate of 5 bpm maximum, monitor pump pressures. Reduce pump rate to 3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re-zeroed at this point. Drill pipe displacement is about 55.4 bbl (3,900’ X .01422 bbl/ft) and liner displacement is 42.6 bbls (4,902’*.008699 bbl/ft). Follow cement with 10 bbls freshwater, 45 bbls mud and 30 bbls spacer and 13 bbls seawater behind to bump the plug. This will give us spacer across the liner top. 76. Monitor returns & pressure closely while circulating. Notify Well Site Supervisor immediately of any changes. Reduce pump rate as required to avoid packoff. 77. Do not over displace by more than 5 bbls = 154’ of liner X OH volume. Review this value based on lowest possible perf interval. Verified cement calcs. -bjm 19 Lead #1: No LCM System SBM CEM ECONOCEM Density 12 lb/gal Design Volume 83 bbls Yield 1.85 ft3/sk Mixed Water 10.15 gal/sk Expected Thickening 5-7 hrs API Fluid Loss < 100 Additives Code Description Concentration Type I/II Halad 344 HR-5 D-Air 5000 SA-1015 Cement Fluid Loss Retarder Defoamer Suspension Aid 94 lbs/sk 0.4 % 0.3 % 0.2 % 0.125 % Lead #2: Bridgemaker LCM System SBM CEM ECONOCEM Density 12 lb/gal Design Volume 109 bbls Yield 1.87 ft3/sk Mixed Water 10.21 gal/sk Expected Thickening 5-7 hrs API Fluid Loss < 100 Additives Code Description Concentration Type I/II Halad 344 HR-5 D-Air 5000 SA-1015 BridgeMaker II Cement Fluid Loss Retarder Defoamer Suspension Aid LCM 94 lbs/sk 0.4 % 0.3 % 0.2 % 0.125 % 5 lb/bbl Tail System SBM CEM VERSACEM TAIL Density 15.3 lb/gal Design Volume 37 bbls Yield 1.24 ft3/sk Mixed Water 5.57 gal/sk Expected Thickening 4-5 hrs API Fluid Loss < 100 Additives Code Description Concentration Type I/II Halad 344 HR-5 CFR-3 FDP-C1446-21 Cement Fluid Loss Retarder Dispersant Gelation inhibitor 94 lbs/sk 0.3 % 0.35 % 0.3 % 0.3 % 20 78. Bleed pressure to zero to check float equipment. 79. Pick up to release from liner running tool and set packer. 80. To set packer. PU to neutral weight per Frontier Oil Tools Procedure. Pick up a minimum of 9 feet, maximum of 11 feet. This will release Setting Dogs. Slack off 50K to shear packer setting pins with 30,240 lbs. Set down stoke should be only a few feet. If it strokes fully back down, the Setting Dogs did not release outside of TBR. Pick up 2 feet further than prior pick up and slack off again. 81. Circulate surface to surface to remove any spacer and cement. 82. Test packer by pressuring down the backside 2,500 psi for 30 minutes. Record test on chart recorder. 83. Bleed of pressure. Slack off to neutral to weight. 84. Circulate well. 85. Pick up lower PBR polish mill and 9-5/8” casing scraper assy and RIH to liner top CBU. Change over to inhibited sea water. POOH. 86. Note: Caliper OD’s and ID’S and strap all components going below the rotary. We need to have fishing dimensions and sketches for anything that goes below the rotary. 87. Be sure to have rabbits for all tubulars used in the completion. 88. Rabbit 3-1/2” as picked up and get good strap. Only one rabbit on the floor and nothing rabbited near the rotary. Run 3-1/2" Upper Completion Assembly 89. Confirm all required Upper Completion Assemblies are on the well location and that there is no visual external damage to any of the assemblies, pup joints or tubing. 90. Confirm all tally records for completion assemblies, serial numbers, pressure ratings and other relevant information for each GLM, CIV, TRSSSV, X-Nipple and 4” seal assembly. 91. Function test the TRSSSV prior to running completion per Baker Hughes Procedure (confirm opening and closing pressures and visually confirm that flapper is opening/closing). 92. Ensure seal assembly has been redressed and is on the rig/well site. 93. Locate the appropriate tubing drift for 3-1/2” 9.2 lb./ft. tubing and drift pipe as running in the hole (NOTE: do not drift the TRSSSV as flapper will be closed prior to MU the TRSSSV assy. to string and connecting ¼” control line). 94. RU tubing running equipment on the rig floor including torque turn equipment for JFE Lion 3-1/2” 9.2# L-80 connection. 95. Confirm appropriate MU Torque is used to MU JFE Lion premium connections and that approved thread compound is used. NOTE: If there is any deviation from anticipated standard for acceptable connection make up graph please contact Furie representative for advise/approval. 96. MU seal stem assembly to the first joint of 3-1/2” 9.2 lb./ft. L-80 JFELion tubing. 21 97. MU 3-1/2” 9.2 #L-80 monobore completion with GLM’s (recommended depths on proposed completion diagram, can be adjusted slightly as needed in tubing tally), chemical injection mandrel, TRSSSV and seal stem. RIH while spooling 3/8” chemical injection and ¼” TRSSSV control lines. Make up control lines and test at 5,000 psi after connections are made. Maintain 2,500 psi pressure on chemical injection line and SSSV control line while running. 98. One joint prior to reaching the anticipated depth of the lower PBR of 3-1/2 x 9-5/8” Liner Hanger check and record Pick-up and Slack-off weights. 99. Rig up pump in sub on top of the 3-1/2” production tubing and break circulation at low pump rate. The recommended pump rate should be low ~1bpm or less. 100. Initiate circulation, confirm returns on the “back side” and start slacking off completion string while observing pressure on the pressure gauge in anticipation of the sudden pressure increase due to seal assy. entering 7” x 5” Liner Hanger x-over to lower PBR. 101. Be prepared to immediately shut off the pumps. 102. Once that tubing pressure increase is observed shut the pumps immediately and bleed- off any remaining pressure in tubing. That pressure increase is an initial positive indicator confirming that the seals of the 4” seal assy. are entering lower PBR. 103. Continue lowering completion string and carefully monitor the string weight on the weight indicator. It is anticipated to see an indication when each set of seals enters the lower PBR. This is the second positive indication that we are approaching desired depth w/upper completion. 104. Once the Seal Stem locator reaches the final depth inside the Liner Hanger assembly ... set ~10-15klbs. down to confirm expected and correct position inside the Liner Hanger assembly. 105. Pick up to neutral weight + 2’ from full engagement. Mark pipe to establish space out. 106. PU install space out pups one joint below tubing hanger. 107. Terminate control lines and tie into tubing hanger. PT control lines to 5,000 psi. 108. Install ¼” Swagelok fitting and ¼ turn valve. Pressure up to 5,000 psi and lock in pressure to keep SSSV open while landing the tubing hanger. 109. Land tubing hanger. Test SSSV control line and chemical injection line at 5,000 psi. 110. PT annulus to 2,500 psi per AOGCC requirement and record on chart for 15 minutes. ND BOPE/RDMO 111. Install BPV. 112. ND 13-5/8” BOP. Install plug off tool in BPV. 113. Confirm correct orientation of flow cross prior to tightening studs and nuts. NU and pressure test 4-1/16” 5K tree to 5000 psi. 114. Retrieve BPV and plug off tool. 115. Perform a slick line gauge ring run to the top of the float collar at ~8,674’ MD. 116. Release to Production. Rig released at this time. Pressure test tubing and liner to 3500 psi (>MPSP). -bjm 22 Contingent Coiled Tubing Cleanout 117. If it is not possible to drift the liner to the deepest desired perf interval as indicated by the slickline drift, it is planned to perform a coiled tubing cleanout of the liner. RU coiled tubing and pressure control equipment. Pressure test BOPs at 250 psi, 4,000 psi. 118. RIH with bit and motor. 119. Cleanout to below deepest planned perforation interval. 120. POH. Rig down coiled tubing. Run Cement Bond Log 121. Contact Halliburton cementer for impedance value for the cement versus time. 122. R/U E-line and run CBL. Put log on depth tying into the original open hole log dated June 19, 2018. Perforate Beluga Zones 123. With a full column of water in the completion the well should be under balanced for perforating in the lower higher pressure interval. Plan to displace cement with kill weight fluid and change well over to sea water above the tested liner hanger. Plan on perforating the higher-pressure interval first and allowing it to purge the well of fluids and then perforate the lower pressured interval against a column of gas. Could pull the deepest GLV, displace tubing with gas or N2 taking returns off the A annulus. 124. Install catcher. Pull dummy gas lift valves. Install live gas lift valves. 125. Based on log analysis, select zones to be perforated. 126. Rig up electric line logging unit (Alaska E-Line). 127. Test tools (CCL and perforating circuit). 128. Rig up and pressure test lubricator to 250/4,000 psi. 129. Open swab valve and master valves. 130. Perform drift run. Minimum ID 2.813”. 131. RIH w/ CCL and perforating guns. 132. Correlate and fire perforating guns. 133. Make multiple trips as required. 134. After perforating runs are completed, rig down lubricator and electric logging unit. 135. Put well on production. Separate sundry required for perforating. -bjm Submit CBL to AOGCC and obtain approval prior to perforating. -bjm 23 10.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. o The highest reservoir pressure expected is 3,890 psi @ 7,414’ TVD in the Beluga lower sand. MASP is 3,486 psi with 0.055 psi/ft gas in the wellbore. o A casing test to 3,500 psi is planned as part of the pre rig work. 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. AOGCC Contact Information: x Jim Regg / AOGCC Inspector/ (O): 907-793-1236 / Email: jim.regg@alaska.gov The highest reservoir pressure expected is 3,890 psi @ 7,414’ TVD in the Beluga lower sand. MASP is 3,486 psi with 0.055 psi/ft gas in the wellbore. 24 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) 11.BOP N/U and Test 1. N/D Tree master valve and adapter (BPV and PX plug installed as part of pre-rig work), inspect landing threads in tubing hanger. Make dummy run to check threads. Install plug off tool. 2. Check the full drift of any spacer spools used several days prior to installation. 3. N/U to 13-5/8" 5M X 13-5/8” 5M spool. 4. 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 valves on the inside of the kill side of mud cross. Manual valve used on the outside or "master valve". o Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 5. 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 Ensure to 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. Confirm the correct valves are opened. o Test VBRs on 4.5" test joint (5,000 psi) See attached permit to drill. o Test Annular on 4.5" test joint (2,500 psi). o Ensure gas monitors are calibrated and tested in conjunction w/ BOPE. 25 12.Attachment 1: KLU A-1 Pore Pressure/Frac Gradient 25 26 13.Attachment 2: 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. Hole Cleaning: Maintain rheology w/ viscofier as necessary. Sweep hole w/ 20 bbls Barazan (xanthan gum biopolymer) as necessary. Optimize solids control equipment to maintain density and 27 minimize sand content. Maintain programmed mud specs. Recommended flow rate in 6.75” hole is 200 to 330 GPM. The wellbore will be cleaned with a low vis(water), hi vis weighted sweeps. Monitor returns closely for signs of gas and circulate out all gas cut mud before continuing drilling. Anticollision: No close approaches. See directional plan for anticollision analysis. MASP: The highest reservoir pressure expected is 3,890 psi @ 7,414’ TVD in the Beluga lower sand. MASP is 3,486 psi with 0.055 psi/ft gas in the wellbore. 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. 28 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. 14.Attachment 3: FIT Procedure Procedure for FIT: 1. Drill 30' 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. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. 29 15.Attachment 4: BOP Schematic 30 16.Attachment 5: Choke Manifold Schematic 31 32 17.Attachment 6: Tubing Hanger (Current) 33 18. Attachment 7 Wellhead Schematic (Current) 33 34 19.Attachment 8: Rig Information 3535353535353535353535 3633336363666636366666663366666633666666666666666336636666633366666633366666333333333633666636 37 20.Attachment 9: Casing Design Information for Liner Hole Size: 6.75” Mud Density: 9.5-10.6 ppg Planned Top: 3,960’ MD/ 3,133’ TVD Planned TD: 8,772’ MD/ 7,414’ TVD MASP: 3,482 psi (see attached MASP determination and calculation) Collapse Calculation: Normal gradient external stress (0.431 psi/ft) and the casing evacuated for the internal stress. Gas Gradient: 0.055 psi/ft Calculation/Specification Casing OD 3.5” Top (MD) 3,960’ MD Top of Liner Top (TVD) 3,126’ TVD Top of liner Bottom (MD) 8,772’ Bottom (TVD) 7,414’ Length 4,812’ Weight (ppf) 9.2 Grade L-80 Connection JFE Lion Weight w/o buoyancy factor (lbs) 44,270 lbs Tension at top of section (lbs) w/ 10 ppg mud (BF= 0.8473)37,510 lbs Minimal Tensile Strength (lbs) 207,000 lbs Worst case safety factor (Tension w/o BF) 5.5 Collapse pressure at bottom (psi) – 10 ppg mud and gas gradient of 0.055 psi/ft 3,485 psi Collapse Pressure 10,540 psi Worst case safety factor (Collapse) Gas filled tubing 3.02 38 21.Attachment 10: 6-3/4” Hole Section for MASP Planned Top: 4,080’ MD/ 3,133’ TVD Planned TD: 8,772’ MD/ 7,414’ TVD Anticipated Formations and Reservoir Pressures Formation MD TVD Est Pressure (psi) Oil/Gas/Wet PPG Gradient Sterling 3,732’ 2,953’ 1249 Gas 8.13 .4228 Beluga 5,760’ 4,774’ 2050 Gas 8.25 .4290 Planned KOP 4,092’ 3,239’ 1472 Gas 8.73 .4540 Planned TD 8,772’ 7,414’ 3890 Gas 10.1 .525 Assumptions: 1. Fracture gradient is between 13.0 and 17.0 EMW. Fracture gradient at window is based on an FIT of 15.0 ppg EMW at 4,080’ MD/3,133’ TVD. (See pore pressure/frac gradient below). 2. Planned mud density for the 6-3/4” hole section is 9.5-10.6 ppg 3. Calculations assume full evacuation of wellbore to gas from reservoir Maximum Allowable Annular Surface Pressure Assuming Window ( 4,080’ MD/ 3,235’ TVD) is the Weakest Formation: MAASP (psi) = (Fracture MW – Current MW) X .052 X TVD (Window) = = (15.0 – 10.6 ppg) X .052 X 3,133’ TVD = 716 psi Maximum Anticipated Surface Pressure, if there is a complete evacuation of wellbore to gas. MASP (psi) = Formation Pressure psi – [.055(psi/ft) X TVD] = 3,890 psi – [ .055 X 7,414’ TVD] = 3,482 psi Summary: 1. MASP while drilling 6-3/4” production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.055 psi/ft. 39 22.Attachment 11: Permit to Drill Kick Tolerance Evaluation 40 23.Attachment 12: Production Drilling Parameters KLU A-1, KLU A- 2A, KLU 3 4124.Attachment 13: Time vs. Depth 42 25.Attachment 14: KLU A-1A Fluid Program 43 44 45 46 47 48 49 50 51 52 26.Attachment 15: KLU A-1A Directional Program (wp08) 53 54 55 56 57 58 59 60 61 1 Dewhurst, Andrew D (OGC) From:Dewhurst, Andrew D (OGC) Sent:Tuesday, 10 September, 2024 16:24 To:'Mike Stefanov' Cc:McLellan, Bryan J (OGC); Roby, David S (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC) Subject:RE: KLU A-1A (PTD 224-103): Bond Number Mike, Will do. Thanks. Andy From: Mike Stefanov <m.stefanov@furiealaska.com> Sent: Tuesday, 10 September, 2024 16:23 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: RE: KLU A-1A (PTD 224-103): Bond Number Andy, The bond number is correct. Furie consolidated several bonds into one. If you can correct the 10-401 that would be most appreciated. Sincerely, Mike Stefanov Drilling Manager Furie OperaƟng Alaska LLC Tel. +1 615 738 8596 E-Mail: m.stefanov@furiealaska.com Alternate E-Mail: mistefanov@my.lonestar.edu 433 W 9th Avenue Anchorage, AK 99501 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Tuesday, September 10, 2024 3:40 PM To: Mike Stefanov <m.stefanov@furiealaska.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: [EXT] KLU A-1A (PTD 224-103): Bond Number 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 Mike, Would you please conĮrm that the correct bond number for Furie OperaƟng Alaska, LLC is 3145524168? If so, I will correct the 10-401; no other acƟon required. I would like to conĮrm this though. Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon 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. 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 Dewhurst, Andrew D (OGC) From:Mike Stefanov <m.stefanov@furiealaska.com> Sent:Monday, 26 August, 2024 16:05 To:Dewhurst, Andrew D (OGC) Cc:McLellan, Bryan J (OGC); Mike Stefanov; Hunter Van Wyhe Subject:RE: KLU A-1A Revised PTD (224-103): Questions Andrew, We will check the direcƟonal calculaƟon and get back with you. Sincerely, Mike Stefanov Drilling Manager Furie OperaƟng Alaska LLC Tel. +1 615 738 8596 E-Mail: m.stefanov@furiealaska.com Alternate E-Mail: mistefanov@my.lonestar.edu 433 W 9th Avenue Anchorage, AK 99501 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Monday, August 26, 2024 3:53 PM To: Mike Stefanov <m.stefanov@furiealaska.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: [EXT] KLU A-1A Revised PTD (224-103): Questions Mike, We received a revision to the KLU A-1A PTD with a wp07 direcƟonal plan. There may be an error in the direcƟonal plan. At 4,092’ MD, the TVD and TVDSS depths both jump to a shallower depth. Would you please double-check these values? 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 Would you also please conĮrm that the correct/current bond number is 3145524168? Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon 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. 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 Dewhurst, Andrew D (OGC) From:Dewhurst, Andrew D (OGC) Sent:Thursday, 22 August, 2024 14:27 To:Guhl, Meredith D (OGC) Subject:FW: KLU A-1A 10-401 Permit to Drill Resubmittal 08.22.24 Attachments:KLU A-1 ST wp07_Geo True North.txt; KLU A-1 ST wp07_GIS.txt; KLU A-1A 10-401 Permit to Drill Resubmittal 08.22.24.pdf From: Hunter Van Wyhe <h.vanwyhe@furiealaska.com> Sent: Thursday, 22 August, 2024 14:22 To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Mike Stefanov <m.stefanov@furiealaska.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: KLU A-1A 10-401 Permit to Drill Resubmittal 08.22.24 Good aŌernoon, Please see aƩached 10-401 permit to drill applicaƟon for the above referenced well. Well KLU A-1 is planned to be sidetracked to access alternaƟve Sterling and Beluga formaƟon producƟon. Note the change of TD of the well to 8,902’ MD/ 7,414’ TVD. The well will be completed with a 3-1/2” gas liŌƟe-back compleƟon. A separate sundry noƟce will be submiƩed for perforaƟng operaƟons. Drilling operaƟons are expected to commence approximately October 2024. 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 You don't often get email from h.vanwyhe@furiealaska.com. Learn why this is important 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. 1 Dewhurst, Andrew D (OGC) From:Dewhurst, Andrew D (OGC) Sent:Thursday, 22 August, 2024 09:21 To:m.stefanov@furiealaska.com Cc:McLellan, Bryan J (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Roby, David S (OGC) Subject:KLU A-1A PTD (224-103): Questions Mike, I’m compleƟng my review of the KLU A-1A PTD and have two minor quesƟons: x Would you please double-check the MD/TVD depths for the anƟcipated tops for Sterling and Beluga (listed in SecƟon 4 of the PTD). I’m geƫng diīerent TVD equivalent depths for those MDs. x Would you please conĮrm that the correct/current bond number is 3145524168? Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 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. KLU A-1A STERLING UNDEFINED GAS BELUGA UNDEFINED GAS KITCHEN LIGHTS WELL PERMIT CHECKLISTCompanyFurie Operating Alaska, LLCWell Name:KLU A-1AInitial Class/TypeDEV / PENDGeoArea820Unit11120On/Off ShoreOffProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2241030KITCHEN LIGHTS, STERL UND GAS - 470500 KITCHEN LIGHTS, BLUG UND GNA1 Permit fee attachedYes ADL389197 and ADL3891982 Lease number appropriateYes3 Unique well name and numberYes KITCHEN LIGHTS, BLUG UND GAS - 470510 and KITCHEN LIGHTS, STERL UND GAS - 470500 - governed by Stat4 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)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA Sidetrack18 Conductor string providedNA Sidetrack - offshore well19 Surface casing protects all known USDWsNA20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitYes25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedNA27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP = 3486 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 H2S not anticipated. Rig is equipped for monitoring and treatment.35 Permit can be issued w/o hydrogen sulfide measuresYes Overall pore pressures anticipated to be 8.3-9.5 ppg EMW. Depleted zones anticipated in production hole.36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate8/22/2024ApprBJMDate9/11/2024ApprADDDate8/22/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 9/13/2024 NA1 Permit fee attachedYes ADL389197 and ADL3891982 Lease number appropriateYes3 Unique well name and numberYes KITCHEN LIGHTS, BLUG UND GAS - 470510 and KITCHEN LIGHTS, STERL UND GAS - 470500 - governed by Stat4 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)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA Sidetrack18 Conductor string providedNA Sidetrack - offshore well19 Surface casing protects all known USDWsNA20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitYes25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedNA27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP = 3486 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 H2S not anticipated. Rig is equipped for monitoring and treatment.35 Permit can be issued w/o hydrogen sulfide measuresYes Overall pore pressures anticipated to be 8.3-9.5 ppg EMW. Depleted zones anticipated in production hole.36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate8/22/2024ApprBJMDate9/11/2024ApprADDDate8/22/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&: