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Home My WebLink About222-1411. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate CTU Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Log Workover to Pull Completion 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:N/A 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?Statewide Spacing Yes No 9. Property Designation (Lease Number): 10. Field: Undefined Gas Pool N/A 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 3452' 3379' 3314' 1134 psi 2876' 3062' Casing Collapse Structural Conductor n/a Surface 2940 psi Production 4020 psi Production 4760 psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): None N/A 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 Observation 16. Verbal Approval: : GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: William Isaacson Doug Cismoski Contact Email: Contact Phone: 907-242-7483 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 PRESENT WELL CONDITION SUMMARY TVD 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: Perforation Depth TVD (ft): Length Size Burst 3245' 6870 psi MD 6450 psi n/a 5620 psi 117' 2155' AOGCC USE ONLY Tubing Grade: Tubing MD (ft): wisaacson@asrcenergy.com Vice President of Drilling, Projects and Engineering 2/20/2026 Subsequent Form Required: Suspension Expiration Date: 7' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 047450 222-141 3900 C Street Suite 700, Anchorage, AK 50-029-23737-00-00 ASRC Consulting & Environmental Services, LLC Proposed Pools: Hydrate-P1 Will perfs require a spacing exception due to property boundaries? Current Pools: Prudhoe Bay Field 2609' 117' 2199' 3370'3443' 24" 16" x 14" 117' 10-3/4"2640' 2169' 2670' 2916' - 2942' 773' 2856' - 2881' Tubing Size: 9-5/8" 7" Perforation Depth MD (ft): 26# L-80 approval: Notify AOGCC so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearance ons of Approval: ection MIT Req'd? Yes No Subsequent Form Required: Suspension Expiration Date: AOGCC USE ONLY Contact Name: William Isaacson Doug Cismoski Contact Email: Contact Phone: 907-242-7483 e: certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. me and ure with Date:wisaacson@asrcenergy.com Vice President of Drilling, Projects and Engineering 15. Well Status after proposed work: OIL WINJ WDSPL Observation GAS WAG GSTOR SPLUG GINJ Op Shutdown Abandoned proval: : esentative: Date for Operations:2/20/2026 13. Well Class after proposed work: Exploratory Stratigraphic Development Service SSSV Type:Packers and SSSV MD (ft) and TVD (ft): None N/A nts: Proposal Summary Wellbore schematic ations Program BOP Sketch Tubing MD (ft): 7' Tubing Grade:Perforation Depth TVD (ft): 2856' - 2881' Tubing Size: 7" pth MD (ft): 26# L-80 4760 psi6870 psi3370'3443'on 773'9-5/8" 4020 psi6450 psi2609'10-3/4"2640'on 2670' 2940 psi5620 psi2155'2199'16" x 14"2169'e n/an/a117'117'24"117'or al CollapseBurstTVDMDSizeLengthg Junk (MD): 3062'2876' ( ) 1134 psi S ( )Effective Depth TVD:Effective Depth MD: 3314' Total Depth TVD (ft): 3379' D (ft): PRESENT WELL CONDITION SUMMARY esignation (Lease Number): 10. Field: Undefined Gas Pool N/A0 Proposed Pools:Current Pools: Prudhoe Bay Field 8.Well Name and Number: Hydrate-P1 g:N/A ation or Conservation Order governs well spacing in this pool?Statewide Spacing Yes Noquire a spacing exception due to property boundaries? 5. Permit to Drill Number: 6. API Number: 222-141 50-029-23737-00-00 4.Current Well Class: Exploratory Development Stratigraphic Service Suite 700, Anchorage, AK ame: ting & Environmental Services, LLC quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate CTU Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Workover to Pull CompletionLog Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 326-055 By Grace Chistianson at 10:48 am, Jan 26, 2026 BjM 2/6/26 BOP test to 2500 psi 10-407 TS 1/27/26 X Verify no sustained casing pressure on OA before placing surface cement plug. Provide 24 hrs notice for AOGCC witness of wellhead cutoff and cement inside well prior to welding plate. Provide 10 days notice for final site clearance inspection. Photo-document well cutoff, showing cement inside well, marker plate installed and final site clearance. DSR-2/2/26 X JLC 2/6/2026 02/06/26 ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 1 of 1 January 22, 2026 Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval Methane Hydrate Project Well Hydrate-P1 PTD 222-141 Dear Commissioners, ASRC Consulting & Environmental Services, LLC (ACES), as operator of four wells related to a Long- Term Production Test of Methane Hydrates located on the Kuparuk State 7-11-12 pad, submits the following 10-403, to use Nordic Rig 3 for plug and abandonment operations on well Hydrate-P1. On the following pages are the detailed operations program, current wellbore schematic, proposed wellbore schematics, and rig BOP and choke diagrams. Please contact William Isaacson at 907-242-7483 or myself should you have any questions regarding this Sundry. Sincerely, Doug Cismoski, P.E. Vice President of Drilling, Projects and Engineering ASRC Energy Services | Consulting & Environmental 3900 C Street, Suite 701, Anchorage, Alaska 99503 Work: (907) 339-7410 Email: dcismoski@asrcenergy.com | asrcenergy.com OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 1 of 7 To: AOGCC From: William Isaacson / Doug Cismoski P.E. ASRC Consulting & Environmental Services Well Name:Hydrate-P1 API:50-029-23737-00-00 PTD: 222-141 Status:Observation Well: Gas Hydrates Production Test Engineer:William Isaacson, (907) 242-7483 Well Summary: Hydrate-P1, drilled in early 2023, is one of two test wells drilled for the Alaska Methane Hydrate Project on the North Slope. The welldesignincludes16x14 vacuum insulated surface casing cemented to surface, and a 9-5/8 x 10-¾ production casing string with 3 x ¼" stainless steel lines (2 x Fiber Optic Lines and 1 x TEC line)clamped to the exteriorof the casingand also fully cemented to surface. Perforated in the Hydrate B Unit from 2916 2942, Hydrate-P1 was originally completed with several unique components including GeoForm sand control, a downhole heater, surface-controlledisolation valve, andcompatible forboth ESP and jet pump artificial lift. Initially placed on test with an ESP, production became troublesome to keep online at low water rates. In May 2024, the ESP was replaced with a jet pump. Through recycling produced water downhole, the well was able to achieve stable flow. However, decreasing inflow once again halted the test and the jet pump was pulled in August 2024. In July 2025 a workover was performed, pulling the upper and lower completions followed by setting a CIBP above the perforations. After pressure testing the CIBPandcirculating the wellboreto 9.5 ppg NaCL, the well was left witha singlepupjoint of 7 tubingbelow the tubing hanger and the well was left inObservation Well Status. Objective: Plug and abandon the Hydrate-P1 wellbore. Scope: Use NordicRig3to pull the 7 tubing hanger and pup joint, section mill the production casing (including the 3 x ¼" stainless steel lines) and place two cement plugs to permanently abandon the wellbore. Well Information: Max Expected BHP 1277 psi Based on 0.447 psi/ft gradient @ 2856TVD (Top B Unit) MPSP: 1134 psi Based on BHP minus 0.05 psi/ft gas gradient Total depth: 3452 MD / 3379 TVD Plug back depth: 2876 MD / 2816 TVD Perforations: 2916-2942 MD / 2856-2881 TVD (plugged w CIBP, tested to 2000 psi) Planned milling depth: 1950-2050 MD / 1914-2011 TVD Recent Well Work: July 2025 Rig workover pulled upper & lower completions. Set 9-5/8 CIBP at 2876, pressure tested to 2000 psi. OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 2 of 7 OA Pressure Discussion: During the course of the production test of Hydrate-P1 the outer annuls (OA) has seen sustained casing pressure. Repeated bleed attempts have confirmed small volume gas bleeds from a micro-annulus in the fully cemented annulus (all gas, bleeding to 0 psi in <5 minutes). The bleed attempts have been unsuccessful at permanently lowering the OA pressure. It is believed the gas is coming from below the surface casing shoe at 2199 MD and traveling through a micro-annulus in the cement to surface. Procedure: Pre-Rig Work 1. RU pumping equipment. Pressure test the 9-5/8 x 10-¾ casing string and 9-5/8 CIBP / Cement P&A Plug to 1500 psi. 2. RU pumping equipment to 10-¾ x 14 outer annulus. Attempt to establish injectiondown OA via micro-annulus, maintaining pressure below 2000 psi (~50% of 10-¾ collapse pressure rating). If injectivity can be established, pump filtered kill weight brine(9.5 ppg or higher)down OA micro annulus to provide a column of kill weight fluid for upcoming P&A operation. The 10-¾ x 14 annulus was cemented to surface during the original well construction process. Cement evaluation logs show good cement in the annulus, however indicate the possible existence of a mirco-annulus. Rig Work 1. Provide AOGCC 24 hrs notice for P&A operations and for upcoming BOPEtest. 2. MIRU Nordic 3 workover rig. 3. ND tree.ND tubing head adapter. 4. Thread into tubing hanger,pull and LD tubing hanger and7 tubing pup. 5. NU 13-5/8 5k x 16-¾ 3k double stud adapter and 13-5/8 5k wellhead. 6. NU 13-5/8 5k BOP with rams for 4 DP. Test BOP to 250 psi low, 2500 psi high, pull test plug. 7. Notify AOGCC 24 hours prior to P&A operations to allow witnessing pressure test and tag of the CIBP and placement of the cement plug. 8. Pressure test the 9-5/8 x 10-¾ casing and CIBP at 2876 MD to 1500 psi. 9. PU DP cementing string, RIH to CIBP at 2876 MD. Tag plug and set down 10k lbs as confirmation of firm base for upcoming cement plug. Circulate well to 9.4 ppg NaClbrine. 10. RU cement unit, PT lines. 11. Mix and pump ~14.7 bbls 15.8 ppg Class G cement spotting balanced plug of ~200MD in length on top of the CIBP. Minimum required plug length is 75, however conservatively spotting ~200. 200 9-5/8 47# casing =14.7 bbls 12. POH above cement top and circulate drill pipe clean. POH 13. MU casing scraper, RIH to ~2150MD. POH. 14. MU 10-¾ CIBP on drill pipe. RIH and set at 2110 MD. 15. Displace well to milling fluid immediately on top of CIBP and then spot a 16.0 ppg pill on top of CIBP, extending up to approximately the top of planned section mill window.POH. OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 3 of 7 16. MU section milling BHA and RIH. Mill 10-¾ casing section from 1950-2050MD. POH. 17. Notify AOGCC 24 hours prior to P&A operations to allow witnessing of the plug placement and pressure test and tag of the TOC. 18. RIH withDP cementing string. Wash down to CIBP. Circulate well to 9.4ppg NaCl. Milled shavings and cement debris in the rathole below the window may inhibit the ability to reach the CIBP depth. If unable to reach CIBP with cement stinger, the cement plug will be placed from the deepest depth obtained at or below the base of the window. 19. RU cement unit, PT lines. 20. Mix and pump ~59 bbls 15.8 ppg Class G cement spotting balanced plug from CIBP, across section mill window and up to ~1550 MD. 460 10-¾ 55.5# casing @ 42.6 bbls + 100 14 82.5# casing @ 16.1 bbls = 58.7 bbls 21. POH above cement topand circulate drill pipe clean. 22. Close BOP and perform hesitation squeeze. Squeeze pressure will be applied in incremental pressure and time stages. Maximum final squeeze pressure is 1000 psi. Maximum cement displacement to leave TOC at 1850 MD or shallower. Hold final pressure until desired compressive strength is reached. 23. Test cement plug to 1500 psi. Tag TOC with ~10k lbs to confirm location. POH. 24. MU 10-¾ CIBP on drill pipe, set at 250 MD. 25. Mix and pump 15.8 ppg Class G cement untilgood cement returns to surface. 220 10-¾ 55.5# casing to ground level = 19 bbls minimum + excess as required to surface 26. POH flushing drill pipe of cement as required (to mousehole). 27. ND BOP stack and NU dry hole tree. RDMO Nordic 3. Post-Rig Work 1. Notify AOGCC 24 hours prior to final excavation and top-off / tag of surface cement to allow witnessing of the operation. 2. Remove wellhead and well cellar. Complete excavation as needed around the well to allow cutting all casing strings to a minimum depth of 3 below the original ground level. 3. Top-off all casing strings with cement as needed. Photograph casing and cement. 4. Weld marker plate on the outermost casing that meets requirements of 20 AAC 25.120. 5. Backfill the excavated hole and grade to the existing pad level. Attachments: 1. Current Wellbore Diagram 2. Proposed P&A Wellbore Diagram 3. BOPE Diagram 4. Choke Manifold Diagram Verify no sustained casing pressure on OA before pumping surface cement plug. -bjm Photograph marker plate and final site clearance location and include photos in 10-407. OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 4 of 7 OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 5 of 7 OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 6 of 7 OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 7 of 7 Jake Flora ASRC Consulting & Environmental Services, LLC Petroleum Engineer (720) 988-5375 jflora@asrcenergy.com 1 August 21, 2025 Alaska Oil and Gas Conservation Commission Natural Resource Technician 333 W 7th Ave, Suite 100 Anchorage, Alaska 99501 RE: DATA TRANSMITTAL WELL: Hydrate P1 PTD: 222-141 API: 50-133-23737-00-00 Name Type x ϮϬϮϱͲϲͲϱƚƵďŝŶŐƉƵŶĐŚĐŽƌƌĞůĂƚŝŽŶ W& x ϮϬϮϱͲϳͲϱƚƵďŝŶŐƉƵŶĐŚĐŽƌƌĞůĂƚŝŽŶ W&͕>^ x ϮϬϮϱͲϳͲϮϭ,^WE>ηϭ W&͕>/^͕>^͕d/&& x ϮϬϮϱͲϳͲϮϮũĞƚĐƵƚĐŽƌƌĞůĂƚŝŽŶ W& x ϮϬϮϱͲϳͲϮϳ,^WE>ηϮ W&͕>^͕d/&& Data Transfer Folder: 222-141 Hydrate P1 Subfolders: 2025 Hydrate P1 Workover Logs Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: 222-141 T40794 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.21 11:28:54 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________HYDRATE P1 JBR 08/22/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:4 Tested with 7" TJ Grease pump had failed while trying to grease failed valves had to replace the grease pump to retest failed valves. Kill HCR failed greased and cycled passed, Choke HCR failed greased and cycled passed retest. CMV #6 & CMV #13 failed greased and cycled passed. Accumulater precharge avg> 11 bottles @ 993 psi Avg. CH Misc.: 3" Demco valve located on the downstream of the manifold. Test Results TEST DATA Rig Rep:Hanson/WoodsOperator:ASRC Consulting & Environmental Servic Operator Rep:Hammons/McGeehan Rig Owner/Rig No.:Nordic 3 PTD#:2221410 DATE:7/17/2025 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopKPS250718111133 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 12 MASP: 971 Sundry No: 325-360 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 12 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 1 PCH Misc Stripper 0 NA Annular Preventer 1 16-3/4"P #1 Rams 1 7"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"FP Kill Line Valves 2 3-1/8" & 3"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1400 200 PSI Attained P35 Full Pressure Attained P172 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2000 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P27 #1 Rams P9 #2 Rams P9 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1          1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Change Well Status Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ ASRC Consulting & Environmental Services, 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 3452' feet 2876' feet true vertical 3379' feet 3060' - 3314' feet Effective Depth measured 2876' feet n/a feet true vertical 2816' feet n/a feet Perforation depth Measured depth 2916' - 2942'feet True Vertical depth 2856 - 2881feet Tubing (size, grade, measured and true vertical depth) 7" 26# L-80 7' 7' Packers and SSSV (type, measured and true vertical depth) none 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:None. 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Observation Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas Observation Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Jake Flora Contact Email:jflora@asrcenergy.com Authorized Title: Vice President of Drilling, Projects and Engineering Contact Phone: (720) 988-5375 325-360 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 0 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MDSize 117' n/a 5260 psi2199' 0 10-3/4" 9-5/8" 4020 psi 4760 psi 6450 psi 6870 psi 0 00 0 00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-141 50-029-23737-00-003900 C Street Suite 700, Anchorage, AK 3. Address: Pulsed Neutron Log, CCL Tie In Log 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 047450 Prudhoe Bay Undefined Gas Pool Hydrate P1 Plugs Junk measured none none Length 2169' 117'Conductor Surface Production 24" 16" x 14" measured TVD Production Liner 2640' 773' Casing Structural 2615' 3370' 2670' 3343' 2155' Burst Collapse n/a 2940 psi Development Service GINJ SUSP SPLUG Gas Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov BJM 10/3/25 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Cloudy Temperature (°F) 30.0 Wind Road Condition Head Count HSE Daily Summary Operations at Report Time Move Tool trailer for T-Tank containment build / RU SL Lubricator Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Tagged Fill at 2907' SLM (2940' MD) worked down to 2925' SLM (2952' MD) Operations Next Report Period Pre RWO Prep - Tag Fill / Bail Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 10.00 10:00 No operations at this time. 10:00 1.00 11:00 Pollard on Location - 3 man crew, Safety discussion, Permit, discuss parameters of the Job. 11:00 2.00 13:00 Spot in Pollard (Josh Worner-Operator) / walk down location - begin rig up. TIO = 750/1060/430 psi. 13:00 1.00 14:00 Take control of the SSV - removed hose from the SSV panel, hook up Pollard direct to the T-SSV - cycle open/close/open. 14:00 1.00 15:00 On well PT to 2300 psi with triplex / methanol. 15:00 1.00 16:00 RIH w / 0.125" wire / 1.75" RS/QC/5' stem/QC/1.75" KJ/QC/Oil Jars/QC/Spangs/QC/2"x 4' DD bailer / mule shoe / tag at 2900' SLM, set down hard at 2907' SLM / work to 2913' SLM (+27 = 2940' MD) OOH / full of sand - sample. 16:00 1.00 17:00 RIH w same to tag at 2914' SLM / work to 2917' SLM (2944' MD), POOH full of sand. 17:00 1.00 18:00 RIH w same to tag at 2918' SLM / work to 2925' SLM (2952' MD), POOH full of sand/mud. 18:00 1.00 19:00 Secure well, lay down lubricator for night. 19:00 3.00 22:00 Pollard off location. 22:00 2.00 00:00 No operations at this time. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 2.0 Report Start Date: 5/29/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Sunny Temperature (°F) 29.0 Wind Road Condition Head Count HSE Daily Summary Operations at Report Time Safety discussion, Permit, discuss parameters of the Job. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Correlation run with 2.5" GR= (+27' same as KB) Bail down to 2945' SLM - (2972' MD) Operations Next Report Period Drift for MD correction / Bail Sand Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 7.00 07:00 No operations at this time. 07:00 0.50 07:30 Pollard on location / Permit / JSA. 07:30 1.00 08:30 Move tool trailer for T-Tank containment build / RU SL lubricator. 08:30 0.75 09:15 PT with Triplex-Meth / Spill 1/2 gallon methanol - cut O-ring at 7" Otis tree cap. Make Calls to HSE-LRS-Sam. 09:15 0.50 09:45 PT with Triplex-Meth / 2000 psi-good / function SSV / open well/ TIO-730/1040/450 psi. 09:45 0.50 10:15 RIH w/ 2.5" G-Ring, tag at 3-1/2" x 2-7/8" X-Over at 2826' SLM (2853' MD 27 KB ) POOH 10:15 1.25 11:30 RIH w/2.25" x 11' Pump Bailer, tag at 2914' SLM, work to 2927' SLM (2954' MD) POOH - 2/3 full of sand-fluid 11:30 1.00 12:30 RIH w/2.25" x 11' Pump Bailer, tag at 2929' SLM, work to 2932' SLM (2959' MD) POOH - 1/2 full of sand - mud 12:30 1.25 13:45 RIH w/2"x4' DD Bailer Mule shoe, tag at 2929' SLM, falls easy to 2934', work to 2936' SLM (2963' MD) POOH- empty 13:45 0.75 14:30 RIH w/2.5" x 11' Pump Bailer, tag at 2930' SLM, work to 2937' SLM (2964' MD) POOH- Full of mud 14:30 0.50 15:00 RIH w/ 2.5" x 11' Pump Bailer, tag at 2937' SLM, work to 2938' SLM (2965' MD) POOH - Full of mud 15:00 0.75 15:45 RIH w/ 2" x 4' DD Bailer-Mule Shoe, tag at 2938' SLM - work to (2965' MD) POOH - empty 15:45 0.50 16:15 RIH w/ 2" x 4' DD Bailer-Mule Shoe, tag at 2930' SLM - work to 2938' SLM , (2965' MD) POOH - Full of sand-mud 16:15 1.00 17:15 RIH w/ 2" x 4' DD Bailer - Mule Shoe, tag at 2939' SLM, work to 2941' SLM (2968' MD) POOH - 1/2 full of sand - mud 17:15 0.75 18:00 RIH w/ 2" x 4' DD Bailer - Mule Shoe, tag at 2940' SLM, work to 2943' SLM (2970' MD) POOH - 1/2 full of sand - mud 18:00 1.00 19:00 RIH w/ 2" x 4' DD Bailer - Mule Shoe, tag at 2942' SLM, work to 2945' SLM (2972' MD) POOH - Full of sand - mud 19:00 3.00 22:00 RD for the day, lay down Lubricator, secure well. 22:00 2.00 00:00 No operations at this time. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 3.0 Report Start Date: 5/30/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Cloudy Temperature (°F) 23.0 Wind Road Condition Head Count HSE Daily Summary Operations at Report Time Spot equipment / RU Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Bail to 2973' MD / Set ISO Sleeve, T-Plug, Catcher sub - Did Not PT tubing - Pump not available- return in morning - Set T-Tank. Operations Next Report Period Bail, set ISO sleeve, T-plug, Catcher Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 10.00 10:00 No operations at this time. 10:00 1.00 11:00 Pollard on Location - 3 man crew, Safety discussion, Permit, discuss parameters of the Job. 11:00 2.00 13:00 Spot in Pollard (Josh Worner-Operator) / Walk down location - begin rig up. TIO = 750/1060/430 psi. 13:00 1.00 14:00 Take control of the SSV - removed hose from the SSV panel, hook up Pollard direct to the T-SSV - Cycle Open/Close/Open 14:00 0.83 14:50 On well PT to 2300 psi with Triplex / Methanol 14:50 1.00 15:50 RIH w / 0.125" wire / 1.75" RS/QC/5' stem/QC/1.75" KJ/QC/Oil Jars/QC/Spangs/QC/2"x 4' DD Bailer / Mule Shoe / Tag at 2900' SLM, set down hard at 2907' SLM / Work to 2913' SLM (+27 = 2940' MD) OOH / Full of Sand - Sample 15:50 1.17 17:00 RIH w same to tag at 2914' SLM / work to 2917' SLM (2944' MD), POOH full of Sand 17:00 1.25 18:15 RIH w same to tag at 2918' SLM / work to 2925' SLM (2952' MD), POOH full of Sand/Mud 18:15 0.75 19:00 Secure Well, lay down lubricator for night. 19:00 5.00 00:00 No operations at this time. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 4.0 Report Start Date: 5/31/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Cloudy Temperature (°F) 28.0 Wind Road Condition Head Count HSE Daily Summary Operations at Report Time No operations. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary PT Tubing to 2000 psi 15 minutes. Good. Operations Next Report Period Test T-Plug / ISO sleeve Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 7.00 07:00 No operations at this time. 07:00 0.75 07:45 Pollard on location, Permit, JSA, discuss scope. 07:45 2.25 10:00 LRS on location, Permit, JSA, discuss scope / Spot equipment / RU - Filter to Trucking line - pull Meth from tank #941. 10:00 0.17 10:10 Difficulties getting fluid flowing from Tank #941 / Trouble shoot / good / Function test SSV control. 10:10 2.83 13:00 PT LRS to 2800 psi / Open well / TIO = 730/800/450, Start down tubing at 1 bpm (941 tank level = 285 bbls). 47.5 bbls Meth down Tubing / starting to build pressure / some difficulty maintaining suction through filters. 2000 psi T-Pressure / Start test / 2000/784/422. 15 min PT good - / 2025/782/426 - Bleed down lines. Bleed filter skid, start rigging down LRS 13:00 2.00 15:00 Pollard RD SL equipment. They left their equipment on location to move tomorrow. 15:00 2.00 17:00 LRS rigged down off location 17:00 5.00 22:00 LRS brought back residual sand from hoses / filter for disposal on site (T-Tank) 22:00 2.00 00:00 No operations at this time. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 5.0 Report Start Date: 6/1/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Cloudy Temperature (°F) 28.0 Wind Road Condition Head Count HSE Daily Summary Operations at Report Time No operations. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary RU E-line, depth correct to sleeve, punch holes above packer, circulate well through punch holes Operations Next Report Period No operations. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 7.75 07:45 No operations at this time. 07:45 0.25 08:00 LRS on location, begin adjusting hardline from previous night installation. 08:00 0.50 08:30 Open SSV, begin bleeding down tubing pressure w 1/2" hose 08:30 0.50 09:00 "AK E-line on location, (engineer Daniel Johnson). Fill out permit to work. Begin RU. AK E-line has control of SSV. " 09:00 2.00 11:00 ASRC vac truck arrives, empty UR tank 941, 270 bbls methwater now on vac truck. 11:00 1.00 12:00 PT LRS & hardline to 3000 psi, PT lubricator to 2500 psi, pass. 12:00 3.00 15:00 "RIH with 3.63"" GR, tag ACP isolation sleeve, perform tie in log. POOH, MU perforating gun. " 15:00 2.00 17:00 RIH with 2" x 2 ft tubing puncher loaded with (9) 3/8" charges. Pressure tubing to 1000 psi. Tie in to tubing tally using CCL to perforate tubing at 2688-2690'. Tubing pressure 1000 psi, IA pressure 50 psi, fire tubing puncher, no response on IA. Pressure up tubing to 2000 psi, see slow bleed off after 10 minutes. Re-pressure tubing to 2000 psi, see pressure fall off and communication with IA. 17:00 2.67 19:40 Swap SSV control to LRS pump. Begin pumping at 5 bpm, fluid pack at 100 bbls, continue circulating 5 bpm at 500 psi. 19:40 2.33 22:00 Circulation complete, final circ pressure 3 bpm at 200 psi. Total volume pumped 400 bbls 50/50 methwater. LRS rig down hardline, choke skid 22:00 2.00 00:00 No operations at this time. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 6.0 Report Start Date: 6/5/2025 15:00 2.00 17:00 RIH with 2" x 2 ft tubing puncher loaded with (9) 3/8" charges. Pressure tubing to 1000 psi. Tie in to tubing tally using CCL to perforate tubing at 2688-2690'. Tubing pressure 1000 psi, IA pressure 50 psi, fire tubing puncher, no response CCL to perforate tubing at 2688-2690'. Tubing pressure 1000 psi, IA pressure 50 psi, fire tubing puncher, no response on IA. Pressure up tubing to 2000 psi, see slow bleed off after 10 minutes. Re-pressure tubing to 2000 psi, see on IA. Pressure up tubing to 2000 psi, see slow bleed off after 10 minutes. Re-pressure tubing to 2000 psi, see pressure fall off and communication with IA. Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Cloudy Temperature (°F) 27.0 Wind Road Condition Head Count HSE Daily Summary Operations at Report Time RIH W/ 2.125"x10' pump bailer to 2,701' KB Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Bailed sand, pulled catcher sub. Initial T/I/O: 120/120/450 Final T/I/O: 75/150/450 Operations Next Report Period RU Slickline, bail, pull catcher. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 10.50 10:30 No operations at this time. 10:30 0.50 11:00 Permit, JSA, TGSM. 11:00 1.00 12:00 Rig up slickline. 12:00 0.33 12:20 P/T to 2000 PSI, good. 12:20 0.17 12:30 Function SSV. 12:30 0.67 13:10 RIH W/ 3 1/2 GS to 2,666' KB, W/T, POOH no catcher sub, no marks on GS. 13:10 0.58 13:45 RIH W/ 2 7/8 BLB to 2,649' KB, W/T, falls to 2,655', POOH. 13:45 0.50 14:15 Add 10' lubricator. 14:15 0.25 14:30 P/T to 2000 PSI, good. 14:30 0.75 15:15 RIH W/ 2.125"x10' pump bailer to 2,649' KB, W/T, falls to 2,689', W/T, POOH 1/2 full sand. 15:15 0.75 16:00 RIH W/ 2.125"x10' pump bailer to 2,582' KB, W/T, falls through, 2,691, W/T 2,715', POOH full sand. 16:00 0.50 16:30 RIH W/ 2.125"x10' pump bailer to 2,582' KB, W/T, falls through, 2,717' W/T, POOH full mud. 16:30 0.83 17:20 RIH W/ 3 1/2 GS, latch catcher sub at 2,717' KB, pull 30 oil jar licks, shear off, POOH. 17:20 0.50 17:50 RIH W/ 2.125"x10' pump bailer to 2,717' KB, W/T, POOH full fluid 17:50 0.50 18:20 RIH W/ 1.75"x10' pump bailer to 2,717' KB, W/T 2,721', POOH 1/2 full sand 18:20 0.67 19:00 RIH W/ 3 1/2 GS to 2,713' KB, W/T, OOH w bailer. 19:00 0.50 19:30 RIH W/ 3" JDC W/ bolt, to 2,718' KB, W/T, pick up see overpull, spang up 2 times, POOH, no prong. 19:30 2.50 22:00 Lay down lubricator, secure well head. 22:00 2.00 00:00 No operations at this time. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 7.0 Report Start Date: 6/7/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Clear Temperature (°F) 40.0 Wind Road Condition Head Count HSE Daily Summary Operations at Report Time RIH W/ 2.5"x8' pump bailer to 2,700' KB Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Made 12 bailer runs, 1 LIB, and 5 catch runs. Recovered 0.5 bbl sand, unable to latch plug due to fill. Operations Next Report Period Pull prong, plug from 3 1/2" CMD at 2721' Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 7.00 07:00 No operations at this time. 07:00 0.33 07:20 Permit, JSA, TGSM. 07:20 0.67 08:00 Rig up slickline. 08:00 0.33 08:20 P/T to 2000 PSI, good 08:20 0.67 09:00 RIH W/ 2.125"x10' pump bailer to 2,701' KB, W/T 2,718', POOH 1/2 full sand. 09:00 0.67 09:40 RIH W/ 2.125"x10' pump bailer to 2,718' KB, W/T, POOH full fluid. 09:40 0.83 10:30 RIH W/ 3" JDC W/ bolt, sat down at 2,580' KB, W/T, would not pass, POOH. 10:30 0.33 10:50 RIH W/ modified 3" SB W/ bolt and knuckle joint, W/T, falls through 2,580' KB, tag at 2,706', POOH. 10:50 0.67 11:30 RIH W/ 2.125"x10' pump bailer to 2,704' KB, W/T 2,718', POOH 1/3 full sand, rest mud. 11:30 1.00 12:30 RIH W/ 2.125"x10' pump bailer to 2,720' KB, W/T, POOH 1/2 full sand, rest mud. 12:30 0.50 13:00 RIH W/ modified 3" SB W/ bolt and knuckle joint, W/T, falls through 2,580' KB, tag at 2,714', POOH. 13:00 0.50 13:30 2.125" bailer threads are galled, call for bigger bailer. 13:30 0.67 14:10 Bleed gas off IA, SI when fluid packed. Begin pressuring lubricator to 200 psi before opening swab between each run with N2. 14:10 0.50 14:40 RIH W/ 1.75"x10' pump bailer to 2,714' KB, W/T 2,718', POOH 1/2 full sand, rest mud. 14:40 0.50 15:10 RIH W/ 2.5"x8' pump bailer to 2,714' KB, W/T 2,721', POOH 1/3 full sand, rest fluid. 15:10 0.67 15:50 RIH W/ 2.5"x8' pump bailer to 2,716' KB, W/T 2,719', POOH 15:50 0.67 16:30 RIH W/ 3" JDC W/ bolt, sat down at 2,580' KB, W/T, falls to 2,718' KB, W/T, POOH no prong. 16:30 0.50 17:00 RIH W/ 2.5"x8' pump bailer to 2,717' KB, W/T 2,720', POOH 1/4 full sand. 17:00 0.50 17:30 RIH W/ 2.5" LIB, sat down at 2,580' KB, spang through, 2,678', spang through, 2,713', W/T, POOH. 17:30 0.83 18:20 RIH W/ 2.5"x8' pump bailer to 2,689' KB, W/T, falls to 2,700', W/T 2,715', POOH 1/2 full sand, rest thick mud. 18:20 0.50 18:50 RIH W/ 2.5"x8' pump bailer ot 2,713' KB, W/T 2,717', POOH 1/3 full sand rest thick mud. 18:50 0.50 19:20 RIH W/ 2.5"x8' pump bailer to 2,721' KB, W/T 2,725', POOH 1/4 full sand, rest mud. 19:20 0.67 20:00 RIH W/ 2.5"x8' pump bailer to 2,725' KB, W/T, POOH 1/8 full sand, rest muddy water. 20:00 1.00 21:00 RIH W/ knuckle joint and 3" JDC w/ bolt 21:00 1.00 22:00 SDFN, LD Lube. 22:00 2.00 00:00 No operations at this time. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 8.0 Report Start Date: 6/8/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Clear Temperature (°F) 40.0 Wind Road Condition Head Count HSE Daily Summary Operations at Report Time No operations. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Successfully pulled prong, plug from 3 1/2" CMD at 2721'. Operations Next Report Period No operations. Job Time Log Start Time Dur (hr) End Time Code 1 Com 06:00 1.00 07:00 Drive to ASRC. 07:00 0.33 07:20 Permit, JSA, TGSM. 07:20 0.33 07:40 Rig up slickline. 07:40 1.33 09:00 Re-head, cut 50' wire and test, rig up slickline. 09:00 0.33 09:20 P/T to 2000 PSI, good. 09:20 0.83 10:10 RIH W/ 2.5"x8' pump bailer to 2,700' KB, W/T 2,720', POOH full light mud. 10:10 1.50 11:40 RIH W/ 2.5"x8' pump bailer to 2,721' KB, spang down, 5 times and pump up, repeat several times, bailer sticks once, no overpull before or after, POOH full light mud. 11:40 0.83 12:30 RIH W/ 3" JDC, W/T, POOH W/ prong. 12:30 0.50 13:00 RIH W/ 3" JDC and 1.375" swedge to 2,721' KB, W/T, POOH W/O plug. 13:00 0.50 13:30 RIH W/ 3" JDC and 1.375" swedge, W/T, latch plug at 2,721' KB, W/T, slips off, POOH 13:30 0.33 13:50 RIH W/ 2.5"x8' pump bailer to 2,721' KB, W/T, POOH full light mud. 13:50 0.67 14:30 RIH W/ 3" JDC and 1.375" swedge, W/T, latch plug at 2,721' KB, W/T, comes free, gain 25#, POOH W/ plug. 14:30 3.50 18:00 Rig down, secure well head. 18:00 6.00 00:00 No operations at this time. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 9.0 Report Start Date: 6/9/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Clear Temperature (°F) 40.0 Wind Road Condition Head Count HSE Daily Summary Operations at Report Time Begin RU of BOP's Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary RU SLB Coil away from well and perform an AOGCC waived BOP test / Rig up choke and hardline Operations Next Report Period CTU FCO to Bull plug at ~3205' MD-Circulate 9.8 ppg Brine to TxIA Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 7.00 07:00 No operations at this time. 07:00 1.00 08:00 SLB coil spotted CTU #8 (Orlando Supv) night before. Permit, JSA, TGSM. 08:00 4.00 12:00 Rig up CTU away from well to prepare for BOP test on Back Deck. 12:00 0.50 12:30 1.75 Nozzle on - RU to Meth Pup begin Full body test - 250 psi Low / 2500 psi High 12:30 1.00 13:30 AOGCC Guy Cook Waived Witness of BOP - Inner Reel valve test Good 13:30 0.83 14:20 Upper Blind Shears Good /Low 301 psi final-290 psi / High 2632 psi final-2593 psi (5 sec function). 14:20 0.67 15:00 Lower Blind Good / Low 267 psi final-258 psi / High 2684 psi final 2634 psi (5 sec function). 15:00 0.42 15:25 Slips Push 13k / Pull 34k (4 sec function). 15:25 0.58 16:00 Pipes Good- Low - 290 psi final-289 psi / High 2581 psi final 2575 psi (4 sec Function). 16:00 1.00 17:00 Wells Support on location to RU Choke / Hardline. 7"- 3k Tree, using combo Seal rings and Bolts / R45xR46 Ring and Combo Bolts 17:00 0.75 17:45 RD SLB Coil - Wells Support lining up to PT Hardline / Choke / Tree cap to Tiger Tank 2500 psi. 17:45 0.25 18:00 Wells Support good PT to 2500 psi w/ diesel. 18:00 1.00 19:00 Wells Support Complete / SLB CTU back up to well raise mast and RU hardline. 19:00 1.00 20:00 SLB off location / well secure. 20:00 4.00 00:00 No operations at this time. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 10.0 Report Start Date: 7/2/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Clear Temperature (°F) 40.0 Wind Road Condition Head Count HSE Daily Summary Operations at Report Time SLB Mechanic on location - Back in Spare pump Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary FCO Tag at 3195' CTM - Pump went down. Lost FCO - POOH - Reload fluids / Empty T-Tank / Restart tomorrow. Operations Next Report Period CTU Re-FCO / Circulate 9.5 Brine down Tubing up IA Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 6.00 06:00 No operations at this time. 06:00 2.00 08:00 Worley / NES loading fluids for the FCO 580 bbls Double Slick water / 290 bbls 9.5 ppg NaCL / 70 bbls Power Vis. 08:00 0.50 08:30 SLB on location / Permit / Begin RU of BOP's to Well - Injector - BHA. 08:30 1.00 09:30 Worley Vac on location with 290 bbls Slick Water. 09:30 1.00 10:30 SLB BOP's flanged up to the well. 10:30 0.75 11:15 MU BHA - 1.9" x 1.75" Fluted CRC / DCV/ 2-1.75" Stingers / 1.75" JSN (Coil is 1.75" QT-90 / 0.156' Wall/15,110 length - has 850k RFT - 35% Life / Packoffs ~15 k RFT 11:15 0.75 12:00 Take Injector to the well. Position Slick Water and Power Vis at SLB Pump. 12:00 0.75 12:45 Line up with SLW down back side to Closed Coil valve PT backside to Choke trailer 5000 psi / Tripped. 12:45 0.75 13:30 Left side choke is plugged / Trouble shoot / SSV Functioned - 10 seconds. 13:30 0.50 14:00 Line up with SLW down coil PT BOP's, through Companion to Choke 2500 psi - (2750 psi trip). 14:00 0.50 14:30 Open Swab (25-T) Line up with SLW down coil, pressure up through T-punches to IA to 300 psi. Open choke, bring rate up to 1.5 bpm, taking returns from IA at 50 psi downstream, good returns. 220/210/310 / RIH Closed choke / Crack choke open from PIS taking displacement from Tubing to T-Tank / Gas returns to start. 14:30 0.75 15:15 2000' CTD - WTCK - 8k up / 2k RIW / 100/45/305. 15:15 0.25 15:30 150/50/300 psi - Gas returns / Line up down the Coil with SLW 1.5 bpm - 1500 CTP. 15:30 0.25 15:45 30/200/300 psi Starting to get fluid returns with 50 bbls away. 15:45 0.17 15:55 Reduce pump to minimum - RIH, good fluid returns ~55 bbls SLW pumped 15:55 0.17 16:05 2900' CTD / Increase rate to 2 bpm - 2300 psi CTP/50 WHP/ Wtck= 9.5k up / Swap to 5 bbls Power Vis (70 SLW) 16:05 0.25 16:20 2905' CTD RBIH / 3k RIW / 2 bpm-2700 CTP / 90 WHP/317 IAP 16:20 0.25 16:35 3020' CTD - Out Ttail / Gel out of Nzl / POOH-10k Upwt / 2.5 bpm- CTP=3200 / WHP-50/IAP-365/OAP-360 psi 16:35 0.17 16:45 PUH to 2550' CTD / Swap to 5 bbls Power vis / RBIH 16:45 0.08 16:50 3100' CTD / Gel out Nozzle / PUH / pump overheating / PUH to 2900' CTD. 16:50 0.17 17:00 RBIH / 2.3 bpm-3000 CTP/ 65 WHP/ 400 IAP/ swap to Power Vis 1700. 17:00 0.17 17:10 3195' CTM Tag (Bull Plug) - swap to Gel PUH. 17:10 0.08 17:15 3195' Tag, cannot Jet further / Gel at Nzl / Pump Overheating- Pump Down / POOH. 17:15 0.92 18:10 2600' CTD / Close Choke / Continue POOH / Radiator cap lost seal. 18:10 0.33 18:30 Slow down at 250' / Swab checks / 25 Turns on Swab / Close SSV-Master / Blow down Lubricator. 18:30 1.00 19:30 Have Worley Reload Slick Water / NES to have Dirty truck out to take returns. 19:30 1.50 21:00 SLB off location. 21:00 3.00 00:00 No operations at this time. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 11.0 Report Start Date: 7/3/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Clear Temperature (°F) 50.0 Wind Road Condition Head Count HSE Daily Summary Operations at Report Time SLB CTU crew start to RD equipment Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Tag Hard Bottom 3198' CTD (3205' Mec) FCO / Lay in 9.5 ppg NaCL in lower completion / Displace 3/8" and 5/8" Control lines with 9.5 ppg NaCL / Circulate TxIA leaving 9.5 ppg NaCL throughout the well. Operations Next Report Period RD CTU / RU E-Line T-Punch Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 5.00 05:00 No operations at this time. 05:00 1.00 06:00 SLB dropped off a Cement Pump during the night to stage for Coil. 06:00 1.00 07:00 SLB on location. 07:00 1.00 08:00 SLB Mechanic on location - Back in Spare pump. 08:00 1.00 09:00 Remote panel for Spare Pump C-Pump inoperable-C pump runs constantly / RU Iron for both pumps-Tee'd in together / If one goes down, swap to the other. 09:00 0.92 09:55 Prime up Pump-2 with SLW / Trip set at 4200 psi-Tripped/ flow to T-tank/ Close choke to test Iron of both pumps to the Choke / 4200 psi good. 09:55 0.17 10:05 Line up Coil Pump with SLW-down Coil to PIS to Choke - Fill Coil / Open well TIO =20/360/606 psi. 10:05 0.42 10:30 RIH - Crack choke back open / On line down Coil 0.5 bpm - SLW. 10:30 0.33 10:50 2000' CTD Wtck - 7k up / RIW-2.5k / kick up pump to 2.3 bpm- 3400 psi CTP. 10:50 0.33 11:10 2450' CTD / 30 SLW / swap to Power Vis 9 bbls, back to SLW / Coil Pump problems. 11:10 0.25 11:25 3198' CTD (3205' Mech) tag, jet / PUH - 10k / RBIH - Jet - Gel at Nozzle Hard bottom. 11:25 0.25 11:40 2550' CTD - Swap to 5 bbls gel / RBIH / kick up rate 2.5 bpm - 3700 psi CTP. 11:40 0.33 12:00 3198' CTD / Gel out nozzle / Jet / PUH to 2550'- 11k upwt / Swap to 9.5 ppg NaCL 10 bbls. 12:00 0.25 12:15 2950' CTD / Swap to Gel / 3198' CTD PUH Lay in 10 bbls 9.5 Brine / OAP - 800 psi - bled to 400 psi, comes back to 800 psi - thermal? 12:15 1.25 13:30 2400' CTD - Park / lay 38 bbls Power Vis in @80%. 13:30 0.50 14:00 At surface / Close Choke / Check Swab / Safety meeting / Discuss 3/8" and 5/8" Control line Displacement with 9.5 ppg Brine. 14:00 1.00 15:00 Line up Triplex w/Diesel to 3/8" Control line pressure up to 2500 psi, numerous times then bled to down hole. Work to steady rate of 0.25 bpm Shut Down / Pump 9.5 ppg NaCL @ 0.25 bpm - 1100 psi. Pumped steady for 10 minutes. Line is displaced with 9.5 ppg NaCL 15:00 0.50 15:30 Line up Triplex w / 9.5 ppg NaCL down 5/8" Control Line - Pump 0.25 bpm for 10 minutes / 1100 psi. Line Displaced / OAP at 1400 psi, bled to 500 psi, comes back up. Is not affected by pumping. 15:30 1.00 16:30 Line up SLW down Tubing, returns from IA / 38 bbls Gel spotted in Tubing / 5.5 bpm - 600 psi pump pressure. 16:30 0.83 17:20 256 bbls SLW away / Swap to 9.5 ppg NaCL returns to T-Tank / 5.5 bpm - 350 psi Pump pressure. Increase rate to 7.3 bpm / back to 5.5 bpm / 17:20 0.25 17:35 240 bbls 9.5 ppg NaCL away, reduce rate to 1.5 bpm, Sample of Brine at the choke. 17:35 1.92 19:30 273 bbls 9.5 ppg NaCL circulated, shut down. Start on partial RD of CTU. 19:30 0.50 20:00 Coil Leave for the night. Back in morning to finish RD. 20:00 4.00 00:00 No operations at this time. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 12.0 Report Start Date: 7/4/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Clear Temperature (°F) 50.0 Wind Road Condition Head Count HSE Daily Summary Operations at Report Time No operations. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Ak E-Line Tubing Punch from 3191' to 3194' ELMD - in 5.5" Liner above Bull Plug Operations Next Report Period No operations. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 8.50 08:30 No operations at this time. 08:30 1.50 10:00 SLB CTU crew start to RD equipment. 10:00 1.00 11:00 Bled OAP - 1200 psi down to 400 psi, increases back to 800 psi. 11:00 1.00 12:00 Check TIO = 0/0/800 psi. 12:00 2.00 14:00 SLB CTU off location. 14:00 0.50 14:30 AK E-Line on location (Dalebout + 2) Permit / Discuss Job. 14:30 1.50 16:00 RU E-line. 16:00 0.25 16:15 E-line on well, PT to 2500 psi. with Triplex / methanol good. 16:15 0.25 16:30 RIH w/ Cable head/Wt bar/ 2-1/8" CCL/Decentralizer - magnet / 2" OD Puncher / OAL=18.5'. 16:30 0.42 16:55 CCL to top shot - 7.5' / Tag at 3203' ELM - PUH correlate / RBIH. 16:55 0.08 17:00 Tag bottom 3203' ELM / PUH to 3183.5' CCL + 7.5' = 3191' Top Shot- 3194' bottom shot. 17:00 1.50 18:30 3' of punches (12 charges-zero degrees) Titan Charge 2107-42501 / Hole=0.45" / POOH. 18:30 0.50 19:00 E-line is off the pad. 19:00 5.00 00:00 No operations at this time. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 13.0 Report Start Date: 7/5/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Partly Cloudy Temperature (°F) 67.0 Wind 8 mph Road Condition Major Road Work Head Count HSE Daily Summary No Accidents, Incidents, or Spills Reported Operations at Report Time Continue Rig move to 7-11-12 pad. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Continue Rig move from KOC toward 7-11-12 Operations Next Report Period Spot Nordic 3 over PTW-1, Rig up, Test BOPE Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 12.50 12:30 Moving Nordic Rig 3 from Y Pad to Milne Point access road. This portion of the move was under the Conoco contract. 12:30 4.00 16:30 Moved rig off Spine Rd on to Milne Point Turnoff to allow traffic to pass and turn over paperwork from ConocoPhillips to Hilcorp security for continuing the escort. Spent additional time to allow the rig tires to cool down. 16:30 7.50 00:00 Continue moving Nordic Rig 3 from Milne Point access to 7-11-12 pad. Working with 250 mats, setting over culverts and soft spots along the road. Moving mats as rig passes to stay ahead of the rig in order to complete the last mile of rig move. Note: 24 hr. notice for BOPE test given to AOGCC Rep, talked to Adam Earl and provided timing update. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 14.0 Report Start Date: 7/14/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Rain / Partly cloudy Temperature (°F) 62.0 Wind 11 mph Road Condition Major Road Work Head Count HSE Daily Summary No Accidents, Incidents, or Spills Reported Operations at Report Time Continue Rig move to 7-11-12 pad. Spot rig over PTW-1 Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Continue Rig move, spot Nordic 3 over PTW-1, Clean pad, N/U Operations Next Report Period N/U choke and Kill lines, Test BOPs Well work Pre-Job Meeting with all personnel involved Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 9.00 09:00 Continue moving Nordic Rig 3 from Milne Point access to 7-11-12 pad. Working with 250 mats, setting over culverts and soft spots along the road. Moving mats as rig passes to stay ahead of the rig in order to complete the last mile of rig move. Note: Revised 24 hr. notice for BOPE test given to AOGCC Rep, talked to Adam Earl and provided timing update. 09:00 2.50 11:30 Set cutting box in place, place kitchen and equipment in position. 11:30 0.50 12:00 Move Nordic Rig 3 over PTW-1. 12:00 3.00 15:00 Back rig off mats, re-set mats to correct spacing. 15:00 1.00 16:00 R/U Koomey lines and make sure ram doors would open, open ram doors, unable to open ram doors fully. 16:00 2.50 18:30 Re-position Nordic Rig 3 for ram doors. 18:30 5.50 00:00 N/U BOPs. Open pipe ram doors, verify top 7" rams are installed, blind rams bottom. NES Crane arrived 20:30. Load spoolers onto rig floor, spotting in place. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 15.0 Report Start Date: 7/15/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Clear Temperature (°F) 64.0 Wind 11 mph Road Condition Major Road Work Head Count HSE Daily Summary No Accidents, Incidents, or Spills Reported Operations at Report Time Testing BOP's Pipe rams and Annular Pass. 3 failures on surface equipment Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary N/U flanges on choke and kill lines / Attempt to Test BOP's Operations Next Report Period Complete BOP test operations. Circulate well, pull production string. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 12.00 12:00 Secure Ram Doors, N/U Choke and Kill DSA's, choke and kill manual valves w/ choke and kill HCR valves, N/U choke and kill hoses. Simops: Installing spoolers up on rig floor. 12:00 2.50 14:30 Center BOP Stack, Establish RKB to BOP measurements: Annular 16.80, 7" rams 20.80, Blinds 26.83, Install flow riser and inflate air boot, boot failed to hold air. Pull riser and change air boot, reset riser, good test on air boot. 14:30 1.00 15:30 R/U testing lines and purge lines. 15:30 0.50 16:00 Held PJSM on testing BOP. 16:00 8.00 00:00 R/U Test Joint and installation / retrieval tool to screw into blanking plug, set aside same. R/U lines and purge. Attempt to test Blind Rams, lost pressure, trouble shoot issue. Pressure up to 250 psi below blind rams, pressure steadily bleeds down checking all surface equipment. Pressure up to 2500 psi below Blinds, with steady pressure loss at 1 psi per 2 seconds then within 15 secounds pressure dropped rapidly to zero. No indication of surface equipment failure. Decision was made to pull blanking plug, found debris and small knicks in sealing check valve ball within blanking plug. Clean plug, and replace ball and O-ring seal on threads. Reset blanking plug into top of 7" tubing hangr with 7" test joint. With test joint in place, close 7" pipe rams and attempt to test. Witness a 6 psi pressure loss per minute, with a steady pressure loss trend, test failed. Attempt to test annular to 2500 psi, with similar result. Hold call with Drilling Manager, Drilling Engineer, make plan forward to troubleshoot BOPE leak path. Note: AOGCC Adam Earl on location during BOP test operations. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 16.0 Report Start Date: 7/16/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Partly Cloudy Temperature (°F) 55.0 Wind 8 Road Condition Major Road Work Head Count HSE Daily Summary No Accidents, Incidents, or Spills Reported Operations at Report Time Work pipe 5 times, pulled packer free 210 K. PU=144K, down 95K. Circ 270 bbls. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Complete BOP Test. Hang sheaves in middle board and derrick. Displace 9.5ppg NaCl brine with 9.2ppg NaCl brine. Operations Next Report Period POOH, L/D 7" casing and spool cables. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 16.00 16:00 Re-set blanking plug and fluid pack surface equipment. Continue to test BOP. Blanking plug leaking, trouble shoot blanking plug. Pulled blanking plug, change o-ring and add new ball as well as a top o-ring to blanking plug. Test Hydril, 7" casing rams, choke and kill, HCR's and blind rams 250psi / 2500psi. Failed test #6 and #13 (kill HCR and choke HCR). Repaired and retested both HCRs - Good Test. Rig down testing equipment. Test witnessed by Kam St. John with AOGCC. 16:00 1.00 17:00 Held Pre-Job Safety Meeting and Crane operator and swing GBR casing pulling equipment to rig floor. 17:00 3.00 20:00 Held Pre-Job Safety Meeting and hang sheave's in derrick as per Baker and lessons learned. 20:00 1.50 21:30 R/U to IA , Pull test joint, break out XO's. M/U FMC running tool, check pressure on Back pressure valve (BPV) - 0 psi. Pull back pressure valve. 21:30 1.50 23:00 Displace 9.5ppg NaCl brine w/ 9.2ppg NaCl brine, 270 bbl @ 5 bpm w/300 psi until 9.2 ppg returns to pits. 23 bbl to fill the hole. Circulated through the "pre rig" tubing punch holes at 2688-2690' MD (one foot above the 9 5/8" production packer). 23:00 1.00 00:00 Allow well to U-Tube, Monitor well - No Flow. M/U landing joint w/4-1/2" FOSV and crossover to top drive. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 17.0 Report Start Date: 7/17/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Cloudy Temperature (°F) 49.0 Wind E @ 21 MPH Road Condition Major Road Work Head Count HSE Daily Summary Near miss / 1 incident, No Spills reported Operations at Report Time POOH L/D 7" Casing and spooling cables Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Circulate 270 bbl of 9.2 KCl brine. Pull hanger to rig floor. Begin laying down 7" upper completion while hoisting up cable sheave in derrick. RU cable sheave to derrick fingers, lower rope over windwalls, while pulling up downhole heater cable, cable connector to leader line parted allowing the heater cable to fall to the rig floor. Investigate failure. Reinstall connectors, resume pulling completion. Operations Next Report Period POOH, L/D 7" casing and spool cables. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 1.50 01:30 PU landing joint and make up to hanger. Make up landing joint to top drive and set down 10K. Pull up hanger to 220K. Work pipe up and down 5' ten times. Shear packer at 210K. Re-land hanger. Work landing joint through closed annular. 01:30 3.50 05:00 RU circulation equipment. Circulate 270 bbl of 9.2 ppg KCl brine. ICP 240 psi, FCP 372 psi. 05:00 3.00 08:00 Attempt to pull hanger to rig floor. Riser ID at top flange is 14-1/2", hanger OD is 16". Shut well in. PU=140K, SO=100K. Pull flow riser to make modifications. Install flow riser and air up riser boot seal. 08:00 0.50 08:30 Attempt to pull hanger to rig floor, pulled tight. PU=170-190K; SO=100K. 08:30 0.50 09:00 Re land hanger. Make up top drive into landing joint and circulate bottoms up. Pumped at 4 bpm @ 70 psi. Monitor shakers, clean returns. 09:00 0.50 09:30 Suspect a clamp is catching downhole. Make small tubing rotation with top drive (1/8th turn), pull hanger free to rig floor. PU=200K, SO=100K. 09:30 4.50 14:00 PJSM with All Personel, R/U GBR casing equipment, RD secondary choke line. Lay down landing joint, lay down hanger. RU lines to spoolers and cable sheave. 14:00 2.50 16:30 Begin laying down 7" upper completion while hoisting up cable sheave in derrick. 16:30 0.50 17:00 Pull (3) joints of 7" tubing, raise and install ESP & downhole heater cable sheaves to derrick fingers, lower rope over windwalls. While pulling downhole heater cable, cable connector sockets that couple the heater cable to the leader rope parted, allowing the heater cable to fall approximately 80 feet, coiling back to the rig floor. 17:00 1.00 18:00 Cut downhole heater cable into sections and remove from rig floor. 18:00 3.00 21:00 Hold safety meeting discussing exclusion zone on rig floor while pulling cables. Lower downhole heater cable sheave. Cut and redress cable ends, install crimp connectors exposed wire ends and make up couplers from cable to leader line. Install Lewis Snake sleeve coupler over the top of the crimp connectors to provide a secondary back-up at the cable to leader line connection point. Hang heater cable on sheave at rig floor, raise sheave as we pull out heater cable and attach sheave to monkey board. 21:00 3.00 00:00 Pull out of hole laying down 7'' completion while spooling cables on spooling reels. Salamander cable is being ran down into the pipe rack area and cut in 30' sections. Pick up weight 123,000 lbs, from 2900' to 2500'. Hole fill 12bbls. Perform kick drill with kick joint. Recover all clamps and pins. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 18.0 Report Start Date: 7/18/2025 05:00 3.00 08:00 Attempt to pull hanger to rig floor. Riser ID at top flange is 14-1/2", hanger OD is 16". Shut well in. PU=140K, Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Cloudy Temperature (°F) 44.0 Wind W @ 23 mph / Gust 34 mph Road Condition Major Road Work Head Count HSE Daily Summary No Accidents, Incidents, or Spills Reported Operations at Report Time Cutting salamander heat trace cable in half to remove from pipeshed. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Pull upper completion out of the hole, operation complete at 16:00 hrs. Submit 24 hr notice of upcoming BOP testing to AOGCC @ 7/19/25 @ 16:00 / Kam St John waived witness @ 16:30 7/19/2025. Operations Next Report Period Make up cleanout BHA with casing scraper, cleanout across 9-5/8" sand control packer, log across Geoform. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 6.00 06:00 Pull out of hole laying down 7'' completion from 2900' to 450', spooling cables on reels, cutting salamander cable in 30' sections. 07:00 1.00 08:00 Hold morning meeting. Discuss decompletion operations, dropped object safety and lateral movement of dropped objects. Clean rig floor and offload pipeshed. 08:00 0.50 08:30 Lay down 7" completion to 450' to 5.5" XO. 08:30 0.50 09:00 Swap GBR handling equipment & power tongs for 5.5" tubing. 12:00 4.00 16:00 Lay down 5.5" upper completion to 9-5/8" production packer. Observe packer element damage due to partial rolling while unsetting and pulling. Lay down remainder of upper completion to wireline entry guide (all of upper completion removed from wellbore). No notable damage or residue on tubing tail across GeoForm. No visual damage to 5/8" injection line. Note: recovered all clamps and cables. 16:00 1.00 17:00 Counting clamps, securing spoolers with cables. Rig down GBR pipe handling equipment. 17:00 2.50 19:30 Pre-Job Safety meeting ahead of rigging down ESP and downhole heater cables. Install clamps on ESP cable and downhole heater cable, cut lines, dress and install spoolable socket connectors. Install secondary Lewis Snake sleeve over the connections. Using tag line ropes, control cables back to spoolers. Use rig floor tugger line to rig down sheaves from derrick. 19:30 1.50 21:00 Unload clamps out of pipeshed. 21:00 1.00 22:00 Pre-Job Safety Meeting with crane operator and Nordic 3. High winds: unable to remove rig floor spooling units with crane. 22:00 2.00 00:00 Unload completion tubing and tools from pipe shed. Cut up salamander heater cable from 30' lengths to 15' lengths to remove from pipe shed. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 19.0 Report Start Date: 7/19/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Cloudy Temperature (°F) 40.0 Wind W @ 15 mph Road Condition Major Road Work Head Count HSE Daily Summary No Accidents, Incidents or spills Operations at Report Time Finish testing BOPs. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Change rams to 4", test. Run scraper run to 9-5/8" sand control packer. NOTE: 24 hr weekley BOP notice was given, @18:00 hrs, Kam St. John waived witness @19:30 7/20/2025. Operations Next Report Period Log PNL across GeoForm. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 3.00 03:00 Continue removing completion equipment from pipe shed: NORM test all components pulled from the wellbore including all tubing, mandrels, and jewelry. No NORM detected. Hold JSA, set test plug, change 7'' pipe rams to 4'' pipe rams. 03:00 2.00 05:00 Hold JSA, test pipe rams 250 psi low 2500 high, test annular 250 low 2500 high. All tests passed. Witness waived by AOGCC Kam St. John. Pull test plug. 05:00 4.00 09:00 Cut salamander heat trace cable in 15' pieces and remove from pipe shed. Place in trailer van. 09:00 3.00 12:00 Load BHA and 4'' drill pipe in pipe shed. 12:00 1.00 13:00 PJSM, discuss cleanout operation, picking up pipe. Pick up BHA # 1: 2 7/8'' mule shoe (3.438" OD) 2 7/8" drill pipe, (1) joint 30' in length 9 5/8" casing scraper. 4" drill pipe to surface 13:00 3.50 16:30 Pick up drill pipe and trip in hole to 60' above the 9 5/8" sand control packer at 2806', pick up weight 80,000 lbs, slack off weight 71,000 lbs. 16:30 1.50 18:00 Wash down while pumping 4 bpm at 135 psi, nose into packer at 2860', wash to 2892' placing XO at the top of the 9- 5/8" packer. Set down 3000 lbs shouldering out on top of packer, see 80 psi increase in pressure confirming the XO is contacting the 9-5/8" packer. Pick up 3' placing the mule shoe at 2889' (29' below the 9-5/8" packer). Circulate bottoms up at 8 bpm at 455 psi, see a small amount of silty returns at shakers. No fill or obstructions detected. 18:00 2.50 20:30 Pull out of hole, rack back drill pipe, Lay down scraper and 2 7/8'' mule shoe. Note: Performed Trip Drill with 4" XT 39 drill pipe. 20:30 2.00 22:30 Send out Baker tools, rig up to test BOPs. 22:30 1.50 00:00 Pull wear ring, clean up pipe shed. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 20.0 Report Start Date: 7/20/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Cloudy Temperature (°F) 62.0 Wind NW @ 6 mph Road Condition Major Road Work Head Count HSE Daily Summary No Accidents, Incidents or Spills Operations at Report Time Jarring on Lower Completion Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Test BOP, spot crane and remove remaining spoolers from rig floor. Run e-line PNL log across 5-1/2" liner. Make up and run in hole with Baker packer retrieval tool to pull 5-1/2" Lower Completion. Operations Next Report Period Continue fishing operations to recover Lower Completion. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 1.50 01:30 M/U and set test plug per FMC. R/U testing equipment and fluid pack lines, repair surface leak, obtain shell test. 01:30 4.50 06:00 Test BOPE - Hydril, 4" pipe rams, blind rams, choke and kill HCR and manual valves, stand pipe, choke manifold, TIW, IBOP, Top drive valves. All tested to 250 / 2500 psi per Sundry, good test. Note: test was waived witness by AOGCC Kam St. John. 06:00 1.00 07:00 Bleed down all pressure and R/D test lines. 07:00 1.00 08:00 Pull test plug and set wear bushing. 08:00 3.00 11:00 Open roof on rig above pipe shed / rig floor interface, L/D pipe skate controls and handrails. Utilize NES crane to remove spooler's from rig floor. Use crane to set Nordic power tong into pipe shed. Close roof. 11:00 1.00 12:00 Unload tools from rig floor and set floor mats in place. 12:00 3.50 15:30 Stencil 7'' 26# VAM TOP CONDITION B on casing at Hilcorp request, install thread protectors. 15:30 1.00 16:30 Rig up Halliburton wireline. Make up 2'' drift, test CCL, zero CCL at rig floor. Well on trip tank, taking two bbls an hour. 16:30 0.50 17:00 Run in hole to 3153' and tag up on PBTD/possible fill in 5-1/2" liner, pull out of hole. 17:00 4.50 21:30 Lay down drift, Make up TMD 3D pulsed neutron logging tools, log PNL from 3000' to 2700', pull out of hole, rig down e -line. 21:30 0.50 22:00 Bring in (6) 4-3/4'' drill collars, load Baker tools. 22:00 2.00 00:00 Make up Baker packer retrieval tool BHA, Run in hole with stands of 4'' drill pipe to 2797'. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 21.0 Report Start Date: 7/21/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Sunny Temperature (°F) 59.0 Wind N @ 10 mph Road Condition Major Road Work Head Count HSE Daily Summary No Accidents, Incidents or Spills Operations at Report Time RIH with dress mill with packoff overshot. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Cut tubing with Spectra 4.5" jet cutter, attempt to pull packer and Geoform. Operations Next Report Period Run in hole to overshot, dress cut joint above GeoForm, engage with overshot and pull GeoForm. Set cast iron bridge plug, pressure test plug. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 0.50 00:30 Held Trip drill, PJSM on stinging in and out of packer with no circulation. 00:30 3.00 03:30 Engage packer with collet @ 2866'. Pick up 84,000 lbs, set down 10,000 lbs, pull 12,000 lbs to open jars, pull to 110,000 lbs and shear packer. Pick up to 115,000 lbs and work up to 130,000 lbs, release packer. Allow packer gas to migrate out of well for 10 minutes, release collet from packer and engage square thread to allow for jarring. Stage jarring from 190,000 lbs and straight pull to 300,000 lbs. No movement. 03:30 1.50 05:00 Perform Nordic policy derrick inspection after 50 hits of jarring. 05:00 2.50 07:30 Jarring @ 200,000 lbs and straight pull to 350,000 lbs. Estimate 1' of upward movement. 07:30 0.50 08:00 Perform Nordic derrick inspection. 08:00 2.00 10:00 Jar on packer and GeoForm 200,000 lbs and straight pull to 375,000 lbs. 10:00 1.00 11:00 Perform Nordic derrick inspection. 11:00 2.00 13:00 Pull out of hole with drill pipe from 2966' to 643', rack back BHA in derrick. 13:00 2.00 15:00 PJSM with all personnel and Yellow Jacket Wireline. Rig up E-line, run in hole w/ bar and CCL, tag at 3126', log from 3126' to 2600', tie in log to lower completion tally, pull out of hole, send log to town to confirm correlation. 15:00 1.00 16:00 Lay down weight bar, make up 5-1/2" jet cutter (4.25" OD), Run in hole, correlate, cut 5-1/2" tubing 3' below GeoForm at 2952'. 16:00 1.50 17:30 Make up 2nd 5-1/2" jet cutter, run in hole , cut tubing at 2952', pull out of hole, rig down E- line. 17:30 1.50 19:00 Make up BHA #3, packer retrieving tool, run in hole to 2864', up weight 83,000 lbs, Down weight 75,000 lbs. Note: Submit 24hr AOGCC notice of cast iron bridge plug pressure test, AOGCC confirmed they will witness. 19:00 1.00 20:00 Engage retrieval tool, attempt to jar packer free, set jars off at 285,000 lbs, straight pull to 350,000 lbs, set off jars 40 times. No movement, behaving similar to jarring attempts prior to tubing jet cut. 20:00 2.50 22:30 Release packer retrieval tool, pull out of hole, Lay down BHA. 22:30 1.50 00:00 Rig up yellow jacket E-line, make up 5-1/2" spectra jet cutter (4.25" OD), run in hole, cut tubing in middle of 20' pup joint below packer at 2882', pull out of hole. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 22.0 Report Start Date: 7/22/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Cloudy Temperature (°F) 44.0 Wind W @ 15 mph Road Condition Major Road Work Head Count HSE Daily Summary No Accidents, Incidents or spills Operations at Report Time Jarring on GeoForm, setting jars off at 28k Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Ran 3 overshots, jarring at 280,000 lbs, pulling up to 350,000 lbs, attempt to free GeoForm. Operations Next Report Period Fish and recover GeoForm, perform PNL logging run with Halliburton. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 1.50 01:30 Make up BHA # 4, packer retrieving tool, run in hole to 2864' up weight 83,000 lbs, down weight 75,000 lbs. 01:30 1.00 02:30 Latch into packer, pull to 150,000 lbs, work string, pull 150,000 lbs, packer pulled free. 02:30 0.50 03:00 Monitor well, let gas break out, well back to taking fluid. 03:00 2.00 05:00 Pull out of hole , follow trip speed per procedure, lay down packer and 10' cut joint. 05:00 1.00 06:00 Perform post jarring inspection, service top drive, found broken roll pin on door hinge, replace roll pin. 06:00 2.00 08:00 Make up BHA # 5: (6) 4-3/4" DCs, jars, bumper sub, accelerator, overshot w/ 5.5" grapple, cut lip guide. Run in hole to 2870'. 08:00 2.50 10:30 Pick up single, make up top drive, rotating weight 80,000 lbs, dress off tubing stump, work grapple over tubing stump, pull up weight 87,000 lbs, observed gas at surface. 10:30 0.50 11:00 Monitor well, let gas break out, well back to taking fluid. 11:00 3.00 14:00 Pull out of hole, follow trip speed requirements, no GeoForm screen, inspect overshot, found dent in cut lip guide. 14:00 0.50 14:30 Consult with town. 14:30 2.00 16:30 Run in hole BHA # 5(same as BHA #5): (6) 4-3/4" DCs, jars, bumper sub, accelerator, overshot w/ 5.5" grapple, cut lip guide to 2870'. 16:30 1.50 18:00 Top of tubing cut off is 2877', work grapple over tubing stump, Set jars off at 280,000 lbs pulled free. 18:00 0.50 18:30 Derrick inspection. 18:30 4.00 22:30 Pull out of hole at controlled trip speed, no GeoForm, grapple pulled off. 22:30 0.50 23:00 Rig service, inspect top drive, grease wash pipe. 23:00 1.00 00:00 Make up BHA #6 (6) 4-3/4" DCs, jars, bumper sub, accelerator, overshot w/ 5.5" grapple, 3' millout extension, burn shoe. Run in hole. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 23.0 Report Start Date: 7/23/2025 08:00 2.50 10:30 Pick up single, make up top drive, rotating weight 80,000 lbs, dress off tubing stump, work grapple over tubing s pull up weight 87,000 lbs, observed gas at surface. Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Partly Cloudy Temperature (°F) 49.0 Wind E@ 15 mph Road Condition Major Road Work Head Count HSE Daily Summary No Accidents, Incidents or spills Operations at Report Time Jarring on GeoForm, setting jars off at 280,000 lbs. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Ran two overshot runs, work on topdrive, change out jars and drill collars. Operations Next Report Period Fish and recover GeoForm. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 1.00 01:00 Continue run in hole BHA #6, Pick up weight 85,000 lbs, slack off weight 75,000 lbs. 01:00 2.50 03:30 Rotate and circulate down over tubing stump to 2878', engage fish. Continue pumping at 2 bpm and initiate jarring at 280,000 lbs, pull to 350,000 lbs - 370,000 lbs, move up hole 1.5'. Discover broken fitting on topdrive grabber box, release overshot, lay down single to bring down top drive to work on broken fitting on grabber box. 03:30 1.00 04:30 Perform post jarring inspection. 04:30 4.50 09:00 Change out washpipe. Cap grabber box hydraulic lines, test washpipe. 09:00 1.50 10:30 Rotate down over tubing stump at 2878', jar at 280,000 lbs, Straight pull to 350,000 lbs, after jarring 4 times the grapple pulled off, unable to re-engage grapple. 10:30 3.50 14:00 Pull out of hole, lay down 4 3/4'' DCs, jars, bumper sub, accelerator jars, overshot. Inspect grapple, teeth worn flat from releasing off of fish to repair topdrive. 14:00 2.00 16:00 Unload 4 3/4" drill collars and tools from pipe shed, rack and tally 6 1/4'' drill collars, bring in new jars. 16:00 3.00 19:00 Make up BHA #7, overshot with 2' extension above grapple, bumper sub, oil jars, (6) 6 1/4 '' drill collars, accelerator jars, run in hole with 4'' drill pipe to 2780' up weight 90,000, slack off weight 80,000 lbs. 19:00 2.50 21:30 Slip and cut 66' of drilling line, reset block height. 21:30 1.00 22:30 Tag tubing stump at 2877', rotate down over tubing while pumping 2 bpm, engage grapple, do not see pressure increase while engaging fish. While continuing to pump initiate jarring; set jars at 280,000 lbs, straight pull to 350,000 lbs. Setting 40,000 lbs down to cock jars. 22:30 1.00 23:30 Jarring inspection while remaining engaged with fish. 23:30 0.50 00:00 Continue jarring, set jars off at 280,000 lbs, straight pull to 350,000 lbs. Gained a few inches of upward movement. No downward movement has been seen while setting 40,000 lbs down to cock jars. Continue to pump at 5 bpm while jarring. Fish has moved approximately 20" total by end of day. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 24.0 Report Start Date: 7/24/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Sunny Temperature (°F) 42.0 Wind E@ 12mph Road Condition Loose gravel, dust Head Count HSE Daily Summary No Accident , Incidents or spills Operations at Report Time Jarring on GeoForm while circulating. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Move GeoForm up hole 20'', circulating some GeoForm chunks out. Operations Next Report Period Continue fishing operations and recover GeoForm. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 6.00 06:00 Continue jarring, set jars off at 280,000 lbs, pull up to 370,000 lbs, jar 50 times, inspect derrick, 4 sets, total 200 times jarring, moved GeoForm up hole 0-4'' during each jarring set. No downward movement, pumping at 2-5 bbls per minute. 06:00 6.00 12:00 Continue jarring, set jars off at 290,000 lbs, pull up to 375,000 lbs, jar 50 times, inspect derrick, 4 sets, total 200 times jarring, moved GeoForm up hole 0-4'' with each jarring set. No downward movement, pumping at 10-14 bbls minute, 1000psi. Recover some GeoForm and sand over shakers. GeoForm pieces ranging from 1-2" in length by 0.5"-1" in width. 12:00 6.00 18:00 Continue jarring, Set jars off at 290,000 lbs, pull up to 375,000 lbs, jar 50 times, inspect derrick, 4 sets, total 200 times jarring, moved GeoForm up hole 0-4'' with each jarring set. No downward movement, pumping at 10-14 bbls minute, 1000 psi, recover some GeoForm and sand over shakers. 18:00 6.00 00:00 Continue jarring, set jars off at 290,000 lbs, Pull up to 375,000 lbs, Jar 50 times, inspect derrick, 4 sets, total 200 times jarring, moved GeoForm up hole 0-4'' with each jarring set, no downward movement. Pumping at 10-14 bbls minute, 1000 psi, some GeoForm over shaker and sand. 24hr total: 800 times jarring today, moved GeoForm up hole 20". Total upward movement to date is 40". Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 25.0 Report Start Date: 7/25/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Sunny Temperature (°F) 40.0 Wind E@ 15 mph Road Condition Loose gravel, dust Head Count HSE Daily Summary No Accidents, Incidents or spills Operations at Report Time Working cut off tubing tail to bottom. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Jar on GeoForm, pull free, pull out of hole and lay down GeoForm, run in hole with mill, work tubing tail to bottom. Operations Next Report Period Perform PNL log, set bridge plug and test. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 9.00 09:00 Continue jarring, set jars off at 290,000 lbs, Pull up to 375,000 lbs, Jar 50 times, inspect derrick. Perform 6 sets of 50 jar hits, moved GeoForm up hole 0-4'' with each jarring set, no downward movement. Pumping at 10-14 bbls per minute, 1000 psi, some GeoForm and sand over shakers. Total upward movement to date is 50". 09:00 5.50 14:30 Perform jar sequence at 0900hrs, set off jars at 290,000 lbs, pull to 355,000 lbs, see weight slowly fall off to 255,000 lbs and then fall sharply to 92,000 lbs. Now have additional 2,000 lbs string weight. Suspect GeoForm free, pull out of hole at controlled rate. 1750 total jar hits after starting Geoform fishing operation. 14:30 0.50 15:00 Confirm GeoForm fish is recovered, take pictures of GeoForm as it passes through the rig floor, wrap in shrink wrap and lay down. 15:00 1.00 16:00 Off load Baker tools, check turn-buckles on torque tube. 16:00 1.50 17:30 Make up 5.5'' pilot mill with skirted wash shoe (8.5" OD x 7" ID), bumper sub, jars, (6) 6 1/4'' drill collars, accelerator. Run in hole. 17:30 0.50 18:00 Kick drill, service rig. 18:00 1.50 19:30 PJSM, run in hole to 2930', up weight 92,000 lbs, slack of weight 92,000 lbs. 19:30 1.50 21:00 Wash down to 2953', SPP 200 psi, Torque 1500 to 2600 ft-lbs. Minimal torque response, suspect we are rotating the entire 5-1/2" liner, slowly pushing it down. 21:00 1.00 22:00 Service wash pipe, tighten hammer unions on top drive kelly hose. 22:00 2.00 00:00 Wash and work cut off tubing tail down to 2974' with 80 RPM, circulating pressure 300psi. Fish continuing to move downward while rotating. Plan to push to bottom. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 26.0 Report Start Date: 7/26/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Partly Cloudy Temperature (°F) 41.0 Wind Calm Road Condition Loose gravel, dust Head Count HSE Daily Summary No Accidents, Incidents or spills Operations at Report Time Lay down drill pipe. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Wash and push cut off tubing tail to PBTD, perform PNL log, set 9-5/8" bridge plug and test to 2000 psi. Operations Next Report Period Nipple down BOPs. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 1.00 01:00 Wash and work cut off tubing tail down to 2974' with 80 RPM, circulating pressure 300psi. Fish continuing to move downward while rotating to 3062'. 01:00 1.50 02:30 Circulate hole clean, 9 BPM, 465 psi circulating pressure. 02:30 0.50 03:00 Flow check, blow down top drive. 03:00 3.00 06:00 Pull out of hole, lay down drill collars, jars, bumper sub, burn shoe, pilot mill. 06:00 0.50 06:30 Unload drill collars and GeoForm from pipe shed. 06:30 2.00 08:30 PJSM with Halliburton E-line, rig up, run in hole with 2'' drift to 3025', pull out of hole. 08:30 3.50 12:00 Run in hole with PNL logging tool (1.69" OD), log from 3025' to 2700', pull out of hole, rig down E-line. 12:00 1.00 13:00 Off load Baker tools from rig floor. 13:00 2.50 15:30 Make up mechanical setting tool, Baker 9-5/8" bridge plug, run in hole to 2853'. 15:30 1.50 17:00 Fill pipe, unable to set bridge plug, lower slips failing to hold. Set weight on bridge plug, lower slips finally bite at 2894', set bridge plug. Release off bridge plug, lay down single. 17:00 1.00 18:00 Rig up to test, pressure up to 900 psi, pressure bled off suddenly, suspect bridge plug failed/moved downhole. Run in hole to below perforations at 2960', bridge plug not tagged. 18:00 2.00 20:00 Pull out of hole, lay down mechanical setting tool. 20:00 0.50 20:30 Rig service. 20:30 2.00 22:30 Make up hydraulic setting tool, 9-5/8" bridge plug, run in hole to 2847'. 22:30 1.00 23:30 Pick up single joint of drill pipe, place bridge plug on planned setting depth, drop ball, pressure up to 3290 psi, set bridge plug at 2876'. Set down 40k to verify in place. 23:30 0.50 00:00 Lay down single, rig up to test bridge plug. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 27.0 Report Start Date: 7/27/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Partly Cloudy Temperature (°F) 48.0 Wind W@5 mph Road Condition Loose gravel, dust Head Count HSE Daily Summary No Accidents, Incidents, 1 Spill Operations at Report Time Nipple down BOPs. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Test bridge plug, displace brine to 9.5ppg. Lay down drill pipe to 300', freeze protect 300' to surface with 60/40 methwater, land hanger, run in lockdown screws. Operations Next Report Period Back rig off well, remove BOPs, install tree. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 1.00 01:00 Test casing against bridge plug to 2000 psi for 30 min, lost 20 psi. 01:00 1.00 02:00 Displace well to 9.5 ppg brine. 02:00 1.00 03:00 Blow down lines, rig down test equipment. 03:00 3.00 06:00 Lay down drill pipe from 2851' to 300'. 06:00 1.00 07:00 PJSM, displace top 300' to 60/40 methanol/water. 07:00 0.50 07:30 Lay down 4" drill pipe. 07:30 1.50 09:00 Pull wear ring, unload 4" drill pipe from pipe shed. 09:00 0.50 09:30 Make up tubing hanger with one joint 7" 26# tubing (7' in length), drain BOP stack, land hanger, run in lockdown screws. 09:30 1.50 11:00 Set BPV, test BPV 250 psi low, 2000 psi high, rig down test equipment. 11:00 4.00 15:00 Rinse out BOPs, pump deep clean rinse through rig equipment, flush all lines. 15:00 9.00 00:00 PJSM, Nipple down flow riser, open ram door and remove 4" pipe rams, remove blind rams, nipple down BOPs, clean rig pits. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 28.0 Report Start Date: 7/28/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Rain Temperature (°F) 40.0 Wind W@ 5 mph Road Condition Loose gravel, dust Head Count HSE Daily Summary No Accidents, Incidents or spills Operations at Report Time Load out equipment. Clean around wells. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Back rig off well, Crane off BOPs, install tree and test. Install well houses. Operations Next Report Period Move rig to Deadhorse Nordic yard. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 6.00 06:00 Remove rams from BOPs. Rig down choke and kill lines. Remove annular hang in cellar. Back rig off well, set annular on mats. 06:00 5.50 11:30 Crane off BOPs set on truck. Install tubing head adapter and dry hole tree. 11:30 0.50 12:00 Test THA void to 3000 psi for 15 mins. 12:00 4.00 16:00 Pull BPV, test tree 500 psi low, 3000 psi high 15 min. 16:00 2.00 18:00 Level area around wells, set 6'' by 6'' around well. Install well houses. 18:00 1.00 19:00 Bleed down all 4 wells (surface, annulis) - record pressures. 19:00 5.00 00:00 Pick up rig mats and load out. Pick up liner, stack 12'' by 12'' timbers. Clean up pad. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 29.0 Report Start Date: 7/29/2025 Page 1/1 Well Name: Hydrate-P1 Report Printed: 8/19/2025www.peloton.com Daily Operations Report (Workover) Operator ASRC Energy Services Alaska API/UWI 50-029-23737-00-00 Pad Name Kuparuk State 7-11-12 Pad State/Province Alaska Weather Rain Temperature (°F) 40.0 Wind W@ 5 mph Road Condition Wet Roads and washed road Head Count HSE Daily Summary No Accidents, Incidents or spills Operations at Report Time Continue to load out and secure 7-11-12 pad. Contractor Nordic-Calista Rig # 3 Last Casing String Production, 3,443.5ftKB Operations Summary Backload all equipment and secure pad. Operations Next Report Period Move rig to Deadhorse Nordic yard. Job Time Log Start Time Dur (hr) End Time Code 1 Com 00:00 10.00 10:00 Backload equipment, secure pad for rig move. Walk Nordic 3 to edge of road. Security arrived @ 09:00 hrs. 10:00 14.00 00:00 Nordic 3 off pad and on Spine Road, begin moving to CCI in Deadhorse. ETA 10:00 AM Friday morning 8/1/2025. Multiple locations along Spine Road required rig mats to be placed, totaling 375 rig mats used. Equipment Pressure Tests Date Test Type Comment Next Test Date Report #: 30.0 Report Start Date: 7/30/2025 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate CTU Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Log Workover to Pull Completion 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:N/A 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?Statewide Spacing Yes No 9. Property Designation (Lease Number): 10. Field: Undefined Gas Pool N/A 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 3452' 3379' 3314' 971 psi none none Casing Collapse Structural Conductor n/a Surface 2940 psi Production 4020 psi Production 4760 psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker 9-5/8" x 3-1/2" / 2-3/8" hydraulic set twin packer Packer- 2692' MD / 2554' TVD; SSSV- 2648' MD/ 2511' TVD 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 Observation 16. Verbal Approval: : apporval for tubing punch GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Jake Flora Contact Email: Contact Phone: 720-988-5375 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 10-3/4"2640' 2169' 2670' See attached schematic 773' See attached schematic Tubing Size: 9-5/8" 7" Perforation Depth MD (ft): 26# L-80 24" 16" x 14" 117' 2615' 117' 2199' 3370'3443' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 047450 222-141 3900 C Street Suite 700, Anchorage, AK 50-029-23737-00-00 ASRC Consulting & Environmental Services, LLC Proposed Pools: Hydrate-P1 Will perfs require a spacing exception due to property boundaries? Current Pools: Prudhoe Bay Field AOGCC USE ONLY 6/3/2025 Tubing Grade: Tubing MD (ft): JFLORA@ASRCENERGY.COM Vice President of Drilling, Projects and Engineering 7/15/2025 Subsequent Form Required: Suspension Expiration Date: 2692' 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: Perforation Depth TVD (ft): Length Size Burst 3245' 6870 psi MD 6450 psi n/a 5620 psi 117' 2155' PRESENT WELL CONDITION SUMMARY TVD MPSP (psi): Perforate Repair Wepair Well Stratigraphic Development Service BOP TestMechanical Integrity Test No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Doug Cismoski Digitally signed by Doug Cismoski Date: 2025.06.12 13:20:57 -08'00' 325-360 By Grace Christianson at 3:23 pm, Jun 12, 2025 Plug to be set no more than 50' above the top of perforated interval. BJM 6/16/25 BOP test to 2500 psi 10-407 X DSR-6/18/25 Provide 24 hrs notice to AOGCC for opportunity to witness test of CIBP to 2000 psi. X Bryan McLellan SFD 7/01/2025 Observation ($8 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.07.01 15:24:56 -08'00'07/01/25 RBDMS JSB 070225 ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 1 of 1 June 11, 2025 Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval MHP Well Hydrate-P1 PTD 222-141 Dear Commissioners, ASRC Consulting & Environmental Services, LLC (ACES), as operator of four wells related to a Long- Term Production Test of Methane Hydrates located on the Kuparuk State 7-11-12 pad, submits the following 10-403, to using Nordic 2 for workover operations to pull the existing completionIURP +\GUDWH3. On the following pages are the detailed operations program, current wellbore schematic, proposed wellbore schematics, and BOP diagram. Please contact Jake Flora at 720-988-5375 or myself should you have any questions regarding this Sundry. Sincerely, Doug Cismoski, P.E. Vice President of Drilling, Projects and Engineering ASRC Energy Services | Consulting & Environmental 3900 C Street, Suite 701, Anchorage, Alaska 99503Work: (907) 339-7410 Email: dcismoski@asrcenergy.com | asrcenergy.com Sincerely, OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 1 of 3 To: AOGCC From: Jake Flora / Doug Cismoski P.E. ASRC Consulting & Environmental Services Well Name: Hydrate-P1 API: 50-029-23737-00-00 PTD: 222-141 Status: SI Producer: Gas Hydrates Production Test Engineer: Jake Flora, (720) 988-5375 Well Summary: Hydrate-P1, drilled in early 2023, is one of two test wells drilled for the Alaska Methane Hydrate Project on the North Slope. The well design includes 16” x 14” vacuum insulated surface casing cemented to surface, and a 9 5/8” x 10-3/4” production casing string with pressure and temperature gauges clamped to the exterior of the casing. Perforated in the Hydrate B Unit from 2916 – 2942’, Hydrate-P1 is completed with several unique components including GeoForm sand control, a downhole heater, surface-controlled isolation valve (now locked open), and is compatible for both ESP and jet pump artificial lift. Initially placed on test with an ESP, production became troublesome to keep online at low water rates. In May 2024, the ESP was replaced with a jet pump. Through recycling produced water downhole, the well was able to achieve stable flow. However, decreasing inflow once again halted the test and the jet pump was pulled in August 2024. It is assumed the expanded pore matrix (GeoForm) within the sand control completion has become plugged with solids. The main objective of this workover is to pull and evaluate the condition of the GeoForm. Scope: Use Nordic Rig 2 to pull the upper completion, perform logs to investigate the lower sand control completion while in place, pull the lower completion, run additional evaluation logs, and run a kill string. Well Information: Max Expected BHP 1256 psi Based on 0.44 psi/ft gradient @ 2856’TVD MPSP: 1113 psi Based on BHP minus 0.05 psi/ft gas gradient Total Depth: 3452’ MD / 3379’ TVD Plug back depth: 3314’ MD / 3162’ TVD Perforations: 2916’-2942’ MD / 2856’-2881’ TVD MIT-Tubing 3500 psi (2-25-2023) MIT-Annulus 3000 psi (2-25-2023) BHT 65 degrees Recent Well Work: 8-16-2024 Pull jet pump, tag fill at 2924’ MD with 2” bailer. Recovered 2 cups of fine mud, open 3 ½” SS, close 4 ½” SS. and set a plug above the perfs. -bjm OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 2 of 3 Risk Discussion: During the production test with the ESP in place, flow exited the tubing through the 4 ½” CMD SS and returned to the tubing via the annular communication port. Due to this flow path, it is expected that annular fill is present below the 4 ½” sliding sleeve at 2631’ MD down to the 9 5/8” dual packer at 2691’ MD. The ability to shear and pull the 9 5/8” production packer is viewed as the greatest challenge for de-completing the well. Procedure: Pre-Rig Work 1. RU Slickline, tag top of fill. Bail fill to below 2973’. COMPLETED 2. Set plug in 3 ½” CMD SS at 2720’. Sliding sleeve will remain open below the plug. COMPLETED 3. Set isolation sleeve in annular communication port at 2581’. COMPLETED 4. Pressure test tubing to 2000 psi. COMPLETED 5. RU E-line, RU pump, pressure up tubing to 1000 psi, tubing punch 2688’ – 2690’ (bottom of 3 ½” 15’ pup joint above 9 5/8” packer). COMPLETED 6. Establish circulation from tubing to annulus through punch holes. COMPLETED 7. Circulate annulus clean, repeat circulation with methanol-water to freeze protect. COMPLETED 8. Pull slickline plug from 2720’. COMPLETED 9. MIRU 1.75” CTU. BOP test to 250 psi low / 2500 psi high. 10. MU cleanout BHA, using hot water clean out well to 5 ½” bull plug at 3205’. 11. MU ball drop firing head, 4’ tubing puncher, RIH to flag, confirm depth, tag bottom, circulate ball to firing head to punch 5 ½” liner 3190-3194’. Holes will allow liner to drain while retrieving with rig. 12. Circulate 9.5 ppg NaCL brine down the 5/8” & 3/8” chemical injection lines taking returns to surface. x 5/8” chemical injection line terminates at the 2 7/8” chemical injection mandrel near the 2 7/8” tubing tail at 3005’. The line has no downhole check and is potentially cut near the top of the perforations at 2916’. x 3/8” chemical injection line terminates at the injection mandrel just below the production packer. Within the injection mandrel a check valve exists to prevent wellbore fluids from entering the injection line. 13. Circulate wellbore with 9.5 ppg NaCL pumping down tubing with returns from IA. Rig Work 1. Review all approved COAs. 2. Provide AOGCC 24 hrs notice for BOPE test. 3. Set BPV. ND Tree. Cap and secure all control lines. NU THA with ported flange/needle valve. 4. MIRU Nordic 3. 5. ND THA, install test plug. 6. NU 16 ¾” BOPE with 7” pipe rams. Verbal approval for tubing punch was granted 6/3/25. -bjm OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 3 of 3 x If necessary to close rams while pulling upper completion a 7” kick joint will be used with XOs to 4 ½” & 3 ½” tubing. 7. Perform BOP test to 250 psi low, 2500 psi high. 8. Pull test plug, pull BPV. 9. Circulate wellbore through tubing punch with 9.2 ppg NaCL. 10. MU & screw in landing joint, back out LDS. 11. PU, shear 9-5/8” packer at 60,000 lbs. 12. Lower hanger, close annular on landing joint, circulate wellbore to remove gas below packer. 13. Remove and cap control lines, connect tail lines from spoolers to lines. 14. Check for flow / pressure. Pull & LD 7” upper completion while keeping wellbore full. x After 7” tubing is laid down MU 4 ½” crossover to kick joint. x After 4 ½” tubing is laid down MU 3 ½” crossover to kick joint. 15. Change BOP pipe rams to 4” pipe rams and test to 250 psi low and 2500 psi high. 16. PU 4” work string, with 1 joint 2-7/8” & 9 5/8” casing scraper. 17. TIH to 9 5/8” sand control packer, shoulder out, circulate packer clean. 18. RU E-line, RIH w gauge ring to tag, log USIT across GeoForm liner. 19. MU SC-2R packer pulling tool. 20. TIH to sand control packer at 2860’ with packer pulling tool. 21. Locate and release packer, pull and LD 5 ½” lower completion. x If necessary to close rams while pulling 5 ½” liner a 4” kick joint to be used with XO to 5 ½” liner threads. 22. MU CIBP on drill pipe, set at ~2850’ (66’ above perforations) 23. PT plug to 2000 psi 24. Circulate wellbore to 60/40 methwater. 25. MU 1 joint of 7” tubing to hanger, land tubing hanger, RILDS. 26. Set and test TWC. 27. ND BOP, NU dry hole tree (2 valves, tubing cap, needle valve. 28. RDMO Nordic 3. Attachments: 1. Current Wellbore Diagram 2. Proposed Wellbore Diagram (final) 3. 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Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Flora, Jake <jflora@asrcenergy.com> Sent: Tuesday, June 3, 2025 11:47 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Isaacson, William <wisaacson@asrcenergy.com> Subject: RE: Hydrate P1 (PTD 222-141) RWO Bryan, Per our phone conversation we are still determining a Ʊnal well conƱguration post workover and will make a proposal to you in the next week. Over the weekend we used slickline to bail and left top of Ʊll at 2973’ (bottom of perforations), set the ACP isolation sleeve, and set a plug in the 3.5” CMD SS below the production packer. To continue pre-rig preparation we would like to request email approval to proceed with steps 9, 10, & 11 pertaining to the tubing punch and circulation listed below: 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 Please advise if you require anything else to review this request. Thanks, Jake From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, June 2, 2025 12:15 PM To: Flora, Jake <jflora@asrcenergy.com> Subject: Hydrate P1 (PTD 222-141) RWO Jake, What are your plans for this well after the RWO? Typically we’d expect a plug in the well or production packer when perfs are open for a signiƱcant length of time. ❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 Also, it’s ok to use the kick joint without rams for short sections of pipe, but you’ll need 2-7/8” rams for running the kill string. I will modify the sundry to reƲect that. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Tuesday, June 3, 2025 1:12 PM To:Flora, Jake Cc:Isaacson, William Subject:RE: Hydrate P1 (PTD 222-141) RWO Jake, ASRC has approval to proceed with the pre-rig work through step 11 as requested below. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Flora, Jake <jflora@asrcenergy.com> Sent: Tuesday, June 3, 2025 11:47 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Isaacson, William <wisaacson@asrcenergy.com> Subject: RE: Hydrate P1 (PTD 222-141) RWO Bryan, Per our phone conversation we are still determining a final well configuration post workover and will make a proposal to you in the next week. Over the weekend we used slickline to bail and left top of fill at 2973’ (bottom of perforations), set the ACP isolation sleeve, and set a plug in the 3.5” CMD SS below the production packer. To continue pre-rig preparation we would like to request email approval to proceed with steps 9, 10, & 11 pertaining to the tubing punch and circulation listed below: 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 Please advise if you require anything else to review this request. Thanks, Jake From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, June 2, 2025 12:15 PM To: Flora, Jake <jflora@asrcenergy.com> Subject: Hydrate P1 (PTD 222-141) RWO Jake, What are your plans for this well after the RWO? Typically we’d expect a plug in the well or production packer when perfs are open for a significant length of time. ❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 Also, it’s ok to use the kick joint without rams for short sections of pipe, but you’ll need 2-7/8” rams for running the kill string. I will modify the sundry to reflect that. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 0 2 9 - 2 3 7 3 7 - 0 0 - 0 0 We l l N a m e / N o . H Y D R A T E P 1 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 2/ 2 7 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 4 1 0 Op e r a t o r A S R C C o n s u l t i n g & E n v i r o n m e n t a l S e MD 34 5 2 TV D 33 7 9 Cu r r e n t S t a t u s 1- G A S 4/ 9 / 2 0 2 5 UI C No We l l L o g I n f o r m a t i o n : Di g i t a l Me d / F r m t Re c e i v e d St a r t S t o p OH / CH Co m m e n t s Lo g Me d i a Ru n No El e c t r Da t a s e t Nu m b e r Na m e In t e r v a l Li s t o f L o g s O b t a i n e d : Su r f a c e H o l e L W D L o g s R a n : G R P r o d u c t i o n H o l e L W D L o g s R a n : R e s i s t i v i t y , G R , D e n s / N e u t , S o n i c , N M R No Ye s Ye s Mu d L o g S a m p l e s D i r e c t i o n a l S u r v e y RE Q U I R E D I N F O R M A T I O N (f r o m M a s t e r W e l l D a t a / L o g s ) DA T A I N F O R M A T I O N Lo g / Da t a Ty p e Lo g Sc a l e DF 4/ 1 8 / 2 0 2 3 16 6 3 4 5 2 E l e c t r o n i c D a t a S e t , F i l e n a m e : H y d r a t e - P1 _ D r i l l i n g _ M e c h a n i c s _ D e p t h . l a s 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 18 2 3 3 7 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : H y d r a t e - P1 _ V I S I O N _ S e r v i c e _ D r i l l i n g P a s s _ R e c o r d e d Mo d e _ L A S . l a s 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 20 5 7 3 3 6 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : Hy d r a t e _ P 1 _ R 6 _ 1 2 . 5 i n _ S o n i c S c o p e 8 2 5 _ D R I L L _ DT C O _ 2 0 5 7 f t _ 3 3 6 5 f t _ L A S . l a s 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 20 5 7 3 3 6 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : Hy d r a t e _ P 1 _ R 6 _ 1 2 . 5 i n _ S o n i c S c o p e 8 2 5 _ D R I L L _ QP _ 2 0 5 7 f t _ 3 3 6 5 f t _ L A S . l a s 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : A S R C _ H y d r a t e - P 1 _ 0 2 - F e b - 20 2 3 _ C e m e n t _ E v a l u a t i o n _ R e p o r t _ R e v i s e d (1 ) . p d f 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : A S R C _ H y d r a t e - P 1 _ I B C - CB L _ 1 0 . 7 5 _ 2 F e b 2 0 2 3 _ U p d a t e d . d l i s 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : A S R C _ H y d r a t e - P 1 _ I B C - CB L _ 2 F e b 2 0 2 3 _ U p d a t e d . P d f 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : A S R C _ H y d r a t e - P 1 _ I B C - CB L _ 9 . 6 2 5 _ 2 F e b 2 0 2 3 _ U p d a t e d . d l i s 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : H y d r a t e - P 1 A S P F i n a l S u r v e y . x l s x 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : H y d r a t e - P 1 - V I S I O N S e r v i c e - Re c o r d e d M o d e C o m p o s i t e D r i l l i n g D a t a M D . d l i s 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : Hy d r a t e _ P 1 _ R 6 _ 1 2 . 5 i n _ S o n i c S c o p e 8 2 5 _ D R I L L _ DT C O _ 2 0 5 7 f t _ 3 3 6 5 f t _ D L I S . d l i s 37 5 7 9 ED Di g i t a l D a t a We d n e s d a y , A p r i l 9 , 2 0 2 5 AO G C C Pa g e 1 o f 3 Hydr a t e - ,y P1 _ V I S I O N _ S e r v i c e _ D r i l l i n g P a s s _ R e c o r d e d __ Mod e _ L A S . l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 0 2 9 - 2 3 7 3 7 - 0 0 - 0 0 We l l N a m e / N o . H Y D R A T E P 1 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 2/ 2 7 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 4 1 0 Op e r a t o r A S R C C o n s u l t i n g & E n v i r o n m e n t a l S e MD 34 5 2 TV D 33 7 9 Cu r r e n t S t a t u s 1- G A S 4/ 9 / 2 0 2 5 UI C No DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : Hy d r a t e _ P 1 _ R 6 _ 1 2 . 5 i n _ S o n i c S c o p e 8 2 5 _ D R I L L _ QP _ 2 0 5 7 f t _ 3 3 6 5 f t _ D L I S . d l i s 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : H y d r a t e - P1 _ D r i l l i n g _ M e c h a n i c s _ D e p t h _ L o g . P d f 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : H y d r a t e - P1 _ V I S I O N _ I m a g e _ 5 _ i n c h _ M D _ R e c o r d e d _ M o d e _L o g . P d f 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : H y d r a t e - P1 _ V I S I O N _ S e r v i c e _ 2 i n c h _ M D _ D r i l l i n g _ R e c o r d e d_ M o d e _ L o g . P d f 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : H y d r a t e - P1 _ V I S I O N _ S e r v i c e _ 2 i n c h _ T V D _ D r i l l i n g _ R e c o r d ed M o d e L o g . P d f 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : H y d r a t e - P1 _ V I S I O N _ S e r v i c e _ 5 i n c h _ M D _ D r i l l i n g _ R e c o r d e d_ M o d e _ L o g . P d f 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : H y d r a t e - P1 _ V I S I O N _ S e r v i c e _ 5 i n c h _ T V D _ D r i l l i n g _ R e c o r d ed _ M o d e _ L o g . P d f 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : Hy d r a t e _ P 1 _ R 6 _ 1 2 . 5 i n _ S o n i c S c o p e 8 2 5 _ D R I L L _ DT C O _ 2 0 5 7 f t _ 3 3 6 5 f t _ P D F . p d f 37 5 7 9 ED Di g i t a l D a t a DF 4/ 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : Hy d r a t e _ P 1 _ R 6 _ 1 2 . 5 i n _ S o n i c S c o p e 8 2 5 _ D R I L L _ QP _ 2 0 5 7 f t _ 3 3 6 5 f t _ P D F . p d f 37 5 7 9 ED Di g i t a l D a t a DF 12 / 1 5 / 2 0 2 3 30 5 3 4 5 1 E l e c t r o n i c D a t a S e t , F i l e n a m e : H y d r a t e - P 1 _ E O W De p t h D a t a . l a s 37 5 7 9 ED Di g i t a l D a t a DF 12 / 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : F i n a l W e l l R e p o r t _ H y d r a t e _ P 1 . p d f 37 5 7 9 ED Di g i t a l D a t a DF 12 / 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : H y d r a t e - P 1 A O G C C D a t a Tr a n s m i t t a l 1 2 - 1 4 - 2 0 2 3 . p d f 37 5 7 9 ED Di g i t a l D a t a DF 12 / 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : H y d r a t e - P 1 _ E O W D e p t h D a t a . c s v 37 5 7 9 ED Di g i t a l D a t a DF 12 / 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : H y d r a t e - P 1 _ M a s t e r l o g 2 4 0 . p d f 37 5 7 9 ED Di g i t a l D a t a DF 12 / 1 5 / 2 0 2 3 E l e c t r o n i c F i l e : H y d r a t e - P 1 _ M a s t e r l o g 6 0 0 . p d f 37 5 7 9 ED Di g i t a l D a t a DF 12 / 1 8 / 2 0 2 3 E l e c t r o n i c F i l e : O . 1 0 0 8 4 2 5 . 0 2 _ R u n 0 6 _ D r i l l _ 2 1 4 9 - 34 5 2 f t _ R M . d l i s 38 2 3 3 ED Di g i t a l D a t a We d n e s d a y , A p r i l 9 , 2 0 2 5 AO G C C Pa g e 2 o f 3 Hydr a t e - P 1 _ E OW De p t h D a t a . l a s DA T A S U B M I T T A L C O M P L I A N C E R E P O R T AP I N o . 5 0 - 0 2 9 - 2 3 7 3 7 - 0 0 - 0 0 We l l N a m e / N o . H Y D R A T E P 1 Co m p l e t i o n S t a t u s 1- G A S Co m p l e t i o n D a t e 2/ 2 7 / 2 0 2 3 Pe r m i t t o D r i l l 22 2 1 4 1 0 Op e r a t o r A S R C C o n s u l t i n g & E n v i r o n m e n t a l S e MD 34 5 2 TV D 33 7 9 Cu r r e n t S t a t u s 1- G A S 4/ 9 / 2 0 2 5 UI C No We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l IN F O R M A T I O N R E C E I V E D Co m p l e t i o n R e p o r t Pr o d u c t i o n T e s t I n f o r m a t i o n Ge o l o g i c M a r k e r s / T o p s Y Y / N A Y Co m m e n t s : Co m p l i a n c e R e v i e w e d B y : Da t e : Mu d L o g s , I m a g e F i l e s , D i g i t a l D a t a Co m p o s i t e L o g s , I m a g e , D a t a F i l e s Cu t t i n g s S a m p l e s Y / N A Y Y / N A Di r e c t i o n a l / I n c l i n a t i o n D a t a Me c h a n i c a l I n t e g r i t y T e s t I n f o r m a t i o n Da i l y O p e r a t i o n s S u m m a r y Y Y / N A Y Co r e C h i p s Co r e P h o t o g r a p h s La b o r a t o r y A n a l y s e s Y / N A Y / N A Y / N A CO M P L I A N C E H I S T O R Y Da t e C o m m e n t s De s c r i p t i o n Co m p l e t i o n D a t e : 2/ 2 7 / 2 0 2 3 Re l e a s e D a t e : 3/ 2 7 / 2 0 2 5 We d n e s d a y , A p r i l 9 , 2 0 2 5 AO G C C Pa g e 3 o f 3 M. G u h l 4/ 9 / 2 0 2 5 From:Heusser, Heather A (DNR) To:Guhl, Meredith D (OGC) Cc:Morgan, Kirk A (DNR) Subject:RE: Hydrate P1, PTD 222-141, Extended Confidentiality? Date:Friday, April 4, 2025 11:43:38 AM Hi Meredith, We did not receive an extended confidentially request for Hydrate P1, PTD 222-141. Heather Ann Heusser Natural Resource Specialist IV State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage AK 99501-3560 heather.heusser@alaska.gov From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Thursday, April 3, 2025 3:01 PM To: Heusser, Heather A (DNR) <heather.heusser@alaska.gov> Cc: Morgan, Kirk A (DNR) <kirk.morgan@alaska.gov> Subject: Hydrate P1, PTD 222-141, Extended Confidentiality? Hello Heather, Has ASRC Consulting and Environmental Services requested extended confidentiality for Hydrate P1, PTD 222-141, due for release after March 27, 2025? Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. ⚠️CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 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:Dial, Amanda To:Dewhurst, Andrew D (OGC); Isaacson, William Cc:Guhl, Meredith D (OGC); McLellan, Bryan J (OGC) Subject:RE: Hydrate P1 and P2 Geologic Tops Date:Thursday, March 13, 2025 12:43:01 PM Attachments:image001.png Hydrate P1-P2 Tops 011823.xlsx Andrew, Apologies for the delay. Please find tops attached for Hydrate P1 and P2. Please let us know if additional information is needed. Thank you, Amanda Dial Cell: 907-382-0124 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Thursday, March 13, 2025 12:28 PM To: Isaacson, William <wisaacson@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Hydrate P1 and P2 Geologic Tops Bill, I am reviewing the 10-407s from both the Hydrate P1 an P2 wells and would like to include additional formation tops (that better match the pre-drill prognosis). A similar request was made for Hydrate-02 and Amanda sent over a table with the detail I was looking for. Would you please direct this request to someone that could provide that additional information for the P1 and P2 wells? Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 Formation Top Project Unit Name MD KB, ft TVD KB, ft TVD SS, ft **Estimated Depth MD KB, ft TVD KB, ft Estimated Depth TVD SS, ft MD KB, ft TVD KB, ft TVD SS, ft G1 349 349 ‐266 345 345 ‐262 347 347 ‐265 (SV6)1131 1131 ‐1048 1142 1132 ‐1049 1140 1129 ‐1047 C17 1679 1672 ‐1589 1708 1678 ‐1596 C16_Top_F (SV5) F1 1773 1762 ‐1679 1791 1764 ‐1681 1801 1769 ‐1687 (SV4)1918 1902 ‐1819 1934 1903 ‐1820 1943 1908 ‐1826 BIBPF NA NA NA 1999 1966 ‐1883 NA NA NA C15_1_Top_E E1 2132 2106 ‐2023 2131 2095 ‐2012 2142 2100 ‐2018 Surface Casing Shoe 2241 2210 ‐2127 2185 2147 ‐2064 2199 2155 ‐2073 Surface Hole TD 2215 2171 ‐2089 C15_Top_D (SV3) D1 2396 2358 ‐2275 2408 2364 ‐2281 2407 2358 ‐2276 C14_2_Top_C (SV2) C0 2578 2531 ‐2448 2584 2529 ‐2447 C1 2607 2558 ‐2475 2609 2555 ‐2473 C2 2658 2606 ‐2523 2657 2603 ‐2521 C3 2745 2687 ‐2604 2749 2694 ‐2612 C4 2847 2781 ‐2698 2828 2769 ‐2687 C13_Top_B (SV1) B1 2927 2857 ‐2774 2906 2849 ‐2766 2911 2850 ‐2768 B2 3013 2937 ‐2854 NA NA NA B3 3039 2970 ‐2887 3035 2972 ‐2890 Base_GHSZ 3145 3060 ‐2977 3123 3061 ‐2978 3123 3061 ‐2979 (UG4)3265 3172 ‐3089 3251 3185 ‐3102 3241 3173 ‐3091 C12_6_Top_A (UG4A)3346 3247 ‐3164 3311 3244 ‐3161 3309 3240 ‐3157 Production Casing Point 3471 3363 3280 3400 3330 ‐3247 Pending Pending Pending Well TD 3482 3374 ‐3291 3443 3372 ‐3289 3452 3379 ‐3297 KB = 82.85 ft ss GL = 52.2 ft ss Gap = 30.65 ft Hydrate‐P1 (PTW‐1) As Drilled Hydrate‐P1 (PTW‐1) Well Plan KB = 82.2 ft ss GL = 52.2 ft ss Gap = 30.0 ft *Base directional plan (DEC‐25) Hydrate‐P2 (PTW‐2) As Drilled ⚠️CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 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:Dial, Amanda To:Dewhurst, Andrew D (OGC); Isaacson, William Cc:Guhl, Meredith D (OGC); McLellan, Bryan J (OGC) Subject:RE: Hydrate P1 and P2 Geologic Tops Date:Thursday, March 13, 2025 12:43:01 PM Attachments:image001.png Hydrate P1-P2 Tops 011823.xlsx Andrew, Apologies for the delay. Please find tops attached for Hydrate P1 and P2. Please let us know if additional information is needed. Thank you, Amanda Dial Cell: 907-382-0124 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Thursday, March 13, 2025 12:28 PM To: Isaacson, William <wisaacson@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Hydrate P1 and P2 Geologic Tops Bill, I am reviewing the 10-407s from both the Hydrate P1 an P2 wells and would like to include additional formation tops (that better match the pre-drill prognosis). A similar request was made for Hydrate-02 and Amanda sent over a table with the detail I was looking for. Would you please direct this request to someone that could provide that additional information for the P1 and P2 wells? Thanks, Andy 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:Cismoski, Doug Cc:Shirzadi, Shahryar; Roby, David S (OGC); Coldiron, Samantha J (OGC); Regg, James B (OGC) Subject:RE: Methane Hydrates Long Term Production Test End Date:Wednesday, November 20, 2024 5:10:13 PM Attachments:Methane Hydrates End of Test Notice AOGCC-20240916.pdf Doug, Thank you for sending the status update. What is the anticipated timeline for P&A of the wells? Since ASRC has no further plans to produce the wells, the waiver that was approved in Docket OTH-23-023 is cancelled. Regarding the need to submit monthly production reports, since the well has not been suspended or P&A’d, ASRC is still required to submit the production reports. However, we are discussing internally whether or not an exception can be made since there are no plans for any more production from this project. We’ll let you know, but for now, continue to report. Sam, please include this email and the attached document in the docket file. Note that this well is still confidential. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Cismoski, Doug <dcismoski@asrcenergy.com> Sent: Monday, September 16, 2024 6:09 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Shirzadi, Shahryar <sshirzadi@asrcenergy.com> Subject: Methane Hydrates Long Term Production Test End Bryan and Jim – Attached is an end of test notice for the methane hydrate project. Please contact myself or Mr. Shirzadi if you have any questions. Doug Cismoski, P.E.Vice President of Drilling, Projects and Engineering ASRC Energy Services | Consulting & Environmental 3900 C Street, Suite 701, Anchorage, Alaska 99503 Work: (907) 339-7410 Email: dcismoski@asrcenergy.com asrcenergy.com ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 1 of 2 September 16, 2024 Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: MHP - End of production phase report Dear Commissioners, ASRC Consulting and Environmental Services, LLC, (ACES) as operator of four wells related to a Long-Term Production Test of Methane Hydrates located on the Kuparuk State 7-11-12 pad, respectfully submits the following report on the end of production phase of the test. The production phase of the methane hydrate long-term production test ended on July 30, and the post-production observation period has begun. ACES began removing portions of the facility in August to return as much rented equipment as possible. ACES anticipates removing the remaining facilities in the spring of 2025. The pad will remain staffed during the observation period. The forward plan is to continue the post-production observation period until November 3 rd, conduct a Vertical Seismic Profile (VSP) survey in early 2025, then P&A the wells and complete dismantling and removing the production facility. The current well conditions are: Hydrate-P1 – Exploratory Well x Perforated 2916 to 2942’ x Freeze-protected with 60/40 methanol/water. x Removed the ISO Sleeve from across the electric submersible pump (ESP) annular connection port (ACP). x Removed tubing stop and jet pump. x 4.5” sliding sleeve above the production packer - closed x 3.5” sliding sleeve below the production packer - open Hydrate-P2 – Exploratory Well x No change since 10-407 Completion Report, submitted on 1/18/2023. x No completion. Hydrate-02 – Exploratory Well x No change since 10-407 Completion Report, submitted on 12/16/2022. x No completion. Hydrate-01 – Exploratory Well x No change since 10-407 Completion Report, submitted on 3/7/2019. x Tubing, IA and OA are cemented to surface. ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 2 of 2 x Suspended Well ACES anticipates the following reporting to the AOGCC: 1. The Monthly Production Report (Form 10-405) a. ASRC requests that the August 2024 Report be the final monthly production report unless production is resumed. 2. The Facility Report of Produced Gas Disposition (Form 10-422) a. ASRC will continue to submit a monthly report while using fuel gas during post- production observation period. 3. The Reservoir Pressure Report (Form 10-412) 4. The Annual Reservoir Properties Report (Form 10-428) ACES requests that the Commission cancel the safety valve systems (SVS) testing waiver that was approved on September 05, 2023, in Docket # OTH-23-023. Given the last test was conducted on 5/22/2024; ACES will conduct the next SVS test as required. Please contact Shahryar (Shawn) Shirzadi at 907-339-6462 or myself at 907-339-7410 should you have any questions regarding this report or the requests herein. Sincerely, Doug Cismoski Methane Hydrate Project Manager Vice President of Drilling, Projects and Engineering ASRC Consulting and Environmental Services 3. Field and Pool Code: 4. Pool Name 5. Reference Datum (ft TVDSS) 6. Temperature (°F) 7. Porosity (%) 8. Permeability (md) 9. Swi (%)10. Oil Viscosity @ Original Pressure (cp) 11. Oil Viscosity @ Saturation Pressure (cp) 12. Original Pressure (psi) 13. Bubble Point or Dew Point Pressure (psi) 14. Current Reservoir Pressure (psi) 15. Oil Gravity (°API) 16. Gas Specific Gravity (Air = 1.0) 17. Gross Pay (ft) 18. Net Pay (ft) 19. Original Formation Volume Factor (RB/STB) 20. Bubble Point Formation Volume Factor (RB/STB) 21. Gas Compressibility Factor (Z) 22. Original GOR (SCF/STB) 23. Current GOR (SCF/STB) 640500 Prudhoe Bay, Undefined Gas 2770 52 30 10 5 NA NA 1270 NA 1174 NA 0.55 59 40 NA NA 0.98 NA NA Subsurface and Wells Development 9/9/2024 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PROPERTIES REPORT 1. Operator:2. Address: ASRC Consulting and Environmental Services 3900 C Street, Suite 700, Anchorage, AK 99503 Printed Name Title DateShahryar Shirzadi I hereby certify that the foregoing is true and correct to the best of my knowledge. Certified Digital Signature Form 10-428 Revised 10/2022 Submit in PDF and Excel to aogcc.reporting@alaska.gov 6. Oil Gravity: NA 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) Hydrate-P1 50029237370000 G 640500 C13_(SV1)2773-2799 9/1/2024 792 SBHP 55.5 2768 1150 2770 0.42 1151 Hydrate-P2 50029237320000 640500 C13_(SV1)9/1/2024 SBHP 51 2770 1160 2770 0.42 1160 Hydrate-02 50029237280000 640500 C13_(SV1)9/1/2024 SBHP 52 2773 1175 2770 0.42 1174 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator:2. Address: Printed Name Title Date Subsurface and Wells Development September 9, 2024Shahryar Shirzadi Certified Digital Signature 23. All tests reported herein were made in accordance with the applicable rules, regulations, and instructions of the Alaska Oil and Gas Conservation Commission. I hereby certify that the foregoing is true and correct to the best of my knowledge. 7. Gas Gravity: ADL 047450 Prudhoe Bay Unit ASRC Consulting and Environmental Services 3900 C Street, Suite 700, Anchorage, AK 99503 Prudhoe Bay, Undefined Gas 2770 0.55 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: Form 10-412 Revised 10/2022 Submit PDF and Excel to aogcc.reporting@alaska.gov 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: ______________________ 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 feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 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: 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: Contact Name: Contact Email: Authorized Title:Contact Phone: Burst Collapse Production Liner Casing Structural Conductor Surface Intermediate measured TVD Plugs Junk measured Length STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure Size 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 3. Address: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf MD Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl p k ft t Fra O s O 6. A G L PG , C Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Install jet pump ASRC Consulting and Environmental Services (ACES) 3900 C Street, Suite 700, Anchorage, AK 99503 222-141 50-029-23737-00-00 ADL 047450 Prudhoe Bay Unit / Undefined Gas Pool Hydrate-P1 N/A 3452' MD 3379' TVD 3314' MD 3244' TVD 2692' MD 2637' TVD 345' 3412' 117' 2167' 24" 16"x14" 10-3/4" / 9-5/8" 5-1/2" 148'148' 2155'2199' 2609' / 3370'6450 / 6870 psi 4020 / 4760 psi 3138'7740 psi 6390 psi 2670' / 3443' 3205' 2916' to 2942' 2856 to 2881' 2952' TVD3014' MDL-807" x 4-1/2" x 3-1/2" x 2-7/8" 9-5/8" pckr 2637' TVD2692' MD Hydraulic Set N/A N/A 80 20 120 * Reverse circulation jet pump installed. 600 psi 240 psi2600' psi * 240 psi 135 324-279 Ray Oakley roakley@ASRCenergy.com 907-230-5059VP of Drilling, Projects, Engineering Doug Cismoski Digitally signed by Doug Cismoski Date: 2024.06.18 19:16:45 -08'00' By Grace Christianson at 7:55 am, Jun 19, 2024 A.Dewhurst 13MAR25 DSR-6/19/24BJM 3/13/25 RBDMS JSB 062724 95/8"CasingPBTDͲ~3314ftMDastagged HydrateͲP1(PTW1) JetPumpInstallation Asrun5/18/2024 36"OpenHole 16"84lbs/ftx14"82.5lbs/ftLͲ80VacuumInsulatedCasing ~2199ftMD/2155ftTVD 20”OpenHole–2215ftMD ~2911ftMD/2850ftTVD– Top of Hydrate BͲUnit 12½”OpenHole–3452ftMD/3379ftTVD 9Ͳ5/8"LͲ8047lbs/ftCasingͲ3443ftMD/3370ftTVD 24"XͲ60189lbs/ftConductor–117ftbelowGL 4 ½” 12.6 lbs/ft Orbit Barrier Valve (9% Cr) w/3.750" profile (2 x ¼” C/L) at 2648 ft MD *** OBV locked open, 5/17/2024 9 5/8" x 3 ½” x 2 3/8" Hydraulic Set Twin Seal Production Packer at 2692 ft MD 4 ½” 12.6 lbs/ft L80 CMD Sliding Sleeve w/3.750" F Profile at 2631 ft MD 3 ½” 9.2 lbs/ft L80 tubing 8.268" OD x 3 ½” Downhole Heater At 2767 ft MD 3 ½” 9.2 lbs/ft tubing 9 5/8"” 47 lbs/ft Casing 9Ͳ5/8" Sand Control Packer SCͲ2R at 2860 ft MD GeoFORMTM (5 ½” 23 lbs/ft Base Pipe) from 2911 – 2949 ft MD 10 ¾” x 9 5/8" Casing XͲOver 2670 ft MD / 2615 ft TVD 7" 29 lbs/ft L80 Tubing/Shroud Access ESP 5 ½” and 7 " OD Motor Shroud with 3.85" internal seal bore Access ESP 3.813" NoͲGo and ‘B’ Profile Crossover 10 ¾” 55.5 lbs/ft Casing 5 ½” Solid Aluminum Bull Plug Shoe – Bottom at 3205 ft MD 3 ½” 9.2 lbs/ft CMD Sliding Sleeve w/ 2.750" F Profile at 2721 ft MD 3 ½” L80 Chemical Injection mandrel for 3/8" line at 2728 ft MD 7” P/T Gauge mandrel L80 at 2306 ft MD SureSENS SPTV Tubing/Annulus – T7/T8 7” P/T Gauge mandrel L80 at 2204 ft MD SureSENS SPTV Tubing/Annulus – T9/T10 7" 26 lbs/ft L80 Tubing 3 ½” P/T Gauge mandrel at 2735 ft MD SureSENS SPTV Tubing/Annulus – T5/T6 3 ½ ” 9.2 lbs/ft P/T Gauge mandrel at 2846 ft MD SureSENS SPTV Tubing/Annulus – T3/T4 2 7/8 ” P/T Gauge mandrel at 2959 ft MD SureSENS SPTV Tubing/Annulus – T1/T2 4 ½” 12.6 lbs/ft x 3 ½" 9.2 lbs/ft X/over L80 2Ͳ7/8” L80 Chemical Injection Mandrel for 5/8" line at 3005 ft MD 1 x ¼ Single Line for P/T Gauges Single Line DTS/DAS Single line DSS 2 x ¼” Dual line Barrier Valve Single Line P/T Gauges Down hole heater Heater cable1 x д” Chemical Injection ESP Cable 1 x з ” Single Line Fluid Injection 7" Tubing Hanger 3 ½” 9.2 lbs/ft x 2 д " 4.6 lbs/Ō X/over L80 2 7/8 " 4.6 lbs/ft L80 Tubing w/ Slotted Tubing from 2914 – 2953 ft MD WEG – Bottom at 3013.5 ft MD 7” P/T Gauge mandrel L80 at 297 ft MD SureSENS SPTV Tubing/Annulus – T11/T12 7" 29 lbs/ft L80 CMD Sliding Sleeve w/5.875" AF Profile at 2523 ft MD 13¼”OpenHole–2750ftMD Access ESP Annular Connection Port 5 ½" 23 lbs/ft L80 Casing 5 ½" 17 lbs/ft L80 Casing Oriented Perforations 2916.5 ft MD to 2942.5 ft MD 4 ½” PrimePump Jet Pump landed in CMD Sliding Sleeve 16"x14"VICcasingcementedwith893bbl11ppgleadand287 bbl12.5ppgtailcement.114bblcementreturnedtosurface. 10Ͳ3/4"x9Ͳ5/8"casingcementedwith228bbl10.7ppgleadand 145bbl12.5ppgtailcement.174bblcementreturnedtosurface. Access ESP 3” ID Isolation Sleeve installed across Annular Connection Port ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 1 of 2 June 18, 2024 Mr. Brett Huber, Sr, Chair, Commissioner Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Report of Sundry Well Operations for MHP well Hydrate-P1 (PTD 222141) Dear Commissioners, ASRC Consulting & Environmental Services, LLC (ACES), as operator of four wells related to a Long- Term Production Test of Methane Hydrates located on the Kuparuk State 7-11-12 pad, submits the following 10-404, report of Sundry well operations relating to installing a jet pump, per Sundry # 324-279. On the following pages are the summary of daily well operations and the revised, current wellbore schematic. Please contact Ray Oakley at 907-230-5059 or myself should you have any questions regarding this report. Sincerely, Doug Cismoski, P.E. Vice President of Drilling, Projects and Engineering ASRC Energy Services | Consulting & Environmental 3900 C Street, Suite 701, Anchorage, Alaska 99503 Work: (907) 339-7410 Email: dcismoski@asrcenergy.com | asrcenergy.com S ce e y, D Ci ki P E ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 2 of 2 Date of Activity Summary of Daily Well Operations 5/5/2024 MIRU / PT / drift and tag tubing stop / pull tubing stop / equalize ESP standing valve (no pressure change seen) / pull Standing Valve -Packoff assembly / 5/6/2024 RU 140' crane / pull ESP pump / pull ESP motor / release crane (plan to run jet pump, not ESP) 5/7/2024 Ran 3.5” pump down bailer,Tag fill at 2599' SLM / made 3 runs with 3”pump down bailer, returned silt and gray water, made 2' / then 2 runs with drive-down bailer, made 10', to 2613' SLM / fill appears to be non-newtonian fluid: liquifies under stress. 5/8/2024 Bailed down to ~ 2635' SLM - OBV / Tattle tails on shoe indicate we are on OBV 5/9/2024 Ran 3.67" GR / BLB to OBV / Bail / Mis-run on OBV shifting / Shifted 7" CMD Closed 5/10/2024 Five runs with 42 BO OBV Shifting tool unsuccessful / Open 4.5" S-Sleeve / Set ISO Sleeve / Prep for Circ Out 5/11/2024 Pull ISO Sleeve - Redress / 6 Bailer Runs / 3- 42 BO OBV Shifting Runs / 1- BLB run 5/12/2024 9 OBV shifting runs with additional shear stock / we did have ~ 15 ml of hyd fluid returns from vent side of control line today. 5/13/2024 Ran 3.5" LIB to 2632' SLM / Ran 7 Bailer runs / Ran 42 BO for Depth Correction / Determine we are Below OBV valve, OBV valve is now open. 5/14/2024 4 - 3.5" Bailer runs / 2-3" Bailer runs / Deepest depth 2651' SLM / Dehydrated Sand recovered 5/15/2024 Ran - 3" Bailer with T-Tails confirmed 4.5" x 3.5" XO / Run 2" Bailer / Pump down 3/8" Inj Line-move sand plug / Ran 3x-2.5" Bailer to 2711' SLM (near 3/8" Inj Line mandrel) 5/16/2024 Ran 6x 2.5" Bailer runs, final deepest depth -2687' SLM / Lost hole / Pump Meth down 5/8" line. 5/17/2024 RIH w/ 2x w / Bailer + 15' of fill from previous day / Inject down 3/8" line-fluff fill / RBIH tag at Inj Mandrel / RIH with 42 BO 3.5" Shifting tool / Shift 3.5" CMD Sleeve / RIH w / bailer for sample 5/18/2024 Ran Gauge Ring / Confirmed 4.5" Sliding Sleeve Open / Set Jet Pump / Set Tubing Stop / Set ACP-ISO Sleeve / Work complete / RDMO 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 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 Subsequent Form Required: Suspension Expiration Date: 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 Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Length Size Proposed Pools: TVD BurstMD Perforation Depth MD (ft): approval: Notify AOGCC so that a representative may witness Sundry Number: BOP Test Mechanical Integrity TestLocation Clearance ons of Approval: ection MIT Req'd? Yes No Subsequent Form Required: Suspension Expiration Date: AOGCC USE ONLY Contact Name: Contact Email: Contact Phone: e: certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. me and ure with Date: Date for 15.W ell Status after proposed work: Operations:OIL WINJ WDSPL Suspended proval:Date:GAS WAG GSTOR SPLUG esentative:GINJ Op Shutdown Abandoned nts: Proposal Summary Wellbore schematic13.W ell Class after proposed work: ations Program BOP Sketch Exploratory Stratigraphic Development Servic e SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Tubing Grade: Tubing MD (ft):Tubing Size:Perforation Depth TVD (ft):pth MD (ft): on ate e or al CollapseSizeTVDBurstMDLengthg D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD):MPSP (psi):Plugs (MD): PRESENT WELL CONDITION SUMMARY esignation (Lease Number):10.Field:Current Pools:Proposed Pools: g:8.W ell Name and Number: ation or Conservation Order governs well spacing in this pool? Yes Noquire a spac ing exception due to property boundaries? ame:4.Current Well Class:5.Permit to Drill Number: Exploratory Development Stratigraphic Service 6.API Number: quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___er Casing __________________ Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov ASRC Consulting and Environmental Services (ACES) Hydrate-P1 3900 C Street, Suite 700, Anchorage, AK 99503 ADL 047450 Prudhoe Bay Unit Undefined Gas Pool 3452' MD 3379' TVD 3322' MD 3253' TVD 900 psi NA NA 24"148'148' 16"x14"2199'2155' 10-3/4" / 9-5/8"2670' / 3443'2609' / 3370' 345' 5-1/2"3205'3138' 7" x 4-1/2" x 3-1/2" x 2-7/8" 7740 psi 6390 psi L-80 3013' MD2916' to 2942' MD 2856 to 2881' TVD 9-5/8" x 3-1/2" x 2-3/8" Hydraulic Set Production Packer 2692' MD / 2637' TVD ROakley@ASRCenergy.com 907-230-5059 50-029-23737-00-00 4020 / 4760 psi6450 / 6870 psi 117' 3412' 2167 Flow test Flare Authorization for extended flow test 222-141 Ray Oakley upon approval VP of Drilling, Projects, Engineering Doug Cismoski Digitally signed by Doug Cismoski Date: 2024.06.14 15:39:04 -08'00' 324-345 By Grace Christianson at 8:12 am, Jun 17, 2024 SFD 6/17/2024 Flaring of test production prior to regular production through July 31, 2024, is authorized in accordance with 20 AAC 25.235(d)(6) BJM 6/26/24 DSR-6/17/24 None *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.26 12:33:59 -08'00'06/26/24 RBDMS JSB 062624 ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 1 of 2 June 14, 2024 Mr. Brett Huber, Sr, Chair, Commissioner Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for authorization to flare for MHP well Hydrate-P1 (PTD 222141) Dear Commissioners, ASRC Consulting & Environmental Services, LLC (ACES), as operator of four wells related to a Long- Term Production Test of Methane Hydrates located on the Kuparuk State 7-11-12 pad, herein applies for AOGCC authorization of extended flaring as allowed in 20 AAC 25.235(d)(6). The methane hydrate production test is scheduled to conclude on or before July 31, 2024. We have produced at a stable flowing bottom-hole pressure (FBHP) but higher than the desired objective. In addition, produced gas rates have been limited due to the test facility’s maximum gas consumption rate. In order to achieve the scientific objective of studying methane hydrate dissociation behavior at lower pressures, we will exceed the test facility gas consumption rate. Background: x The agreement with PBU WIOs authorizing the Methane Hydrate Production Test facility and production does not authorize feeding into PBU infrastructure. Therefore, all gas produced from wells during the test is to be used onsite. x At times when produced gas is below the Test Facility’s demand, fuel gas is sourced from the Oliktok Pipeline. x The Test Facility lacks appropriate equipment to condition and compress produced gas for injection into the Oliktok Pipeline. x To date, the test well is producing less water than expected and has effectively removed thermal evaporators from the operation. The evaporators were to be the largest on-site consumer of produced gas. x Two 500kW load banks were installed to increase our microturbine generator gas consumption. x Anticipated flare volume could potentially reach 500,000 standard cubic feet per day (SCFD) and the flare is capable of rates more than 4 million SCFD. x With the limited time remaining in the production test, there are no feasible options for increasing gas consumption capacity onsite, aside from flaring. The remaining science objective of this production test is to establish a baseline of methane hydrate reservoir behavior and evaluate several production methods at low (<650 psi) reservoir pressures. Managing the associated produced gas at this lower bottomhole pressure will require extended flaring. ACES understands that the commission may, in its discretion, authorize the flaring or venting of gas for purposes of testing a well before regular production, as described in 20 AAC 25.235(d)(6). The Long- Term Production Test of Methane Hydrates is a test of an unproven resource and is a pilot prior to any regular production activity. ACES applies for advance authorization from the AOGCC for extended gas flaring, as necessary, over the remainder of the production test. Please do not hesitate to contact Ray Oakley at 907-230-5059 or myself should you have any questions regarding this request. ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 2 of 2 Sincerely, Doug Cismoski, P.E. Vice President of Drilling, Projects and Engineering ASRC Energy Services | Consulting & Environmental 3900 C Street, Suite 701, Anchorage, Alaska 99503 Work: (907) 339-7410 Email: dcismoski@asrcenergy.com | asrcenergy.com Sincerely, Doug Cismoski, P.E. 95/8"CasingPBTDͲ~3314ftMDastagged HydrateͲP1(PTW1) JetPumpInstallation Asrun5/18/2024 36"OpenHole 16"84lbs/ftx14"82.5lbs/ftLͲ80VacuumInsulatedCasing ~2199ftMD/2155ftTVD 20”OpenHole–2215ftMD ~2911ftMD/2850ftTVD– Top of Hydrate BͲUnit 12½”OpenHole–3452ftMD/3379ftTVD 9Ͳ5/8"LͲ8047lbs/ftCasingͲ3443ftMD/3370ftTVD 24"XͲ60189lbs/ftConductor–117ftbelowGL 4 ½” 12.6 lbs/ft Orbit Barrier Valve (9% Cr) w/3.750" profile (2 x ¼” C/L) at 2648 ft MD *** OBV locked open, 5/17/2024 9 5/8" x 3 ½” x 2 3/8" Hydraulic Set Twin Seal Production Packer at 2692 ft MD 4 ½” 12.6 lbs/ft L80 CMD Sliding Sleeve w/3.750" F Profile at 2631 ft MD 3 ½” 9.2 lbs/ft L80 tubing 8.268" OD x 3 ½” Downhole Heater At 2767 ft MD 3 ½” 9.2 lbs/ft tubing 9 5/8"” 47 lbs/ft Casing 9Ͳ5/8" Sand Control Packer SCͲ2R at 2860 ft MD GeoFORMTM (5 ½” 23 lbs/ft Base Pipe) from 2911 – 2949 ft MD 10 ¾” x 9 5/8" Casing XͲOver 2670 ft MD / 2615 ft TVD 7" 29 lbs/ft L80 Tubing/Shroud Access ESP 5 ½” and 7 " OD Motor Shroud with 3.85" internal seal bore Access ESP 3.813" NoͲGo and ‘B’ Profile Crossover 10 ¾” 55.5 lbs/ft Casing 5 ½” Solid Aluminum Bull Plug Shoe – Bottom at 3205 ft MD 3 ½” 9.2 lbs/ft CMD Sliding Sleeve w/ 2.750" F Profile at 2721 ft MD 3 ½” L80 Chemical Injection mandrel for 3/8" line at 2728 ft MD 7” P/T Gauge mandrel L80 at 2306 ft MD SureSENS SPTV Tubing/Annulus – T7/T8 7” P/T Gauge mandrel L80 at 2204 ft MD SureSENS SPTV Tubing/Annulus – T9/T10 7" 26 lbs/ft L80 Tubing 3 ½” P/T Gauge mandrel at 2735 ft MD SureSENS SPTV Tubing/Annulus – T5/T6 3 ½ ” 9.2 lbs/ft P/T Gauge mandrel at 2846 ft MD SureSENS SPTV Tubing/Annulus – T3/T4 2 7/8 ” P/T Gauge mandrel at 2959 ft MD SureSENS SPTV Tubing/Annulus – T1/T2 4 ½” 12.6 lbs/ft x 3 ½" 9.2 lbs/ft X/over L80 2Ͳ7/8” L80 Chemical Injection Mandrel for 5/8" line at 3005 ft MD 1 x ¼ Single Line for P/T Gauges Single Line DTS/DAS Single line DSS 2 x ¼” Dual line Barrier Valve Single Line P/T Gauges Down hole heater Heater cable1 x д” Chemical Injection ESP Cable 1 x з ” Single Line Fluid Injection 7" Tubing Hanger 3 ½” 9.2 lbs/ft x 2 д " 4.6 lbs/Ō X/over L80 2 7/8 " 4.6 lbs/ft L80 Tubing w/ Slotted Tubing from 2914 – 2953 ft MD WEG – Bottom at 3013.5 ft MD 7” P/T Gauge mandrel L80 at 297 ft MD SureSENS SPTV Tubing/Annulus – T11/T12 7" 29 lbs/ft L80 CMD Sliding Sleeve w/5.875" AF Profile at 2523 ft MD 13¼”OpenHole–2750ftMD Access ESP Annular Connection Port 5 ½" 23 lbs/ft L80 Casing 5 ½" 17 lbs/ft L80 Casing Oriented Perforations 2916.5 ft MD to 2942.5 ft MD 4 ½” PrimePump Jet Pump landed in CMD Sliding Sleeve 16"x14"VICcasingcementedwith893bbl11ppgleadand287 bbl12.5ppgtailcement.114bblcementreturnedtosurface. 10Ͳ3/4"x9Ͳ5/8"casingcementedwith228bbl10.7ppgleadand 145bbl12.5ppgtailcement.174bblcementreturnedtosurface. Access ESP 3” ID Isolation Sleeve installed across Annular Connection Port 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 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 Subsequent Form Required: Suspension Expiration Date: 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 Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Length Size Proposed Pools: TVD BurstMD Perforation Depth MD (ft): approval: Notify AOGCC so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearance ons of Approval: ection MIT Req'd? Yes No Subsequent Form Required: Suspension Expiration Date: AOGCC USE ONLY Contact Name: Contact Email: Contact Phone: e: certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. me and ure with Date: Date for 15.W ell Status after proposed work: Operations:OIL WINJ WDSPL Suspended proval:Date:GAS WAG GSTOR SPLUG esentative:GINJ Op Shutdown Abandoned nts: Proposal Summary Wellbore schematic 13.W ell Class after proposed work: ations Program BOP Sketch Exploratory Stratigraphic Development Service SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Tubing Grade: Tubing MD (ft):Tubing Size:Perforation Depth TVD (ft):pth MD (ft): on ate e or al CollapseSizeTVDBurstMDLengthg D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD):MPSP (psi):Plugs (MD): PRESENT WELL CONDITION SUMMARY esignation (Lease Number):10.Field:Current Pools:Proposed Pools: g:8.W ell Name and Number: ation or Conservation Order governs well spacing in this pool? Yes Noquire a spacing exception due to property boundaries? ame:4.Current Well Class:5.Permit to Drill Number: Exploratory Development Stratigraphic Service 6.API Number: quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___er Casing __________________ Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov ASRC Consulting and Environmental Services (ACES) Hydrate-P1 3900 C Street, Suite 700, Anchorage, AK 99503 ADL 047450 Prudhoe Bay Unit Undefined Gas Pool 148' 3452' MD 3379' TVD 3322' MD 3253' TVD 900 psi NA NA 24"148'148' 2199'16"x14"2199'2155' 3443' 10-3/4" / 9-5/8"2670' / 3443'2609' / 3370' 345' 5-1/2"3205'3138' 7" x 4-1/2" x 3-1/2" x 2-7/8" 7740 psi 6390 psi L-80 3013' MD2916' to 2942' MD 2856 to 2881' TVD 9-5/8" x 3-1/2" x 2-3/8" Hydraulic Set Production Packer 2692' MD / 2637' TVD Ray Oakley ROakley@ASRCenergy.com 907-230-5059 Install jet pump 222-141 50-029-23737-00-00 4020 / 4760 psi6450 / 6870 psi Wednesday, May 8, 2024 VP of Drilling, Projects, Engineering By Grace Christianson at 8:23 am, May 08, 2024 117' 3412' SFD May 8, 2024 DSR-5/9/24 May 08, 2024 Jet pump operation approved on a temporary basis for up to 6 months from this sundry's approval date. Operation beyond 6 months will be re-evaluated at that time, and will require 10-3/4" csg pressure test. Waiver to 20AAC25.200(d) approved based on short-term production test, presence of DTS/DSS wires outside production casing able to detect a casing leak. If DTS/DSS indicates production casing leak, well must be shut-in immediately and reported to AOGCC. SFD 5/8/2024BJM 5/13/24 10-404 2167' JLC 5/14/2024 Hydrate-P1 (PTW1) Intervention Program Pull ESP, Open Barrier Valve and Swap to Jet Pump Alaska Methane Hydrate Project North Slope, Alaska May 7, 2024 Prepared by 3900 C Street, Suite 700 Anchorage, Alaska 99503 Alaska Methane Hydrate Project North Slope, Alaska Japan Oil, Gas, Metals National Corporation i May 2024 Rev. 1.0 THIS PAGE INTENTIONALLY LEFT BLANK Alaska Methane Hydrate Project North Slope, Alaska Japan Oil, Gas, Metals National Corporation 1 May 2, 2024 Rev. 1.0 Well Status, Operational Overview and Well Schematic Hydrate-P1 is currently offline following swap-out of the ESP pack-off, because the downhole barrier valve (OBV) will not open. There is a slow leak across the OBV. Current pressure at the perfs is 1120 psi, per the installed pressure gauge. Based on 0.1 psi/ft gas gradient, the maximum pressure anticipated at surface is 850 psi. The decision was made to change from ESP to jet pump as the artificial lift method for the next phase of the production test. The first section below covers the in-progress steps required to pull the pack-off and wireline-retrievable ESP in order to access the inoperable downhole barrier valve (OBV) and open it. The second section covers the steps required to install the jet pump. The attached 10-403 Sundry is submitted for the jet pump installation portion of the procedure. Below is a high-level overview of the steps required for both objectives. Barrier valve steps: 1. Rig up slickline. 2. Perform drift run to tubing stop on top of retrievable ESP assembly. 3. Run in hole with GS tool to pull tubing stop. 4. Perform run with prong or stem bar to equalize standing valve. 5. Run in hole with GS tool to pull tubing pack-off from above ESP pump assembly. 6. Pull ESP and motor Completed 05-06-2024 7. Tag OBV 8. Bail sand and solids if needed. 9. Cycle Control Lines of OBV 10. If unsuccessful in opening OBV Run B-Shifting Tool to Lock Open OBV 11. Drift Run / Tag bottom Sample Bailer Jet pump steps: 12. Install Jet Pump in 4-1/2 CMD Sliding sleeve 13. Shift 7 CMD Sliding Sleeve Closed 14. Set ISO sleeve across ACP (Annular Connection Port) 15. Rig-down and move out slickline unit. Alaska Methane Hydrate Project North Slope, Alaska Japan Oil, Gas, Metals National Corporation 2 May 2, 2024 Rev. 1.0 9 5/8" Casing PBTD ~3314 ft MD as tagged Hydrate P1 (PTW1) Proposed Jet Pump Installation 5/13/2024 36" Open Hole 16" 84 lbs/ft x 14" 82.5 lbs/ft L 80 Vacuum Insulated Casing ~2199 ft MD / 2155 ft TVD 20 Open Hole 2215 ft MD ~2911 ft MD / 2850 ft TVD Top of Hydrate B Unit 12 ½ Open Hole 3452 ft MD / 3379 ft TVD 9 5/8" L 80 47 lbs/ft Casing 3443 ft MD / 3370 ft TVD 24" X 60 189 lbs/ft Conductor 117 ft below GL 4 ½ 12.6 lbs/ft Orbit Barrier Valve (9% Cr) w/3.750" profile (2 x ¼ C/L) at 2648 ft MD Valve will be locked open or milled out if cannot be successfully locked open. 9 5/8" x 3 ½ x 2 3/8" Hydraulic Set Twin Seal Production Packer at 2692 ft MD 4 ½ 12.6 lbs/ft L80 CMD Sliding Sleeve w/3.750" F Profile at 2631 ft MD 3 ½ 9.2 lbs/ft L80 tubing 8.268" OD x 3 ½ Downhole Heater At 2767 ft MD 3 ½ 9.2 lbs/ft tubing 9 5/8" 47 lbs/ft Casing 9 5/8" Sand Control Packer SC 2R at 2860 ft MD GeoFORMTM (5 ½ 23 lbs/ft Base Pipe) from 2911 2949 ft MD 10 ¾ x 9 5/8" Casing X Over 2670 ft MD / 2615 ft TVD 7" 29 lbs/ft L80 Tubing/Shroud Access ESP 5 ½ and 7 " OD Motor Shroud with 3.85" internal seal bore Access ESP 3.813" No Go and B Profile Crossover 10 ¾ 55.5 lbs/ft Casing 5 ½ Solid Aluminum Bull Plug Shoe Bottom at 3205 ft MD 3 ½ 9.2 lbs/ft CMD Sliding Sleeve w/ 2.750" F Profile at 2721 ft MD 3 ½ L80 Chemical Injection mandrel for 3/8" line at 2728 ft MD 7 P/T Gauge mandrel L80 at 2306 ft MD SureSENS SPTV Tubing/Annulus T7/T8 7 P/T Gauge mandrel L80 at 2204 ft MD SureSENS SPTV Tubing/Annulus T9/T10 7" 26 lbs/ft L80 Tubing 3 ½ P/T Gauge mandrel at 2735 ft MD SureSENS SPTV Tubing/Annulus T5/T6 3 ½ 9.2 lbs/ft P/T Gauge mandrel at 2846 ft MD SureSENS SPTV Tubing/Annulus T3/T4 2 7/8 P/T Gauge mandrel at 2959 ft MD SureSENS SPTV Tubing/Annulus T1/T2 4 ½ 12.6 lbs/ft x 3 ½" 9.2 lbs/ft X/over L80 2 7/8 L80 Chemical Injection Mandrel for 5/8" line at 3005 ft MD 1 x ¼ Single Line for P/T Gauges Single Line DTS/DAS Single line DSS 2 x ¼ Dual line Barrier Valve Single Line P/T Gauges Down hole heater Heater cable1 x Chemical Injection ESP Cable 1 x Single Line Fluid Injection 7" Tubing Hanger 3 ½ 9.2 lbs/ft x 2 " 4.6 lbs/ X/over L80 2 7/8 " 4.6 lbs/ft L80 Tubing w/ Slotted Tubing from 2914 2953 ft MD WEG Bottom at 3013.5 ft MD 7 P/T Gauge mandrel L80 at 297 ft MD SureSENS SPTV Tubing/Annulus T11/T12 7" 29 lbs/ft L80 CMD Sliding Sleeve w/5.875" AF Profile at 2523 ft MD 13 ¼ Open Hole 2750 ft MD Access ESP Annular Connection Port 5 ½" 23 lbs/ft L80 Casing 5 ½" 17 lbs/ft L80 Casing Oriented Perforations 2916.5 ft MD to 2942.5 ft MD 4 ½ PrimePump Jet Pump landed in CMD Sliding Sleeve 16"x14" VIC casing cemented with 893 bbl 11 ppg lead and 287 bbl 12.5 ppg tail cement. 114 bbl cement returned to surface. 10 3/4" x 9 5/8" casing cemented with 228 bbl 10.7 ppg lead and 145 bbl 12.5 ppg tail cement. 174 bbl cement returned to surface. Access ESP 3 ID Isolation Sleeve installed across Annular Connection Port 1 McLellan, Bryan J (OGC) From:Shirzadi, Shahryar <sshirzadi@asrcenergy.com> Sent:Monday, May 13, 2024 2:58 PM To:McLellan, Bryan J (OGC) Subject:RE: Hydrate P1 (PTD 222-141) jet pump sundry Attachments:Hydrate-P1 (PTW1) Proposed Jet Pump Completion Schematic 5-13-24.pdf Bryan, Attached is the new schematic for PTW1 with JP. Shahryar (Shawn) Shirzadi, B.S, M.S. Subsurface and Wells ASRC Energy Services 3900 C Street, Suite 601, Anchorage, Alaska 99503 Work: (907) 339-6462 Cell: (832) 490-4628 Email: sshirzadi@asrcenergy.com asrcenergy.com From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, May 13, 2024 2:46 PM To: Shirzadi, Shahryar <sshirzadi@asrcenergy.com> Subject: RE: Hydrate P1 (PTD 222-141) jet pump sundry Shawn, In my email below, I misquoted the number of the regula on needing a waiver for jet pump opera ons. It is 20 AAC 25.200(d), related to produc on packer isola ng tubing from annulus. The sundry is ready to go, I just need to a ach the wellbore diagram. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 From: Shirzadi, Shahryar <sshirzadi@asrcenergy.com> Sent: Monday, May 13, 2024 12:54 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Oakley, Raymond <roakley@asrcenergy.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: Hydrate P1 (PTD 222-141) jet pump sundry Bryan, We do have three different ways of monitoring the production packer leaks/communication. One is DTS in casing (10 ¾) which shows temperature anomalies above and below the packer. This is monitored daily. Second, we have pressure and temperature gauges in annulus above and below the packer which we monitor continuously in our production control systems. Third, we have DSS fiber which will also indicate if there are any pressure anomalies causing stress signal across the packer. A forward-circulating JP would result in significant facility re-design which cannot be done during the short-term nature of this production test (to finish by end of July 2024). Due to the short nature of this project (end of July 2024), as well as the scientific objectives to ensure the produced fluid is not contaminated with chemicals, we have not used corrosion inhibitor in our operations. USGS, NETL and JOGMEC are keen on daily fluid samples and analysis for geological and hydrate studies in the future from PTW1. Shahryar (Shawn) Shirzadi, B.S, M.S. Subsurface and Wells ASRC Energy Services 3900 C Street, Suite 601, Anchorage, Alaska 99503 Work: (907) 339-6462 Cell: (832) 490-4628 Email: sshirzadi@asrcenergy.com asrcenergy.com From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, May 13, 2024 12:41 PM To: Shirzadi, Shahryar <sshirzadi@asrcenergy.com> Cc: Oakley, Raymond <roakley@asrcenergy.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: Hydrate P1 (PTD 222-141) jet pump sundry Shahryar, The AOGCC recently issued Conserva on Order CO 808 which includes rules for jet pumps at Milne Point for Hilcorp. Although your opera ons are not subject to this CO, we do try to be somewhat consistent across operators. Your well design doesnt t into any of the approved categories in CO 808 because it is a reverse circula ng jet pump with high pressure on the IA and no way to monitor for a leak in the produc on casing. See CO 808 CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 here: h ps://ogc-docs.commerce.alaska.gov/weblink/0/doc/114532/Page1.aspx Let me know if this link doesnt work and Ill help you navigate to it on our website. Is it feasible for you to install a forward-circula ng jet pump? Do you plan to inject corrosion inhibitor in the power uid? A short-dura on ow test would be treated di erently than a well on long-term produc on. Approximately how long do you plan to con nue on jet pump opera on? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Shirzadi, Shahryar <sshirzadi@asrcenergy.com> Sent: Monday, May 13, 2024 11:11 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: Hydrate P1 (PTD 222-141) jet pump sundry Hi Bryan, We are working on the schematic today, will send one as soon as its ready. Regarding the IA/tubing communication, it is the same as what we had with ESP, the only pressure communication is through the Jet pump, which is above the production packer (where the 4.5 sleeve is and has been open throughout the operation in line with previous sundry). In case of Jet Pump, there will be no gas flow through the annulus. All flow is through tubing. Best regards, Shahryar (Shawn) Shirzadi, B.S, M.S. Subsurface and Wells ASRC Energy Services 3900 C Street, Suite 601, Anchorage, Alaska 99503 Work: (907) 339-6462 Cell: (832) 490-4628 Email: sshirzadi@asrcenergy.com asrcenergy.com 4 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, May 10, 2024 3:50 PM To: Shirzadi, Shahryar <sshirzadi@asrcenergy.com> Subject: RE: Hydrate P1 (PTD 222-141) jet pump sundry Do you have a proposed wellbore diagram showing the jet pump? I assume that the jet pump will allow communica on from tubing to IA if the well is shut-in, e ec vely bypassing the produc on packer. Is that correct? You would need to request a waiver or variance from 20 AAC 25.005 for that. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Shirzadi, Shahryar <sshirzadi@asrcenergy.com> Sent: Friday, May 10, 2024 11:16 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: Hydrate P1 (PTD 222-141) jet pump sundry Bryan, Any chance we can get a signed copy of sundry today, as we are gearing up to install jet pump on Sunday. Let me know if you have any questions. Sincerely, Shahryar (Shawn) Shirzadi, B.S, M.S. Subsurface and Wells ASRC Energy Services 3900 C Street, Suite 601, Anchorage, Alaska 99503 Work: (907) 339-6462 Cell: (832) 490-4628 Email: sshirzadi@asrcenergy.com asrcenergy.com CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 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. 5 From: Shirzadi, Shahryar <sshirzadi@asrcenergy.com> Sent: Friday, May 10, 2024 10:55 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: Hydrate P1 (PTD 222-141) jet pump sundry Hi Bryan, The answers to your questions are below in red. Shahryar (Shawn) Shirzadi, B.S, M.S. Subsurface and Wells ASRC Energy Services 3900 C Street, Suite 601, Anchorage, Alaska 99503 Work: (907) 339-6462 Cell: (832) 490-4628 Email: sshirzadi@asrcenergy.com asrcenergy.com From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, May 9, 2024 2:59 PM To: Shirzadi, Shahryar <sshirzadi@asrcenergy.com> Subject: FW: Hydrate P1 (PTD 222-141) jet pump sundry Shahryar, I received an out of o ce reply from Ray. In his absence, can you answer the ques ons below regarding the sundry applica on? Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 6 From: McLellan, Bryan J (OGC) Sent: Thursday, May 9, 2024 1:30 PM To: Oakley, Raymond <roakley@asrcenergy.com> Subject: Hydrate P1 (PTD 222-141) jet pump sundry Ray, I have a few ques ons about the jet pump sundry applica on for this well. 1. Is this to be a reverse-circula ng jet pump comple on, meaning you are pumping power uid down the IA and returns up the tubing? Yes, injec on down into IA and produce through tubing. 2. What is the maximum power uid injec on pressure? Not to exceed 2800 psig. 3. When was the last MITIA and to what pressure? The MITIA (and tubing) was performed on 2/25/2023. Both tubing and IA tested to 3000 psig surface pressure for 30 minutes and passed. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 1 Davies, Stephen F (OGC) From:Oakley, Raymond <roakley@asrcenergy.com> Sent:Wednesday, May 8, 2024 11:18 AM To:Davies, Stephen F (OGC) Cc:Cismoski, Doug Subject:RE: Hydrate-P1 (PTD 222-141, Sundry 324-279) - Question Stephen, Thanks for the question. It is a rig table / RKB issue: RKB is 31.3 above ground level. So, all MD/TVD depths on completion report, completion diagram, and the 10-403 are correct. The schematic is right about the conductor, also: 117 below ground level (GL) is equivalent to 148 MD/ 148TVD with the RKB reference. Unfortunately, the lengths on the 10-403 are incorrect, 31 to 32 too long, for conductor and both casings, because I did NOT account for the rig table. I apologize for that error. As discussed by phone, below are the correct lengths, so that the 10-403 may be easily corrected. String Length Conductor 117 Surface Casing 2167 Production casing 3412 Respectfully, Ray Ray Oakley Petroleum Engineer Methane Hydrate Project ASRC Energy Services 907-230-5059 cell 907-339-6218 o ice From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Wednesday, May 8, 2024 9:22 AM To: Oakley, Raymond <roakley@asrcenergy.com> Subject: FW: Hydrate-P1 (PTD 222-141, Sundry 324-279) - Question Ray, Minor ques on: The conductor depth listed on the Sundry Applica on form and on the Well Comple on Report is 148. On the well schema c drawing, it is listed as 117 below ground level. Which is correct? All other casing depths on the applica on agree with those on the drawing and on the Well Comple on Report. You don't often get email from roakley@asrcenergy.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. CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any a achments, contains informa on from the Alaska Oil and Gas Conserva on Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain con den al and/or privileged informa on. The unauthorized review, use or disclosure of such informa on may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without rst saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov 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:Oakley, Raymond Cc:Cismoski, Doug; Spence, Clinton; Olsen, Clark; Regg, James B (OGC) Subject:RE: Hydrate P1: Open OBV Date:Thursday, May 2, 2024 3:13:00 PM Attachments:Hydrate-P1 (PTW1) Pack-off ESP - open OBV 10-403 Program 5-2024.pdf Ray, ASRC has approval to proceed with this work without a sundry. ASRC must submit a 10-404 after completing the work scope. Also, be sure the re-start is compliant with the requirements outlined in Docket OTH-23-023. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Oakley, Raymond <roakley@asrcenergy.com> Sent: Thursday, May 2, 2024 2:46 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Cismoski, Doug <dcismoski@asrcenergy.com>; Spence, Clinton <cspence@asrcenergy.com>; Olsen, Clark <colsen@asrcenergy.com> Subject: Hydrate P1: Open OBV Bryan, As discussed by phone, here is the high-level plan for Hydrate-P1 to address the downhole barrier valve that is not opening. The slickline work is scheduled to begin this Sunday, May 5. Please let me know if a 10-403 is required, and I will get the package completed and submitted directly. Respectfully, Ray Ray Oakley Petroleum Engineer Methane Hydrate Project Hydrate-P1 (PTW1) Intervention Program Pull ESP, Open OBV Alaska Methane Hydrate Project North Slope, Alaska May 2024 Prepared by 3900 C Street, Suite 700 Anchorage, Alaska 99503 Alaska Methane Hydrate Project North Slope, Alaska Japan Oil, Gas, Metals National Corporation i May 2024 Rev. 1.0 THIS PAGE INTENTIONALLY LEFT BLANK Alaska Methane Hydrate Project North Slope, Alaska Japan Oil, Gas, Metals National Corporation 1 May 2, 2024 Rev. 1.0 1.0 Operational Overview and Well Schematic This program covers the steps required to pull the pack-off and ESP on the retrievable wireline assembly currently installed in the Hydrate-P1 well in order to access the inoperable downhole barrier valve (OBV). A determination of next artificial lift method, jet pump or re-designed ESP, is pending, based on equipment availability. Below is a high-level overview of the steps required. • Rig up slickline. • Perform drift run to tubing stop on top of retrievable ESP assembly. • Run in hole with GS tool to pull tubing stop. • Perform run with prong or stem bar to equalize standing valve. • Run in hole with GS tool to pull tubing pack-off from above ESP pump assembly. • Pull ESP. • Tag OBV. • Cycle Control Lines of OBV, attempting to open OBV. • If unsuccessful in opening OBV – Run B-Shifting Tool to “Lock Open OBV”. • Drift Run / Tag bottom – Sample Bailer. • Rig-down and move out slickline unit. Alaska Methane Hydrate Project North Slope, Alaska Japan Oil, Gas, Metals National Corporation 2 May 2, 2024 Rev. 1.0 OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 1 of 1 February 22, 2024 Bryan McLellan, Petroleum Engineer James Brooks, Research Analyst Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Monthly Production Reports for the Methane Hydrates Production Test Dear Bryan, James, Please find enclosed the production reports for October, November and December 2023 for the Methane Hydrate Long-term Production Test. We understand our obligation to submit production reports monthly and identified a gap in our compliance reporting process after achieving stable production which we are self-reporting now. The production test began on October 26, 2023. The plant startup up to stable operations has been challenging due to many factors that could not be anticipated but are typical of new technology trial programs. Our primary challenge has been learning how to operate our single test well which is producing significantly less than expected (roughly one percent of plant installed design capacity). This low production rate has complicated both stable well operations and production accounting efforts requiring significant human intervention to develop methods to accurately calculate the low produced volumes. In January, we achieved a sustained duration of steady flow based on well pressures and measured gradients that allowed us to develop a reliable method to measure gas and water daily production volumes. This has allowed us to submit a representative and true report for January’s production and reconciled previous months’ production volumes. As we proceed with the production test for the remaining few months of this test, we don’t anticipate further challenges in providing monthly production reports. Please contact me at any time with questions about the Methane Hydrate Long-term Production Test. Sincerely, Ray Oakley Petroleum Engineer Methane Hydrate Project ASRC Consulting & Environmental 907-230-5059 cell 907-339-6218 office About ASRC Consulting & Environmental, LLC ASRC Consulting & Environmental, LLC (ACES) is a subsidiary of ASRC Energy Services, LLC (AES). AES is a wholly owned subsidiary of the Alaska Native corporation Arctic Slope Regional Corporation (ASRC). With over 2,000 employees and more than 40 years of experience serving Alaska and working in the Arctic, AES has the expertise to handle every phase of an energy project regardless of scale or location. ACES is considered a Small Disadvantaged Business and Small Business Administration 8(a) program when subcontracting on a federal government contract and will count toward the prime contractor’s Small Disadvantaged Business subcontracting goal. 8.OIL (BBL) 9.WATER (BBL) 10.GAS (MCF) 11.OIL (BBL) 12.W ATER (BBL) 13.GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 5 27 508 0 12.6 50.5 0 340 1,364 0 340 1,36414.TOTALContact Email: roakley@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-7218 Title: Petroleum Engineer Authorized Name and Digital Signature with date: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas November, 2023 3.Type 5.Method 7.Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1.Well Number 2.API Number: XX-XXX-XXXXX-XX-XX 4.Field & Pool Code 6.Days in Operation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakley on Mar. 1, 2024 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 5 6 767 0 9.9 8.2 0 59 49 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas October, 2023 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation 0 59 4914. TOTALContact Email: roakley@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-7218 Title: Petroleum Engineer Authorized Name and Digital Signature with date: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakleyon Mar. 1, 2024 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 February 12, 2024 Mr. Ray Oakley ASRC Energy Services 3900 C Street, Suite 700 Anchorage, AK 99503 Subject: Docket Number: OTH-24-002 Notice of Violation - Rescinded Request for Information Safety Valve System Test Hydrate P1 (PTD 2221410) Dear Mr. Oakley: Staff from ASRC Consulting and Environmental Services (ASRC) and the Alaska Oil and Gas Conservation Commission (AOGCC) met on February 6, 2024, in regards to a January 25, 2024 notice of violation issued for failing to take advantage of an extended shutdown to test the test well’s safety valve system. The purpose of that discussion was to provide the AOGCC with additional information describing the events that occurred during an extended shutdown of the Methane Hydrate Project (Kuparuk State 7- 11-12 pad) flow test. ASRC offered the additional details in support of reasons for not testing the flowing well’s safety valve system as required by the AOGCC’s letter dated September 5, 2023. During the February 6 meeting and in a subsequent email dated February 8, 2024, ASRC detailed the high level of activity triggered by an unexpected rise of the well’s bottomhole and inner annulus pressures. The activities included troubleshooting the electrical submersible pump (ESP), surface facility cleaning, repair operations, and restart of the ESP. ASRC notes that even after restarting the ESP there was uncertainty about its performance for at least the first day after restart. ASRC has demonstrated to AOGCC’s satisfaction that the diagnostics and efforts required to bring the test well back online did not provide an appropriate opportunity to test the safety valve system during the shutdown period. The AOGCC rescinds this notice of violation based on the additional details provided on February 6 and February 8. Sincerely, Jessie L. Chmielowski Commissioner cc: P. Brooks Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.02.12 08:45:29 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Oakley, Raymond To:Regg, James B (OGC) Cc:Cismoski, Doug; Curley, Patrick; Gardner, Jared; McLellan, Bryan J (OGC) Subject:Re: NOV RFI (Jan. 25, 2024) Docket Number: OTH-24-002 Date:Thursday, February 8, 2024 8:43:58 AM Some people who received this message don't often get email from roakley@asrcenergy.com. Learn why this isimportant Dear Jim, Thank you for the recent opportunity to discuss the above-referenced Notice of Violation (NOV) Request for Information (RFI) and to present additional information about activity surrounding the Hydrate P1 well and the associated test facility. This email summarizes our February 6 meeting and responds to your request to provide a written description of our plan for future safety valve system (SVS) testing. The NOV related to the second condition on an SVS system test waiver, dated September 5, 2023, that required SVS performance tests to be “done on an opportunistic basis driven by shut-in events.” The NOV identified a December 12, 2023 status report that described an issue with the electrical submersible pump (ESP) and related shutdown, during which an SVS performance test was not performed. As discussed in our meeting, however, this outage required a high level of activity that included troubleshooting operations, work required to prepare the site, and an eventual wellwork operation to reset the upper sealing element of the ESP assembly. When Hydrate P1 was eventually restarted, we still suspected additional issues with the ESP, and only after a day of production were we able to conclude the well equipment was fully operational. In light of this activity, we request your concurrence that the event did not provide an “opportunistic basis” for SVS testing. In that meeting, we also provided a forward look for the remainder of the Hydrate production test. We anticipate the production test will conclude no later than June 30. There are potential scenarios for the production test to conclude earlier. In all cases, however, a short data monitoring period is planned after production testing ends. You also requested that we clarify our SVS testing plans to satisfy the second condition of the September 5, 2023 waiver. The current operation has Hydrate P1 producing at a steady flowing bottom hole pressure for several weeks. At the conclusion of this stage, currently scheduled for mid to late February, we have an opportunity to shut in the well while preparing the facility for our next stage. We plan to provide notice for an SVS performance test at that time. We will also conduct additional SVS performance tests if and when Hydrate P1 is shut in after this next phase and Operations is standing by waiting on additional equipment. Thank you again for your assistance with this issue, and please do not hesitate to contact me if you have questions or require additional information. Sincerely, Ray Oakley Petroleum Engineer Methane Hydrate Project ASRC Consulting & Environmental, LLC (ACES) 907-230-5059 cell 907-339-6218 office 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov January 25, 2024 CERTIFIED MAIL – RETURN RECEIPT REQUESTED 7018 0680 0002 2049 1129 Mr. Ray Oakley ASRC Energy Services - 3900 C Street, Suite 700 Anchorage, AK 99503 Subject: Docket Number: OTH-24-002 Notice of Violation Request for Information Safety Valve System Test Hydrate P1 (PTD 2221410) Dear Mr. Oakley: On September 5, 2023, the Alaska Oil and Gas Conservation Commission (AOGCC) conditionally approved a safety valve system waiver requested by ASRC Consulting and Environmental Services (ASRC) for the Methane Hydrate Project located at Kuparuk State 7-11-12 pad. ASRC’s request was to test the safety valve system (SVS) “on an opportunistic basis driven by shut-in events due to operational needs” instead of a calendar-driven test schedule as required by 20 AAC 25.265(h)(5). The waiver is specific to the production well test phase of the project. AOGCC’s approval requires the following: 1. SVS performance tests must be performed before placing well Hydrate P1 online. Tests must include all SVS components including the ESD capability. 2. Subsequent SVS performance tests must be done on an opportunistic basis driven by shut- in events. AOGCC witnessed the Hydrate P1 initial SVS test on September 25, 2023, prior to this well being placed on production. ASRC’s summary of recent operations dated December 12, 2023, reports that on November 26, 2023, the plant and surface safety valves tripped on a low wellhead tubing pressure due to poor electrical submersible pump (ESP) performance. Hydrate P1 was returned to production on December 6 after addressing the ESP issue, apparently without testing the safety valve system (no notice provided for opportunity to witness safety valve system tests, and no test report). Failure to test the safety valve system during this shut down is a violation of condition 2 of AOGCC’s approval for operating Hydrate P1. Docket Number: OTH-24-002 January 25, 2024 Page 2 of 2 Within 14 days of receipt of this letter, ASRC is requested to provide: - written details and an example of its regulatory compliance tracking system; and - the specific corrective actions taken to prevent recurrence of missed well safety valve system tests. This information request is made pursuant to 20 AAC 25.300. Failure to comply with this request is itself a violation subject to enforcement in accordance with 20 AAC 25.535. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, Brett W. Huber, Sr. Chair cc: P. Brooks Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.25 14:28:28 -09'00' William Isaacson ASRC Consulting & Environmental Services, LLC Drilling Engineer (907) 339-6455 wisaacson@asrcenergy.com 1 December 18, 2023 Alaska Oil and Gas Conservation Commission Natural Resource Technician 333 W 7th Ave, Suite 100 Anchorage, Alaska 99501 RE: DATA TRANSMITTAL - WELL: Hydrate-P1 PTD: 222-141 API: 50-029-23737-00-00 An additional DLIS file has been uploaded to the AOGCC Data Transfer Folder. The DLIS file, as outlined below, includes the necessary data tracks as back-up to the PDF Vision Image Logs previously provided. This log was mistakenly left out during any prior log or data transmittals. Data Transfer Folder: 222-141 Hydrate-P1 Subfolders: DLIS / Updated Vision Image DLIS Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PTD: 222-141 T38233 12/18/2023Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.18 13:54:20 -09'00' William Isaacson ASRC Consulting & Environmental Services, LLC Drilling Engineer (907) 339-6455 wisaacson@asrcenergy.com 1 December 14, 2023 Alaska Oil and Gas Conservation Commission Natural Resource Technician 333 W 7th Ave, Suite 100 Anchorage, Alaska 99501 RE: DATA TRANSMITTAL - WELL: Hydrate-P1 PTD: 222-141 API: 50-029-23737-00-00 Updated Final Mud Logs to correct issues with files included with prior transmittals. -Mud Logs and End of Well Mud Loggers Report The below files were included in e-mail dated December 14, 2023 from William Isaacson. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Revised PTD: 222-141 T37579 12/15/2023Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.15 10:23:02 -09'00' 1 Carlisle, Samantha J (OGC) From:Oakley, Raymond <roakley@asrcenergy.com> Sent:Tuesday, December 12, 2023 4:13 PM To:McLellan, Bryan J (OGC); Regg, James B (OGC) Cc:Cismoski, Doug Subject:RE: Weekly updates Attachments:MHP report to AOGCC week ending 2023-12-10.docx Bryan, Jim, Please ﬁnd enclosed the ﬁrst report of operaƟons from the Methane Hydrate Long‐term ProducƟon Project (MHP). I apologize for the delay in reporƟng these trends to the AOGCC. The project has had several ﬂow measurement, automaƟon and operaƟonal issues related to lower‐than‐expected water producƟon rates. We are circulaƟng make up water via chemical injecƟon lines to the lower compleƟon and due to measurement error, produced water daily rates were being calculated in the negaƟve. The relaƟve low producƟon gas rates have also challenged the facility metering. We have made several adjustments to meters, piping and the measurement system to ﬁnally have conﬁdence in the reported volumes. Respecƞully, Ray Ray Oakley Petroleum Engineer Methane Hydrate Project ASRC Energy Services 907‐230‐5059 cell 907‐339‐6218 office From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, December 12, 2023 11:25 AM To: Oakley, Raymond <roakley@asrcenergy.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Weekly updates Ray, Has ASRC been providing weekly updates as required by condiƟon 5 of the aƩached leƩer? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 You don't often get email from roakley@asrcenergy.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. ❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Dec 12, 2023 Mr. BreƩ Huber, Sr, Chair, Commissioner Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Alaska Oil and Gas ConservaƟon Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Dear Commissioners, ASRC ConsulƟng and Environmental Services, LLC, as operator of four wells related to a Long-Term ProducƟon Test of Methane Hydrates located on the Kuparuk State 7-11-12 pad, offers the following report on recent operaƟons:  10/26: Well brought online.  11/26: Plant and SSVs tripped on low wellhead tubing pressure due to poor ESP performance.  12/6: Well BOL following ESP pack-off replacement.  12/9: Barrier valve (OBV) was closed temporarily due to poor performance of ESP.  12/10: OBV opened back up with limited drawdown. Well API PTD Status HYDRATE P1 50 029 237 370 000 222141 Gas producer – online HYDRATE P2 50 029 237 320 000 222125 Monitor well HYDRATE 01 50 029 236 130 000 218125 Monitor well HYDRATE 02 50 029 237 280 000 222114 Monitor well Please do not hesitate to contact Ray Oakley at 907-230-5059 should you have any quesƟons regarding this request. Respecƞully, Ray Oakley Petroleum Engineer Methane Hydrate Project ASRC Energy Services 907-230-5059 cell | 907-339-6218 office 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:Isaacson, William To:McLellan, Bryan J (OGC) Cc:Dial, Amanda Subject:Hydrate-P1 ESP Pack-off Changeout Date:Friday, December 1, 2023 10:33:35 PM Bryan, As discussed, this note is to document our conversation on the plans to change out a failed pack-off at the top of the wireline retrievable ESP in the Hydrate-P1 well and that there was no need to submit an Application for Sundry for this work. The work will involve pulling a tubing stop above the pack-off and then the pack-off itself. We will then go right back in with a new pack-off and tubing stop assembly. Regards, Bill Isaacson Drilling Engineer ASRC Energy Services Alaska, Inc. 3900 C Street, Suite 701 Anchorage, AK 99503 Direct: 907-339-6455 | Cell: 907-242-7483One Crew, One JourneyHonoring the values of our founders as we develop the future. 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov September 5, 2023 Ray Oakley ASRC Consulting and Environmental Services, LLC 3900 C Street Suite 700 Anchorage, AK 99503 Re: Docket Number: OTH-23-023 Hydrate-P1 (PTD 222-141) Kuparuk State 7-11-12 Pad Dear Mr. Oakley: On June 29, 2023, ASRC Consulting and Environmental Services, LLC (ACES) submitted two letters to the Alaska Oil and Gas Conservation Commission (AOGCC) regarding well Hydrate- P1. In the letters, ACES requested waivers to 20 AAC 25.265(b) and 20 AAC 25.265(h)(5) as well as approval to produce the well through the annulus. Specifically, ACES requested: x Waiver to 20 AAC 25.265(b) to allow the well to be produced with an emergency shut down (ESD) system on the production annulus and the Safety Valve System (SVS) low- pressure pilots isolated until the well reaches stable, steady state production and the pressure trends indicate that a pilot system can be utilized without inadvertently triggering a shut-in due to production instability. x Waiver to 20 AAC 25.265(h)(5) to allow the frequency of SSV testing to be driven by planned shut-in events. x Approval for production through the annulus per 20 AAC 25.200(d). The AOGCC hereby APPROVES ACES’s requests as described in ACES’s June 29, 2023 letters with the following conditions: 1. SVS performance tests must be performed before placing well Hydrate-P1 online. Tests must include all SVS components including the ESD capability. 2. Subsequent SVS performance tests must be done on an opportunistic basis driven by shut- in events. 3. Function tests of the SVS components – including the ESD capability – must occur not later than 6 months after the initial performance test. 4. SVS testing results and strategy must be reviewed with AOGCC every 6 months and before commencing a flow test in a different well. 5. ACES must provide to AOGCC a weekly report of operations to include the following information: a. Current status of all wells involved with the flow test Docket Number: OTH-23-023 Hydrate-P1 Flow Test September 5, 2023 b. Flow rate trend (graphed) c. Pressure trend (graphed) d. Occurrence of any well shutdowns Please contact Jim Regg of our staff at 907-793-1236 if you have any questions on this approval. Sincerely, Brett W. Huber, Sr. Jessie L. Chmielowski Gregory C. Wilson Chair, Commissioner Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.09.05 12:16:01 -08'00' Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.05 13:03:22 -08'00' Gregory Wilson Digitally signed by Gregory Wilson Date: 2023.09.06 09:46:46 -08'00' June 29, 2023 Mr. Brett Huber, Sr, Chair, Commissioner Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Dear Commissioners, ASRC Consulting and Environmental Services, LLC, (ACES), as Operator of four wells related to a Long-Term Production Test of Methane Hydrates located on the Kuparuk State 7-11-12 pad, request waiver for well Hydrate-P1, Permit to Drill #222-141, to the following Alaska Administrative Code: 20 AAC 25.265 (b) and 20 AAC 25.265. (h)(5). 20 AAC 25.265 (b) states “A safety valve system must have a surface safety valve with an actuator and a low-pressure mechanical or electrical detection device with the capability to shut-in a well when the well’s flow line pressure drops below the required system actuation pressure.” 20 AAC 25.265. (h)(5) states “(5) a performance-test must be conducted semi-annually, not to exceed 210 days between tests, unless the commission prescribes a different testing interval based on test performance results.” Background ASRC Consulting & Environmental Services, LLC (ACES) has contracted with the US Department of Energy’s National Energy Technology Laboratories (NETL) and the Japan Oil Gas Metals Energy Company (JOGMEC) to be a third-party operator (TPO) in the execution of a long-term production test of methane hydrates on the North Slope. This production test scope includes well planning, drilling, coring, monitoring and other items to understand the long-term production behavior of methane hydrates. All work will be conducted on the Kuparuk State 7-11-12 pad. ACES has drilled three methane hydrate wells, Hydrate-02 as a geo-data well and observation well, and producers Hydrate-P1 and Hydrate-P2, on 7-11-12 pad for a several-month production test through a small production facility being assembled on the pad. The production test will consist of slowly decreasing the flowing bottomhole pressure from initial shut-in bottom hole pressure while monitoring the production, pressure, and temperature trends at the production well and monitoring wells nearby. Hydrate-P1 has been perforated and completed with sand control. P1 will be produced with an electric submersible pump (ESP). Annular production of gas is planned to enable gas separation from the produced water before the ESP pump intake. Aims of the test are scientific research regarding long-term methane hydrate production and field- testing of less-proven technologies, such as GeoForm for sand control and an in-line downhole electric heater to prevent hydrate formation. A fundamental science objective of the program is to maintain a stable flowing bottomhole pressure and to minimize well shut-ins in order to maximize the quality of production and reservoir data collected. Additionally, well shut-ins should be minimized due to the high risk associated with the formation of ice and hydrates in the tubing and annulus during shut-in periods. The expected production from each well is highly variable and production is expected to be unsteady. The ESP will provide sufficient wellhead pressure on the tubing to configure a low- pressure shutdown system, however, the annulus is expected to have a variable pressure of between 0 to 400 psi. The tubing and production annulus will each be equipped with operating SSVs. Both SSVs are held open by one electric over hydraulic control panel system. Separate wireless pressure transmitters monitor the tubing / water flowline pressure and production annulus / gas flowline pressure. A high and low pressure set point will cause an ESD shut-in of both SSVs via an electric signal to the hydraulic panel solenoid. 20 AAC 25.265 (b): low-pressure shutdown ACES proposes that the production annulus SSV be initially installed with an active ESD capability but a low-pressure shutdown which is defeated. The defeated shutdown system will be locked out and tagged. ACES proposes utilizing the low-pressure shutdown on the production annulus SSV should the well stabilize and the annulus pressure trends indicate that a shutdown system can be utilized without inadvertently triggering shut-in due to production instability. It can be considered safe to defeat the low-pressure pilot of the annular SSV because the reservoir and wellbore fluid’s natural state is a solid hydrate. The wellbore is kept clear of hydrates by the addition of heat while flowing, and 50/50 methanol freeze protect along with heat when the well is shut-in. Additionally, the well is equipped with a downhole barrier valve below the ESP that provides a barrier between the reservoir and the surface. 20 AAC 25.265. (h)(5): semi-annual tests of the SSV Limited well intervention activity is anticipated to support the several-month production test of the methane hydrate well. The initial reservoir production is anticipated to be very low, and with water injected down the water injection line to allow the ESP to operate in a normal range as we gradually lower the flowing bottomhole pressure and increase hydrate dissociation and production. The initial completion is designed to allow for low flow rates with a lower flow ESP. When the well’s production exceeds the low flow ESP capacity, a higher flow rate ESP will be wireline deployed. A practical goal of the production plan is to minimize the number of times that the ESP is cycled off and back on to assure the life of the ESP. ACES proposes that the initial SSV performance test be completed via a planned, witnessed performance test during facility commissioning, prior to the well being initially put on production, rather than being tested within 5 days after being brought online. A calendar-driven SSV test schedule makes difficult the project goal to minimize well shut-ins for scientific and operational purposes. ACES proposes that subsequent SSV testing be on an opportunistic basis driven by shut-in events due to operational needs. ACES proposes to give the AOGCC notice of a planned shut-in for wellwork, and to conduct a witnessed SSV test at that time. If a shut-in event does not occur within the normal 6-month SSV testing window, ACES proposes that the SSV controls be function-tested to ensure functionality of the safety device, in place of shutting in the well for SSV testing. Documentation - 7-11-12 Pad is a manned facility. The board operator will be monitoring well-pressure trends and have the ability to activate the annular SSV ESD from the control room. - A production technician on site will perform frequent walk arounds of the production train including the well house and flowline. - There is an ESD button for the annular SSV in the wellhouse. - The well is completed with a barrier valve which can be manually closed from a control panel in the wellhouse to isolate the well below the point of tubing by annulus communication (the open sliding sleeve). - Annular production is expected to be unstable; the well is predicted to be in unsteady flow conditions initially and could remain unsteady and unstable for a prolonged duration. - Only one well will be produced at any given time. The facility only has one flowline. - In all flow cases, the producing well has an actuated surface safety valve as part of the inner annulus / gas flowline production system. - The formation of ice and hydrates in the tubing and annulus during production and during shut-ins is a production risk that will be minimized with Tubing by Annulus communication (via sliding sleeve) below the ESP along with heat trace cable, a downhole electric heater below the production packer, and water and methanol injection lines. Request Waiver to 20 AAC 25.265. (b) to allow the well to be produced with an ESD system on the production annulus and the SSV low-pressure pilots isolated until the well reaches stable, steady state production and the pressure trends indicate that a pilot system can be utilized without inadvertently triggering a shut-in due to production instability. Waiver to 20 AAC 25.265. (h)(5) to allow the frequency of SSV testing to be driven by planned shut- in events. Supporting Attachments: Production Well Completion Schematic Production Well Log Summary Wellhead and Tree P&ID SSV P&ID Please do not hesitate to contact Ray Oakley at 907-230-5059 should you have any questions regarding this request. Respectfully, Ray Oakley Petroleum Engineer Methane Hydrate Project ASRC Consulting and Environmental Services 907-230-5059 cell | 907-339-6218 office 9 5/8" Casing PBTD ‐ ~3314 ft MD as tagged Hydrate‐P1 (PTW1) As Run 2/27/2023 36" Open Hole 16" 84 lbs/ft x 14" 82.5 lbs/ft L‐80 Vacuum Insulated Casing ~2199 ft MD / 2155 ft TVD 20” Open Hole – 2215 ft MD ~2911 ft MD / 2850 ft TVD – Top of Hydrate B‐Unit 12 ½” Open Hole – 3452 ft MD / 3379 ft TVD 9‐5/8" L‐80 47 lbs/ft Casing ‐ 3443 ft MD / 3370 ft TVD 24" X‐60 189 lbs/ft Conductor – 117 ft below GL 4 ½” 12.6 lbs/ft Orbit Barrier Valve (9% Cr) w/3.750" profile (2 x ¼” C/L) at 2648 ft MD 9 5/8" x 3 ½” x 2 3/8" Hydraulic Set Twin Seal Production Packer at 2692 ft MD 4 ½” 12.6 lbs/ft L80 CMD Sliding Sleeve w/3.750" F Profile at 2631 ft MD 3 ½” 9.2 lbs/ft L80 tubing 8.268" OD x 3 ½” Downhole Heater At 2767 ft MD 3 ½” 9.2 lbs/ft tubing 9 5/8"” 47 lbs/ft Casing 9‐5/8" Sand Control Packer SC‐2R at 2860 ft MD GeoFORMTM (5 ½” 23 lbs/ft Base Pipe) from 2911 – 2949 ft MD 10 ¾” x 9 5/8" Casing X‐Over 2670 ft MD / 2615 ft TVD 7" 29 lbs/ft L80 Tubing/Shroud Access ESP 5 ½” and 7 " OD Motor Shroud with 3.85" internal seal bore Access ESP 3.813" No‐Go and ‘B’ Profile Crossover 10 ¾” 55.5 lbs/ft Casing 5 ½” Solid Aluminum Bull Plug Shoe – Bottom at 3205 ft MD 3 ½” 9.2 lbs/ft CMD Sliding Sleeve w/ 2.750" F Profile at 2721 ft MD 3 ½” L80 Chemical Injection mandrel for 3/8" line at 2728 ft MD 7” P/T Gauge mandrel L80 at 2306 ft MD SureSENS SPTV Tubing/Annulus – T7/T8 7” P/T Gauge mandrel L80 at 2204 ft MD SureSENS SPTV Tubing/Annulus – T9/T10 7" 26 lbs/ft L80 Tubing 3 ½” P/T Gauge mandrel at 2735 ft MD SureSENS SPTV Tubing/Annulus – T5/T6 3 ½ ” 9.2 lbs/ft P/T Gauge mandrel at 2846 ft MD SureSENS SPTV Tubing/Annulus – T3/T4 2 7/8 ” P/T Gauge mandrel at 2959 ft MD SureSENS SPTV Tubing/Annulus – T1/T2 4 ½” 12.6 lbs/ft x 3 ½" 9.2 lbs/ft X/over L80 2‐7/8” L80 Chemical Injection Mandrel for 5/8" line at 3005 ft MD 1 x ¼ Single Line for P/T Gauges Single Line DTS/DAS Single line DSS 2 x ¼” Dual line Barrier Valve Single Line P/T Gauges Down hole heater Heater cable1 x ⅜” Chemical Injection ESP Cable 1 x ⅝ ” Single Line Fluid Injection 7" Tubing Hanger 3 ½” 9.2 lbs/Ō x 2 ⅜ " 4.6 lbs/Ō X/over L80 2 7/8 " 4.6 lbs/ft L80 Tubing w/ Slotted Tubing from 2914 – 2953 ft MD WEG – Bottom at 3013.5 ft MD 7” P/T Gauge mandrel L80 at 297 ft MD SureSENS SPTV Tubing/Annulus – T11/T12 7" 29 lbs/ft L80 CMD Sliding Sleeve w/5.875" AF Profile at 2523 ft MD 13 ¼” Open Hole – 2750 ft MD Access ESP Annular Connection Port 5 ½" 23 lbs/ft L80 Casing 5 ½" 17 lbs/ft L80 Casing Oriented Perforations 2916.5 ft MD to 2942.5 ft MD AccessESP W‐line Retrievable ESP with top at 2482 ft MD 16"x14" VIC casing cemented with 893 bbl 11 ppg lead and 287 bbl 12.5 ppg tail cement. 114 bbl cement returned to surface. 10‐3/4" x 9‐5/8" casing cemented with 228 bbl 10.7 ppg lead and 145 bbl 12.5 ppg tail cement. 174 bbl cement returned to surface. MHP Well Hydrate-P1 Log Top B MHP Well Hydrate-P1 Tops Instrument flange on downstream side of actuated valve with companion flange & bull plug with bleeder. Second 2‐1/16" M120 GV installed before companion flange, bull plug, needle valve & gauge assembly. X Omit Actuated Valve and installed blind flange with port for bleeder downstream of instrument flange. Hydrate‐P1 Wellhead Configuration As Installed Needle valve and T with a needle valve bleeder and gauge installed on tree cap. Companion flange & bull plug with bleeder. VR plug not installed due to cement being flush with outlet and covering VR plug threads. Companion flange, bull plug, needle valve & gauge assembly. Cement is flush with outlet and covering VR plug threads. DSGN/CNST PI-00-0001-05 ALASKA METHANE HYDRATE PROJECT - SURFACE FACILITY DESIGN PIPING AND INSTRUMENTATION DIAGRAM WELLHEAD HYDRAULIC PANEL T. GLAZIER AES R. SEITZ R.SCHIMSCHEIMER P. RAMERT 05/28/21 NONE 418000A CURTIS A. WATTERS ME-11263R E G ISTEREDPROFE S S I O N A L E N GINEER 18000A-J04_21-059 Re-Issued For Construction - Process - Piping & Instrumentation Diagrams (MOD00) June 29, 2023 Mr. Brett Huber, Sr, Chair, Commissioner Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Dear Commissioners, ASRC Consulting and Environmental Services, LLC, as operator of four wells related to a Long-Term Production Test of Methane Hydrates located on the Kuparuk State 7-11-12 pad, requests specific approval for production through the annulus on well Hydrate-P1, Permit to Drill #222-141, per the following Alaska Administrative Code: 20 AAC 25.200 (d). 20 AAC 25.200 (d) states “All producing wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer that effectively isolate the tubing-casing annulus from fluids being produced, unless the commission specifically approved production through the annulus to increase flow rate without jeopardizing ultimate recovery from the well.” Background ASRC Consulting & Environmental Services, LLC (ACES) has contracted with the US Department of Energy’s National Energy Technology Laboratories (NETL) and the Japan Oil Gas Metals Energy Company (JOGMEC) to be a third-party operator (TPO) in the execution of a long-term production test of methane hydrates on the North Slope. This production test scope includes well planning, drilling, coring, monitoring and other items to understand the long-term production behavior of methane hydrates. All work will be conducted on Kuparuk State 7-11-12 pad. AES has drilled three methane hydrate production wells, Hydrate-P1 and Hydrate-P2, on 7-11-12 pad for a year-long production test through a small production facility being assembled on the pad. The production test will consist of slowly decreasing the flowing bottomhole pressure from initial shut-in bottom hole pressure while monitoring the production, pressure, and temperature trends at the production well and monitoring wells nearby. Hydrate-P1 has been perforated and completed with sand control. P1 will be produced with an electric submersible pump (ESP). Annular production of gas will be needed to enable gas separation from the produced water before the ESP pump intake. Communication between the inner annulus and tubing via sliding sleeve above the production packer will also allow for circulating out produced fluids during a shut-in period to prevent the formation of ice and hydrates in the tubing and annulus. Documentation - The target production zone of Hydrate-P1 is Unit B which has a SIBHP of approximately 1260psi and a depth of 2769 ft TVDSS. The initial dissociation pressure of hydrates in Unit B is anticipated to be 1140psi. - The target production zone of Hydrate-P1 is Unit B and Unit D. Unit D has a SIBHP of approximately 1000psi and a depth of 2276 ft TVDSS. The dissociation pressure of Unit D is anticipated to be 650 psi. - Only one well will be produced at any given time. The facility only has one flowline. - Well will be produced with ESP and the completion will be configured to separate gas from water downhole. - Downhole gas separation and production of gas up the annulus will enable increased water handling capability of the ESP, to meet the anticipated water and gas rates. - Gas produced up the annulus will be processed via a gas flowline and utilized on site. - The formation of ice and hydrates in the tubing and annulus during production and during shut- ins is a production risk that will be minimized with Tubing by Annulus communication below the ESP along with a tubing heat trace cable, a downhole electric heater, and water and chemical injection lines. - The well is completed with a barrier valve below the ESP which can be manually closed from the wellhouse to isolate the well below the point of tubing by annulus communication (sliding sleeve). Justification Annular production will allow for downhole gas separation from water, which will improve ESP operational capacity and longevity. ACES considers the practice of annular production safe as the well is equipped with downhole pressure and temperature gauges, the facility is manned 24/7 with personnel dedicated to monitoring the one producing well, and the well has a downhole barrier valve as a final contingency measure. The open sliding sleeves will also allow for pumping freeze-protect fluids while circulating out hydrate-prone produced water and methane, during a shut-in event. Request ACES requests specific approval for production through the annulus, per the following Alaska Administrative Code: 20 AAC 25.200 (d). Supporting Attachments: Production Well Completion Schematic Production Well Log Summary Wellhead and Tree P&ID Please do not hesitate to contact Ray Oakley at 907-230-5059 should you have any questions regarding this request. Respectfully, Ray Oakley Petroleum Engineer Methane Hydrate Project ASRC Consulting and Environmental Services 907-230-5059 cell | 907-339-6218 office 9 5/8" Casing PBTD ‐ ~3314 ft MD as tagged Hydrate‐P1 (PTW1) As Run 2/27/2023 36" Open Hole 16" 84 lbs/ft x 14" 82.5 lbs/ft L‐80 Vacuum Insulated Casing ~2199 ft MD / 2155 ft TVD 20” Open Hole – 2215 ft MD ~2911 ft MD / 2850 ft TVD – Top of Hydrate B‐Unit 12 ½” Open Hole – 3452 ft MD / 3379 ft TVD 9‐5/8" L‐80 47 lbs/ft Casing ‐ 3443 ft MD / 3370 ft TVD 24" X‐60 189 lbs/ft Conductor – 117 ft below GL 4 ½” 12.6 lbs/ft Orbit Barrier Valve (9% Cr) w/3.750" profile (2 x ¼” C/L) at 2648 ft MD 9 5/8" x 3 ½” x 2 3/8" Hydraulic Set Twin Seal Production Packer at 2692 ft MD 4 ½” 12.6 lbs/ft L80 CMD Sliding Sleeve w/3.750" F Profile at 2631 ft MD 3 ½” 9.2 lbs/ft L80 tubing 8.268" OD x 3 ½” Downhole Heater At 2767 ft MD 3 ½” 9.2 lbs/ft tubing 9 5/8"” 47 lbs/ft Casing 9‐5/8" Sand Control Packer SC‐2R at 2860 ft MD GeoFORMTM (5 ½” 23 lbs/ft Base Pipe) from 2911 – 2949 ft MD 10 ¾” x 9 5/8" Casing X‐Over 2670 ft MD / 2615 ft TVD 7" 29 lbs/ft L80 Tubing/Shroud Access ESP 5 ½” and 7 " OD Motor Shroud with 3.85" internal seal bore Access ESP 3.813" No‐Go and ‘B’ Profile Crossover 10 ¾” 55.5 lbs/ft Casing 5 ½” Solid Aluminum Bull Plug Shoe – Bottom at 3205 ft MD 3 ½” 9.2 lbs/ft CMD Sliding Sleeve w/ 2.750" F Profile at 2721 ft MD 3 ½” L80 Chemical Injection mandrel for 3/8" line at 2728 ft MD 7” P/T Gauge mandrel L80 at 2306 ft MD SureSENS SPTV Tubing/Annulus – T7/T8 7” P/T Gauge mandrel L80 at 2204 ft MD SureSENS SPTV Tubing/Annulus – T9/T10 7" 26 lbs/ft L80 Tubing 3 ½” P/T Gauge mandrel at 2735 ft MD SureSENS SPTV Tubing/Annulus – T5/T6 3 ½ ” 9.2 lbs/ft P/T Gauge mandrel at 2846 ft MD SureSENS SPTV Tubing/Annulus – T3/T4 2 7/8 ” P/T Gauge mandrel at 2959 ft MD SureSENS SPTV Tubing/Annulus – T1/T2 4 ½” 12.6 lbs/ft x 3 ½" 9.2 lbs/ft X/over L80 2‐7/8” L80 Chemical Injection Mandrel for 5/8" line at 3005 ft MD 1 x ¼ Single Line for P/T Gauges Single Line DTS/DAS Single line DSS 2 x ¼” Dual line Barrier Valve Single Line P/T Gauges Down hole heater Heater cable1 x ⅜” Chemical Injection ESP Cable 1 x ⅝ ” Single Line Fluid Injection 7" Tubing Hanger 3 ½” 9.2 lbs/Ō x 2 ⅜ " 4.6 lbs/Ō X/over L80 2 7/8 " 4.6 lbs/ft L80 Tubing w/ Slotted Tubing from 2914 – 2953 ft MD WEG – Bottom at 3013.5 ft MD 7” P/T Gauge mandrel L80 at 297 ft MD SureSENS SPTV Tubing/Annulus – T11/T12 7" 29 lbs/ft L80 CMD Sliding Sleeve w/5.875" AF Profile at 2523 ft MD 13 ¼” Open Hole – 2750 ft MD Access ESP Annular Connection Port 5 ½" 23 lbs/ft L80 Casing 5 ½" 17 lbs/ft L80 Casing Oriented Perforations 2916.5 ft MD to 2942.5 ft MD AccessESP W‐line Retrievable ESP with top at 2482 ft MD 16"x14" VIC casing cemented with 893 bbl 11 ppg lead and 287 bbl 12.5 ppg tail cement. 114 bbl cement returned to surface. 10‐3/4" x 9‐5/8" casing cemented with 228 bbl 10.7 ppg lead and 145 bbl 12.5 ppg tail cement. 174 bbl cement returned to surface. MHP Well Hydrate-P1 Log Top B MHP Well Hydrate-P1 Tops Instrument flange on downstream side of actuated valve with companion flange & bull plug with bleeder. Second 2‐1/16" M120 GV installed before companion flange, bull plug, needle valve & gauge assembly. X Omit Actuated Valve and installed blind flange with port for bleeder downstream of instrument flange. Hydrate‐P1 Wellhead Configuration As Installed Needle valve and T with a needle valve bleeder and gauge installed on tree cap. Companion flange & bull plug with bleeder. VR plug not installed due to cement being flush with outlet and covering VR plug threads. Companion flange, bull plug, needle valve & gauge assembly. Cement is flush with outlet and covering VR plug threads. William Isaacson ASRC Consulting & Environmental Services, LLC Drilling Engineer (907) 339-6455 wisaacson@asrcenergy.com 1 April 17, 2023 Alaska Oil and Gas Conservation Commission Natural Resource Technician 333 W 7th Ave, Suite 100 Anchorage, Alaska 99501 RE: DATA TRANSMITTAL - WELL: Hydrate-P1 PTD: 222-141 API: 50-029-23737-00-00 Updated Final Open Hole, Cased Hole and Mud Logs to correct issues with mud log files and include missing logs from the first transmittal. - GammaRay/Resistivity/Density/Neutron/Sonic - MudLogsandEndofWellMudLoggersReport - CementEvaluationIBC/CBL Data Transfer Folder: 222-141 Hydrate-P1 Subfolders: PDF, LAS, DLIS, Mud Logging, Cement Evaluation PTD: 222-141 T37579 Revised Data William Isaacson ASRC Consulting & Environmental Services, LLC Drilling Engineer (907) 339-6455 wisaacson@asrcenergy.com 2 Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.18 14:33:19 -08'00' William Isaacson ASRC Consulting & Environmental Services, LLC Drilling Engineer (907) 339-6455 wisaacson@asrcenergy.com 1 March 29, 2023 Alaska Oil and Gas Conservation Commission Natural Resource Technician 333 W 7th Ave, Suite 100 Anchorage, Alaska 99501 RE: DATA TRANSMITTAL - WELL: Hydrate-P1 PTD: 222-141 API: 50-029-23737-00-00 Final Open Hole Logs, Mud Logs and Directional Survey -Gamma Ray / Resistivity / Density / Neutron / Sonic -Mud Logs and End of Well Mud Loggers Report -Final SLB Directional Surveys Data Transfer Folder: 222-141 Hydrate-P1 Subfolders: PDF, LAS, DLIS, Mud Logging, Survey William Isaacson ASRC Consulting & Environmental Services, LLC Drilling Engineer (907) 339-6455 wisaacson@asrcenergy.com 2 Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 52.0 Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 n/a (ft MSL) 22. Logs Obtained: Surface Hole LWD Logs Ran: GR 23. BOTTOM 24" X-60 148 16"X14" L-80 2155 10-3/4" L-80 2609 9-5/8" L-80 3370 5-1/2" L-80 3138 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 599134.9 228 bbl lead/145 bbl tail If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, Production Hole LWD Logs Ran: Resistivity, GR, Density/Neutron, Sonic, NMR 9-5/8" Casing TUBING RECORD No Cement3205 2801 13.25" 3014'7" x 2-7/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ASRC Consulting & Environmental Services, LLC WAG Gas 2/27/2023 222-141 50-029-23737-00-00 Hydrate-P1 ADL 047450 829.6 FSL, 3882.7 FEL, Sec 7, T11N, R12E, UM LONS 22-004 12/28/2022 3452' / 3379' 3322' / 3253' 32.5' 3900 C Street Suite 700, Anchorage, AK, 99503 598673.21 5966179.48 1123 FSL, 3312 FEL, Sec 7, T11N, R12E, UM 1073 FSL, 3417 FEL, Sec 7, T11N, R12E, UM CASING WT. PER FT.GRADE 1/18/2023 CEMENTING RECORD 5966428.58 2002' / 1964' SETTING DEPTH TVD 5966480.92 TOP HOLE SIZE AMOUNT PULLED 599238.82 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. n/a BOTTOM SIZE DEPTH SET (MD) 2692' / 2637' PACKER SET (MD/TVD) 2860 36" 17 & 23 20" cement to surface pre-rig 0 893 bbl lead/287 bbl tail 47 0 2670 21990 0 55.5 3443 0 2609 189 166.5 148 0 2670 Flow Tubing Perforated Feb 5, 2023 Top: 2916.5' MD / 2856.4' TVD Bottom: 2942.5' MD / 2881.8' TVD 6-5/8" 18 SPF guns w/ 38.8 gram big hole charges loaded at 12 SPF to cover only 180 deg of wellbore. Guns were oriented to fire ~180 deg out from fiber optic cables on 9-5/8" casing. Ran a 5-1/2" lower completion liner to position sand control screens across the perforation interval. Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 12.5" Sr Res EngSr Pet GeoSr Pet Eng PBU Undefined Gas Pool n/a Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST n/a Date of Test: Oil-Bbl: 25. 26. Was hydraulic fracturing used during completion?YesNo ACID, FRACTURE,CEMENT SQUEEZE,ETC. TUBING RECORD 7" x 2-7/8" SIZE to production or injection? YesNo t each interval open (MD/TVD of Top and Bottom; Perforation Number; Date perf'd or liner run): d Feb 5, 2023 2916.5' MD / 2856.4' TVD 2942.5' MD / 2881.8' TVD SPF guns w/ 38 8 gram big hole charges loaded at 12 SPF to cover 2692' / 2637'3014' PACKER SET (MD/TVD)DEPTH SET (MD) No Cement9-5/8" Casing313880305860L-80&3 228 bbl lead/145 bbl tail13.25" 12.5" 2609 3370 0 60933 60 60 0L-80 L-80 55 5 893 bbl lead/287 bbl tail20"21550990L-8066 5 cement to surface pre-rig36"148080X-6089 AMOUNT PULLEDCEMENTING RECORDHOLESIZEBOTTOMTOPBOTTOMTOP SETTING DEPTH MDGRADEWT.PER FT. SETTING DEPTH TVD CASING, LINER AND CEMENTING RECORD Obtained: Hole LWD Logs Ran: GR List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, n Hole LWD Logs Ran: Resistivity, GR, Density/Neutron, Sonic, NMR on, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud taneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing ator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. onal or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore:21. Re-drill/Lateral Top Window MD/TVD: t electronic information per 20 AAC 25.050 n/a (ft MSL)n/a ion of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: x- y Zone- 4 x- y- Zone- 4 12. SSSV Depth MD/TVD:20. Thickness of Permafrost MD/TVD: pth: x-y- Zone- 4 LONS 22-0043452' / 3379'y-y- 2002' / 1964'966 80 9299238 82 n/a ion of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: oductive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 52.0 pth: 10. Plug Back Depth MD/TVD: 18. Property Designation: Hydrate-P1 ADL 047450 829.6 FSL, 3882.7 FEL, Sec 7, T11N, R12E, UM 3322' / 3253'1123 FSL, 3312 FEL, Sec 7, T11N, R12E, UM 1073 FSL, 3417 FEL, Sec 7, T11N, R12E, UM 1/18/2023 PBU Undefined Gas Pool ss: 7. Date Spudded: 15. API Number: 50-029-23737-00-0012/28/2022treet Suite 700, Anchorage, AK, 99503 or Name: 6. Date Comp.,Susp., or 14. Permit to Drill Number / Sundry: Aband.:onsulting & Environmental Services, LLC 2/27/2023 222-141 Status:OilSPLUG OtherAbandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory WINJ WDSPLNo. of Completions: _ServiceStratigraphic Test1 Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 84.5 JSB Completed 2/27/23 JSB RBDMS JSB 040523 Received 3/22/2023 GDSR-4/6/23 AOGCC A.Dewhurst 13MAR25 BJM 3/13/25 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 00 2002 1964 D Unit 2408 2359 2911 2851 Ugnu 3452 3379 31. List of Attachments: Summary of daily operations; wellbore schematic; directional survey, cementing summary; as-built survey, logging list, marker and overpressure list. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Mike Quick Digital Signature with Date:Contact Email:mquick@asrcenergy.com Contact Phone: 907-317-2969 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. N/A 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. B Unit (TPI) Authorized Title: Formation Name at TD: Authorized Name and Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Director of Drilling and Field Management Cismoski, Doug Digitally signed by Cismoski, Doug Date: 2023.03.21 13:03:41 -08'00' SV6 1,140 1,129 SV5 1,801 1,769 SV4 1,943 1,908 UG4 3,241 3,173 UG4A 3,309 3,240 See attached email. -A.Dewhurst 13MAR25 (SV1) (SV3) SingleLineDTS/DAS SingleLineDSS SingleLineP/TGauges 24"189#XͲ60 118'BelowGL (148'MD/TVD) 16"84#x14"82.5#LͲ80 ThermocaseVICw/VAMTopKB 2199'MD/2155'TVD 9Ͳ5/8"47#LͲ80VAMTop 3443'MD/3370'TVD HydrateͲP1CasingSchematic (Currentasof1/26/2023) 20"OpenHole 12Ͳ1/2"OpenHole ToTDat3452'MD/3372'TVD 13Ͳ1/4"OpenHole To2750'MD10Ͳ3/4"55.5#LͲ80VAMTop 2670'MD/2609'TVD 1/26/2023 Confidential AlaskaMethaneHydrateProject PTD:222Ͳ141 API:50Ͳ029Ͳ23737Ͳ00Ͳ00 Spud:12/28/2022 TD:1/18/2023 16"x14"VICcasingcementedwith 893bbl11ppgleadand287bbl 12.5ppgtailcement.114bbl cementreturnedtosurface. 10Ͳ3/4"x9Ͳ5/8"casingcemented with228bbl10.7ppgleadand 145bbl12.5ppgtailcement.174 bblcementreturnedtosurface. CompletionDetailon NextPage March 20, 2023 Mr. Greg Wilson, Commissioner Ms. Jessie Chmielowski, Commissioner Mr. Brett Huber, Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: 10-407 for Hydrate-P1 Permit to Drill No.: 222-141 API No: 50-029-23737-00-00 Dear Commissioners, Please find the enclosed 10-407 Well Completion Report for the Hydrate-P1 well. Included is the 10-407 form, drilling summary, wellbore schematic, final survey, and casing and cementing summary report. The Hydrate-P1 well will be the primary production well for the Methane Hydrate long term production test. If you have any questions, please contact Mike Quick at (907) 317-2969. Sincerely, Doug Cismoski Director of Drilling and Field Management ASRC Consulting & Environmental Services, LLC 95/8"CasingPBTDͲ~3314ftMDastagged HydrateͲP1(PTW1) AsRun2/27/2023 36"OpenHole 16"84lbs/ftx14"82.5lbs/ftLͲ80VacuumInsulatedCasing ~2199ftMD/2155ftTVD 20”OpenHole–2215ftMD ~2911ftMD/2850ftTVD– Top of Hydrate BͲUnit 12½”OpenHole–3452ftMD/3379ftTVD 9Ͳ5/8"LͲ8047lbs/ftCasingͲ3443ftMD/3370ftTVD 24"XͲ60189lbs/ftConductor–117ftbelowGL 4 ½” 12.6 lbs/ft Orbit Barrier Valve (9% Cr) w/3.750" profile (2 x ¼” C/L) at 2648 ft MD 9 5/8" x 3 ½” x 2 3/8" Hydraulic Set Twin Seal Production Packer at 2692 ft MD 4 ½” 12.6 lbs/ft L80 CMD Sliding Sleeve w/3.750" F Profile at 2631 ft MD 3 ½” 9.2 lbs/ft L80 tubing 8.268" OD x 3 ½” Downhole Heater At 2767 ft MD 3 ½” 9.2 lbs/ft tubing 9 5/8"” 47 lbs/ft Casing 9Ͳ5/8" Sand Control Packer SCͲ2R at 2860 ft MD GeoFORMTM (5 ½” 23 lbs/ft Base Pipe) from 2911 – 2949 ft MD 10 ¾” x 9 5/8" Casing XͲOver 2670 ft MD / 2615 ft TVD 7" 29 lbs/ft L80 Tubing/Shroud Access ESP 5 ½” and 7 " OD Motor Shroud with 3.85" internal seal bore Access ESP 3.813" NoͲGo and ‘B’ Profile Crossover 10 ¾” 55.5 lbs/ft Casing 5 ½” Solid Aluminum Bull Plug Shoe – Bottom at 3205 ft MD 3 ½” 9.2 lbs/ft CMD Sliding Sleeve w/ 2.750" F Profile at 2721 ft MD 3 ½” L80 Chemical Injection mandrel for 3/8" line at 2728 ft MD 7” P/T Gauge mandrel L80 at 2306 ft MD SureSENS SPTV Tubing/Annulus – T7/T8 7” P/T Gauge mandrel L80 at 2204 ft MD SureSENS SPTV Tubing/Annulus – T9/T10 7" 26 lbs/ft L80 Tubing 3 ½” P/T Gauge mandrel at 2735 ft MD SureSENS SPTV Tubing/Annulus – T5/T6 3 ½ ” 9.2 lbs/ft P/T Gauge mandrel at 2846 ft MD SureSENS SPTV Tubing/Annulus – T3/T4 2 7/8 ” P/T Gauge mandrel at 2959 ft MD SureSENS SPTV Tubing/Annulus – T1/T2 4 ½” 12.6 lbs/ft x 3 ½" 9.2 lbs/ft X/over L80 2Ͳ7/8” L80 Chemical Injection Mandrel for 5/8" line at 3005 ft MD 1 x ¼ Single Line for P/T Gauges Single Line DTS/DAS Single line DSS 2 x ¼” Dual line Barrier Valve Single Line P/T Gauges Down hole heater Heater cable1 x д” Chemical Injection ESP Cable 1 x з ” Single Line Fluid Injection 7" Tubing Hanger 3 ½” 9.2 lbs/Ō x 2 д " 4.6 lbs/Ō X/over L80 2 7/8 " 4.6 lbs/ft L80 Tubing w/ Slotted Tubing from 2914 – 2953 ft MD WEG – Bottom at 3013.5 ft MD 7” P/T Gauge mandrel L80 at 297 ft MD SureSENS SPTV Tubing/Annulus – T11/T12 7" 29 lbs/ft L80 CMD Sliding Sleeve w/5.875" AF Profile at 2523 ft MD 13¼”OpenHole–2750ftMD Access ESP Annular Connection Port 5 ½" 23 lbs/ft L80 Casing 5 ½" 17 lbs/ft L80 Casing Oriented Perforations 2916.5 ft MD to 2942.5 ft MD AccessESP WͲline Retrievable ESP with top at 2482 ft MD 16"x14"VICcasingcementedwith893bbl11ppgleadand287 bbl12.5ppgtailcement.114bblcementreturnedtosurface. 10Ͳ3/4"x9Ͳ5/8"casingcementedwith228bbl10.7ppgleadand 145bbl12.5ppgtailcement.174bblcementreturnedtosurface. Date EndDepth (ft) MudWeight (ppg) ActivitySummary 12/23/2022 ͲNOACCIDENTS,INCIDENTSORSPILLS.MOVERIGOVERPTW1ͲNOTLEVEL.MOVERIGBACK,SCRAPEHIGHSPOTSINRIG FOOTPRINT.MOVERIGBACKOVERPTW1.CONTINUERIGUPOPERATIONS. 12/24/2022 ͲNOACCIDENTS,INCIDENTSORSPILLS.FINISHBERMINGUPAROUNDRIG&CUTTINGSBOX.NIPPLEUP4'DIVERTERSPOOL &RISER.STOPWORKAUTHORITYDRILLASPERASRCCOMPANYREP.INSTALLMOUSEHOLE&RISER.INSTALL6Ͳ5/8" ELEVATORS,R/UPIPESPINNERS.P/U6Ͳ5/8"DRILLPIPE&RACKBACK,TOTAL32DRILLPIPESTANDSINDERRICK.P/U15 JTSHWDP&RACKBACK. 12/25/2022 ͲNOACCIDENTS,INCIDENTSORSPILLS.REPLACECLEANOUTVALVESINPIT1&2.REPAIRHERCULITELINER.TESTT.I.W. VALVE.REPLACECHECKVALVEONTESTPUMP.LOADPITSWITH412BBLOF8.5PPGDRILLPLEXMUD.LOAD2ROWSOF 16"X14"VICCASINGINTOPIPESHED,DRIFTANDTALLYBOTHROWS.MOVE2NDROWOF16"X14"VICCASINGFROMOFF DRILLER'SSIDETODRILLER'SSIDEOFPIPESHED. 12/26/2022 Ͳ NOACCIDENTS,INCIDENTSORSPILLS.BEGINTOROLLMUDOVERSHAKERS.PUMPMUDTHROUGHSURFACELINES& BLEEDERTOSHEARMUDPRIORTODRILLING.LOADWORKINGJOINT,M/UBHA#0,RIHTO40',M/UTOPDRIVE,BRING PUMPONLINE&FILLCONDUCTORWITHSPUDMUD.ONEOFTHE4"BALLVALVESONCONDUCTORWASCRACKED& LEAKING.DRAINRISER&CHANGEOUTCRACKED4"BALLVALVE.LOADMWD/GYRO/DDTOOLSINPIPESHED. 12/27/2022 Ͳ NOACCIDENTS,INCIDENTSORSPILLS.CONTSHEARINGMUD.CHECKALLPIPEHANDLINGEQUIPMENTFORUPCOMING BHA.LOAD6JTS8Ͳ1/4"DRILLCOLLARSINPIPESHED.HELDPREͲSPUDMEETINGWITHALL3RDPARTYPERSONNEL&RIG CREW.SPOTCEMENTSILOS.LOADWITH1036SXOFLEADCEMENT.BRINGONADDITIONALWBM. 12/28/2022 2508.7 NOACCIDENTS,INCIDENTSORSPILLS.HELD2NDPREͲSPUDMEETINGWITHNIGHTRIGCREW.BRINGDRILLCOOLONLINE ANDCHILLMUD.FINISHLOADING,STRAPPING&TALLYING16"X14"VICCASING&14"SHOETRACK.L/DWASHTOOL ASSEMBLY.DRILLFROM148'TO250',PUMPOUTOFHOLEWITHBHA#1ANDM/UBHA#2. 12/29/2022 3128.7 NOACCIDENTS,INCIDENTSORSPILLS.RIHWITHBHA#2,DRILLFROM250'TO278'MD,POOHTOCHANGEOUTGYRO TOOL,MUBHA#3WITHNEWGYROTOOL.RIHANDDRILLAHEADTO312'.PUMPOUTOFHOLEFROM312'TOPUMONEL COLLARS#5AND#6. 12/30/2022 9718.9 NOACCIDENTS,INCIDENTSORSPILLS.M/ULASTDRILLCOLLARSINTO12Ͳ1/4"SURFACEBHA#3,DRILLAHEADIN12Ͳ1/4" SURFACEHOLEFROM312'TO971'MD. 12/31/2022 1,7349.3 NOACCIDENTS,INCIDENTSORSPILLS.DRILLFROM971'TO1734'MD,REPLACESAVERͲSUBANDGRABBERDIES,REPAIR MUDPUMP#2BLEEDERVALVE. 1/1/2023 2,2159.5 NOACCIDENTS,INCIDENTSORSPILLS.DRILL12Ͳ1/4"HOLEFROM1734'TO2215'TD,CIRCULATEBOTTOMSUPWITH39° MUD,FLOWCHECKWELL,WELLSTATIC,POOHANDL/DBHA#3. 1/2/2023 2,2159.4 NOACCIDENTS,INCIDENTSORSPILLS.FINISHL/D12Ͳ1/4"BHA#3,M/U20"HOLEOPENERBHA#4ANDWASHDOWNUNTIL TAGAT375'MD.REAM20"HOLETO395'ANDPOOHTOCONDUCTORSHOETOCIRCULATEHOLECLEANANDCHILLMUD TO38°.WASH/REAM20"HOLEDOWNTO589',POOHTO135'ANDRIHHWDPTO591',CONTINUEREAMINGTO683'. SHUTDOWNTOWORKONMUDPUMP#1. 1/3/2023 2,2159.5 NOACCIDENTS,NOSPILLS,1NEARMISS.WASH/REAMWITH20"HOLEOPENER,BHA#4FROM683'TO884',INSPECT DERRICKAFTERPINFOUNDONFLOOR,WASH/REAMFROM884'TO913'.POOHBHA#4DUETOPRESSUREDROPAND LOWROP.L/DBHA#4ͲNOZZLEMISSINGFROMBULLNOSE,M/UBHA#5WITHNEWHOLEOPENERANDRIHWITHSAME. 1/4/2023 2,2159.5 NOACCIDENTS,INCIDENTSORSPILLS.RIHWITH20"HOLEOPENERBHA#5TO871',WASHTO913'WITHNOFILL, WASH/REAMFROM913'TO1555'OPENING12Ͳ1/4"HOLETO20" 1/5/2023 2,2159.5 NOACCIDENTS,INCIDENTS,ONENONͲRECORDABLESPILL.WASH/REAMWITH20"HOLEOPENERBHA#5FROM1555'TO 1668'.UNABLETOPASS1668',POOHTOINSPECTBHA#5.SOMECOMPONENTSWORNORUNDERGAUGE.SLIPANDCUT DRILLLINE.CHANGEOUTBHACOMPONENTSANDM/U20"HOLEOPENERBHA#6TO132'. 1/6/2023 2,2159.5 NOACCIDENTS,ONEINCIDENT,ONESPILLINCONTAINMENT.RIHWITH20"HOLEOPENERBHA#6FROM132'TO1325'. WASHFROM1325'TO1668',WASH/REAMFROM1668'TO2130'. 1/7/2023 2,2159.5 NOACCIDENTS,INCIDENTSORSPILLS.WASH/REAMFROM2130'TOTDAT2215',CIRCULATEBOTTOMSUP,SHORTTRIP TOBHA,CIRCULATE,POOHFROM2175',L/DBHA,R/UTORUN16"X14"VICSURFACECASING. 1/8/2023 2,2159.5 NOACCIDENTS,INCIDENTSORSPILLS.FINISHR/UCASINGEQUIP,M/U14"SHOETRACK,CHANGEOUTHANDLINGTOOLS FROM14"TO16".RUN16"X14"VICCASINGFROM124'TO1250'. 1/9/2023 2,2159.5 NOACCIDENTS,INCIDENTSORSPILLS.RUN16”X14”VICCASINGFROM1250’TO2135’.WASHFROM2135'TO2202', CIRCULATEBOTTOMSUP,M/UPORTEDPUP&SETSLIPSONFLOORWITHCASINGSHOEAT2199',P/U&RIHWITH CEMENTSTINGERON6Ͳ5/8"DPTO498'. 1/10/2023 2,2159.5 NOACCIDENTS,INCIDENTSORSPILLS.FINISHRIHWITHCEMENTSTINGINASSY&STINGINAT2115',CIRCULATE BOTTOMSUP.R/UCEMENTLINES&PSITESTSAME1000#LOW/3000#HIGH,GOODTEST.CEMENTSURFACECASINGAS PERHALLIBURTONCEMENTINGPROGRAM.PUMPED70BBLMUDPUSH,893BBLOF11PPGARCTICCEMLEADCEMENT, 287BBL12.5PPGTUNEDLIGHTCEMENT,FULLRETURNSTHROUGHCEMENTJOB,HAD114BBLOF11PPGCEMENT RETURNEDATSURFACE.SETCASINGSLIPSINWELLHEAD. HydrateͲP1DailyOperationsSummary PTD:222Ͳ141API:50Ͳ029Ͳ23737Ͳ00Ͳ00 NordicͲCalistaRig3 1/11/2023 2,2159.5 NOACCIDENTSORINCIDENTSONESPILLͲNONRECORDABLE.PJSM,N/URISERFLANGEAFTERSETTINGCASINGSLIPS, PUMPSCOURINGPILL&CIRCULATEHOLECLEAN.POOHWITHCEMENTSTINGINASSY.N/DRISER,TRANSFERCASING WEIGHTTOWELLHEADSLIPS,CUTCASING,INSTALLSTARTINGHEAD&DSA. 1/12/2023 2,2159.5 NOACCIDENTS,INCIDENTSORSPILLS.INSTALLANNULUSVALVES,PREPFORBOPINSTALLATION.WAITINGONWEATHERͲ PHASEIICONDITIONSFROM8:00AMTO18:00PM.SPINEROADSHUTDOWN4HRSFOREXTRACTIONOFVEHICLE.N/U DOUBLEGATE&ANNULAR. 1/13/2023 2,2159.5 NOACCIDENTS,INCIDENTSORSPILLS.PHASEIIWEATHERCONDITIONSTHROUGH3:15PM.FINISHN/U16Ͳ3/4"BOPE, LOAD12Ͳ1/2"BHAINTOPIPESHED,BEGINTESTING16Ͳ3/4"BOPEBEGINPRESSURETESTINGBOPETO250PSILOW/3000 PSIHIGH,(2500PSIONANNULAR)PERPTD,TESTWITNESSEDBYAOGCCINSPECTORSULLIVAN. 1/14/2023 2,2159.0 1SPILL(NONͲAGENCYREPORTABLE),NOACCIDENTSORINCIDENTS.CONTINUETESTING16Ͳ3/4"BOPE,ALLTESTED GOOD.P/U12Ͳ1/2"BHA#7&RIHTO2115',DISPLACEWELLWITH9.0PPGOBM,PRESSURETESTCASINGTO2000PSIͲ GOODTEST,TESTWITNESSWAIVEDBYAOGCCINSPECTORCOOK. 1/15/2023 2,2359.0 NOACCIDENTS,INCIDENTSORSPILLS.DRILLSHOETRACKFROM2115'TO2197'MD.PULLUPTO2193'TOCIRCULATE HOLECLEAN.CIRCULATEPITSOVERSHAKERSTOREMOVEICEWHILEDRILLCOOLCLEANED&CHANGEDOUTFILTERPOD SCREENSEVERY5Ͳ30MINUTES.DRILL20'OFNEWFORMATIONFROM2215'TO2235',CIRCULATEBOTTOMSUP, PERFORMFITTO12.0PPGEQUIVALENTWITH9.0PPGMWAND340PSIPRESSUREͲGOODTEST. 1/16/2023 2,3879.0 1INCIDENT,NOACCIDENTSORSPILLS.CIRCULATINGWHILECHILLINGMUD.REDUCEFLOWRATETOCLEANSCREENS. INCREASEDPUMPRATE,OBSERVEDLARGEAMOUNTOFICEINRETURNMUDATSHAKERS.SCREENOUTICEFROMMUD. DRILLFROM2215'TO2248'MD.MP#1DISCHARGEMANIFOLDDEVELOPEDALEAK,PULLUPINTOSHOE,MAKEREPAIRS TOMP#1.DRILLFROM2248'TO2387'MD.ECIPROCATE&COOLMUD. 1/17/2023 3,3549.1 ONESPILL.NOACCIDENTS,NOINCIDENTS.CHILLMUDTO20.7°IN32.7°OUT.DRILL12Ͳ1/2"HOLEFROM2387'TO2430 MD.DROP2"BALLTOOPENUNDERREAMERAT2420'(2210'UNDERREAMERDEPTH).DRILL&UNDERREAM12Ͳ1/2"x13Ͳ 1/4"HOLEFROM2420'TO2960'MD(2750'UNDERREAMERDEPTH).DROP2"BALLTOCLOSEUNDERREAMER.CONTINUE DRILLING12Ͳ1/2"HOLEFROM2960'TO3354'MD. 1/18/2023 3,4529.1 NOACCIDENTS,INCIDENTSORSPILLS.CHILLMUD.DRILL12Ͳ1/2"HOLEFROM3354'TO3452'MDTD.CIRCULATEB/U. POOH,HOLESWABBING,KELLYUP&BACKREAMFROM3452'TO2891'.POOHFROM2891'TOSHOEAT2145'. CIRCULATEB/U.RIHFROM2145'TO3434',WASHDOWNTO3452'.CIRCULATEB/U.POOHFROM3452'TO2170' RACKINGBACK.POOHFROM2170'TO749'LAYINGDOWNDP. 1/19/2023 3,4529.1 ONESPILL,NOACCIDENTSORINCIDENTS.POOHFROM998'TO289'LAYINGDOWNDP&HWDP.L/DBHA.STAGE MWD/LWDINPIPESHEDTODOWNLOADDATA.P/UTESTJT&WEARRINGPULLER.CHANGEOUTPIPERAMSFROM6Ͳ 5/8"TO10Ͳ3/4".RIGUPFORBOPETEST.LOADBAKER,SILIXA&SLBEQUIPMENTTORIGFLOOR.ATTEMPTTOPULLWEAR RING,UNABLETOLATCHINTOWEARRING.RIGUPBOPWASHTOOL&WASHWEARRING. 1/20/2023 3,4529.1 NOACCIDENTS,INCIDENTSORSPILLS.WASHDEBRISFROMSTACK,DRAINSTACK,PULLWEARRING,WASH STACK/WELLHEAD,SETTESTPLUG.TEST16Ͳ3/4"BOPE&ANNULARTO250PSILOW/3000PSIHIGH,(2500PSION ANNULAR)PERPTD,TESTWITNESSWAIVEDBYAOGCCINSPECTORMCLEOD,ALLTESTGOOD.HANGSHEAVES&SPOT SPOOLERS.DIAGNOSEISSUESWITHDRAWWORKS&SCR. 1/21/2023 3,4529.1 NOACCIDENTS,INCIDENTSORSPILLS.TROUBLESHOOTISSUEWITHDRAWWORKS&REPAIRSAME.L/DTESTPLUG,WEAR RING&RUNNINGTOOL.R/U&RUN9Ͳ5/8"SHOETRACK&9Ͳ5/8"47#L80CASING.M/U&SPLICEASSY#1,ASSY#2& PERFJOINT.INSTALLINGCABLECLAMPS/CENTRALIZERSASPERRUNNINGPROCEDURE. 1/22/2023 3,4529.1 NOACCIDENTS,INCIDENTSORSPILLS.RIHWITH9Ͳ5/8"47#L80CASINGFROM496'TO780'.PERFORMSPLICE&COLD SPRAYCALIBRATIONONASSY#2,#3&#4.SWITCHTO10Ͳ3/4"HANDLINGEQUIPMENT.RIHWITH10Ͳ3/4"X9Ͳ5/8"L80 CASINGFROM780'TO1386'.INSTALLINGCABLECLAMPS/CENTRALIZERSASPERRUNNINGPROCEDURE. 1/23/2023 3,4529.1 NOACCIDENTS,INCIDENTSORSPILLS.RIHWITH10Ͳ3/4"X9Ͳ5/8"CASINGFROM1386'TO3365',INSTALLINGCABLE CLAMPS/CENTRALIZERSASPERRUNNINGPROCEDURE.PERFORMEDCOLDSPRAYCALIBRATIONONDISTRIBUTED TEMPERATURESENSOR/DISTRIBUTEDACOUSTICSENSORCABLE.FILLINGUPPIPEEVERY10JOINTS.RIHWITHSLBEͲLINE GR/CCLTOCORRELATERATAGS.SPACEOUT&LANDHANGERAT3443'.PREPARETOCIRCULATEPRIORTOCEMENTJOB. 1/24/2023 3,4529.1 1INCIDENT,NOACCIDENTSORSPILLS.CIRCULATINGPREPARINGTOCEMENT10Ͳ3/4"X9Ͳ5/8"PRODUCTIONCASING. CEMENT10Ͳ3/4"X9Ͳ5/8"CASINGASPERHALLIBURTONCEMENTPROGRAM.PUMPED65BBLMUDPUSH,228BBLOF 10.7PPGARCTICCEMLEADCEMENT,145BBL12.5PPGTUNEDLIGHTCEMENT,FULLRETURNSTHROUGHCEMENTJOB, HAD174BBLOF10.7PPGCEMENTRETURNEDATSURFACE.DISPLACEDCEMENTWITH9.0PPGBRINE.WAITON CEMENT.R/DCEMENTEQUIP&CHOKE.REMOVEGBR,SLB,SILIXA&BAKERSPOOLS&EQUIPFROMRIGFLOORWITH CRANE.OFFLOAD9Ͳ5/8"&10Ͳ3/4"JOINTSOFCASINGFROMPIPESHED.R/D6Ͳ5/8"HANDLINGEQUIPMENT.LOAD4" DRILLPIPEDRIFT&TALLY,CONTINUECLEANINGMUDPITS. 1/25/2023 3,4529.1 1INCIDENT,NOACCIDENTSORSPILLS.WAITONCEMENT.CONTINUER/UTOP/U4"15.66#XTͲ39DP.BACKOUT LANDINGJT&L/DSAME.BAKER,SLB&SILIXATERMINATELINESONRIGFLOOR.N/DRISER&BOPE.LIFTANNULAR,FEED BAKER,SILIXA,ANDSLBCABLESTHROUGHANNULAR,PLACEANNULARONBEDTRUCKATCELLARDOOR.REMOVE OUTSIDEANNULARVALVES,INSTALLBLINDFLANGEWITHTESTPORTONEASTSIDEOFWELLHEAD,LIFTDRILLINGSPOOL FROMWELLHEAD,FEEDBAKER,SILIXA,&SLBCABLESTHROUGHDRILLINGSPOOL,REMOVEDRILLINGSPOOLFROM CELLAR.TRIMWIRES,&PREPFORADAPTERNIPPLEUP,NIPPLEUPADAPTER. 1/26/2023 3,4529.1 NOACCIDENTS,INCIDENTSORSPILLS.NUTUBINGSPOOLANDTESTSAMETO3000PSIFOR10MINS.BEGINFIBERLINE TERMINATIONSTHROUGHTUBINGSPOOL–BAKERFIBERLINEDAMAGED.LIFTSPOOLANDREDRESSCABLESON HANGER,RESETSPOOLANDTESTSAMETO3000PSIFOR10MINS.BAKERFIBERCABLEDAMAGEDA2NDTIME. CONTINUETOCLEANMUDPITSYSTEM.FLUSHALLMUDLINESWITHDEEPCLEAN.PREP4”DRILLPIPEFORPU. 1/27/2023 3,4529.1 NOACCIDENTS,INCIDENTSORSPILLS.BREAKANDLIFTTUBINGSPOOL.ACCESSADDITIONALFIBERLINEANDRETHREAD THROUGHSPOOL.MUTUBINGSPOOLANDTESTTO3000PSI.FINISHTERMINATINGBAKER&SILIXAFIBERLINESAND TEST–REVIEWSIGNALSTRENGTHTHROUGHTERMINATION.AFTERAPPROVALTOMOVEFORWARD,TERMINATESLB ELECTRICALFEEDTHROUGHANDTEST.BEGINN/U16Ͳ3/4”BOPE. 1/28/2023 3,4529.1 1INCIDENT,NOACCIDENTSORSPILLS.CONTINUEN/U16Ͳ3/4"BOPE,FLUSHSTACK,N/UKILL/CHOKEASSEMBLIES.SET WEARRING,FILLBOPWITHH2O&OBSERVEDLEAKONFLOWNIPPLEFLANGE,BLOWDOWNTOPDRIVE&TIGHTEN FLANGE. 1/29/2023 3,4529.1 NOACCIDENTS,INCIDENTSORSPILLS.CONTINUEFLUSHBOPSTACK&ALLLINES.PULLWEARRINGANDSETTESTPLUG, CHANGERAMSTO4"FIXEDBORERAMS.SHELLTESTANDTROUBLESHOOTLEAKONCHOKESIDEGRAYͲLOCHUB,BEGIN TESTING16Ͳ3/4"BOPE250PSILOW/3000PSIHIGH,TESTWITNESSWAIVEDBYAOGCCINSPECTORSTJOHN. 1/30/2023 3,4528.9 NOACCIDENTS,INCIDENTSORSPILLS.RIGDOWNFROMTESTINGBOP.PULLTESTPLUG&SETWEARRING.PUMPHOT WATERRINSETHROUGHALLLINES.M/U10Ͳ3/4"CASINGCLEANOUTBHA&RIHPICKINGUP4"DP.TAG10Ͳ3/4"X9Ͳ5/8" XͲOAT2670'.CIRCULATEWELLCLEANWITH8.8NaClBRINE.POOH&L/D10Ͳ3/4"CLEANOUTBHA.M/U9Ͳ5/8" CLEANOUTBHA&RIHTO9Ͳ5/8"CASING.WASHDOWNANDTAGPBTDAT3314'MD. 1/31/2023 3,4528.8 NOACCIDENTS,1INCIDENTAND1SPILL.POOHWITH9Ͳ5/8"CLEANOUTBHAFROM3314'TOCROSSOVER@2639'&RIH TO3310',PRESSURETEST10Ͳ3/4"X9Ͳ5/8"CASINGTO3000PSIFOR30MINSͲGOODTEST.DRAINPITSANDREPAIR LEAKINGSUCTIONLINEIN#4PIT.BUILDSPACERSANDTAKEONNaBr.BEGINFILTERINGSOLIDSOUTOFBRINE. 2/1/2023 3,4528.7 NOACCIDENTS,INCIDENTSORSPILLS.FILTER8.8PPGNaBrBRINEANDCHILLTO44°,POOH&L/D9Ͳ5/8"CLEANOUTBHA #2,R/UEͲLINE&RIHTO3265'WLM&POOHLOGGINGUPFROM3265'TO80'WLM.CHANGEOUTGYRO&DOWNLOAD VERTILOGDATA.P/U&RIHWITHNEWGYRO/VERTILOGONSLBEͲLINE. 2/2/2023 3,4528.7 NOACCIDENTS,INCIDENTSORSPILLS.RIHWITHGYRO/VERTILOGRUN#2UNABLETOGETPAST10Ͳ3/4"x9Ͳ5/8"XO (2673'WLM),LOGOUTOFHOLETOSURFACE.RIHWITHCEMENTBONDLOGONEͲLINE&LOGTOSURFACE.PULLWEAR RING&INSTALLTESTPLUG&R/UTOTESTBOPE'STO250/3000PSIͲTESTWITNESSWAIVEDBYAOGCCINSPECTORCOOK PULLTESTPLUG&SETWEARRING,R/USLBEͲLINEEQUIPMENTTORESUMELOGGINGOPERATIONS. 2/3/2023 3,4528.7 NOACCIDENTSORINCIDENTS,1SPILL.RIHWITHEͲLINEVERTILOG/GYRORUNTO3263'WLM.POOHLOGGINGTO SURFACE.STRAP&VERIFYALLLENGTHSONPERFORATINGBHA.RIHWITHTCPON4"DPTO2777',PUMPDPCLEANUP SOLVENTPILLS.REVERSECIRCOUTTOCUTTINGSBOX.CIRCULATETOCHILLWELLBOREBRINEWHILEWAITINGONEͲLINE UNIT. 2/4/2023 3,4528.7 NOACCIDENTS,INCIDENTSORSPILLS.WAITONEͲLINEUNITAVAILABILITY,CIRCULATE&CHILLINGBRINE,RIHWITH PACKER&TESTSET,UNSET&CONTINUERIH.R/USLBEͲLINEUNIT,RIHWITHGYRO/GAMMARAYTOCORRELATEGUNS INTOPOSITION. 2/5/2023 3,4528.7 NOACCIDENTS,INCIDENTSORSPILLS.CHANGEGYRO/GAMMARAYTOOL&RIHW/CORRELATIONRUN.ORIENTGUNS& SETPACKER.PERFORATECASING.REVERSECIRCULATETOCHECKFORGAS.RELEASETCPPACKER,CIRCULATE&CHILL BRINE.POOH,L/DBHA&PERFGUNSͲALLSHOTSFIRED.R/U&BEGINRUNNING5Ͳ1/2"COMPLETIONLINER. 2/6/2023 3,4528.7 NOACCIDENTS,INCIDENTSORSPILLS.RIH&SETPACKERAT2860',TESTPACKERTO1,000PSI,PRESSUREUPTOCLEAR BALLFROMSETTINGTOOL,CIRCULATETOCHILLBRINE,POOHL/D4"DRILLPIPE. 2/7/2023 3,4528.7 NOACCIDENTS,INCIDENTSORSPILLS.LOAD7"CASINGINTOPIPESHED,INSTALL7"FIXEDRAMS,CRANEIN&R/U3RD PARTYSPOOLERS&EQUIPTORIGFLOOR,R/U&BEGINTESTING16Ͳ3/4"BOPETO250PSILOW/3000PSIHIGH,TEST WITNESSEDBYAOGCCINSPECTORSULLIVAN 2/8/2023 3,4528.6 NOACCIDENTS,INCIDENTSORSPILLS.FINISHTESTINGBOPE.CRANEINSPOOLERS&EQUIPTORIGFLOOR.HELDPREͲJOB MEETINGWITHALLPARTIESONRUNNINGUPPERCOMPLETIONSTRING,CONTINUER/UCOMPLETIONHANDLINGTOOLS, SPOOLERS&EQUIP. 2/9/2023 3,4528.6 NOACCIDENTS,INCIDENTSORSPILLS.BEGINRUNNINGUPPERCOMPLETIONSTRING.P/UASSEMBLIES#1Ͳ#5,BAKER& AAISPLICINGLINES. 2/10/2023 3,4528.6 NOACCIDENTS,INCIDENTSORSPILLS.CONTINUERUNNINGUPPERCOMPLETIONSTRING.M/UASSEMBLY#6,BAKER& AAISPLICINGCONTROL&ELECTRICALLINES. 2/11/2023 3,4528.6 NOACCIDENTS,INCIDENTSORSPILLS.CONTINUERUNNINGUPPERCOMPLETIONSTRING.P/UASSEMBLIES#7Ͳ#12, BAKER&AAISPLICINGLINES.FAULTYCOMPONENTSONASSY#11,POOH&L/DASSY#11&#12. 2/12/2023 3,4528.7 NOACCIDENTS,INCIDENTS.1SPILL(INCONTAINMENT).MAKEUPASSEMBLY#11,PSITESTGOODBUTHADBAD ELECTRICALTEST,DISASSEMBLEACPINPREPFORNEWPARTARRIVAL,REPLACEMENTCOMPONENTENROUTETOSLOPE. CONTINUERIGGINGDOWNDRILLCOOLCHILLER#14. 2/13/2023 3,4528.7 NOACCIDENTS,INCIDENTSORSPILLS.SERVICERIGWHILEWAITINGONACPREPLACEMENTPARTS.ACPREPLACEMENT PARTSARRIVED,REPAIRASSY#11,P/UASSY#11Ͳ#13&RIHFROM440'TO790'.DISCOVEREDESPCABLEGROUNDED, POOHFROM790'TO710'TOLOCATEGROUND.AOGCCREPJIMREGGAPPROVEDCONTINUEDCOMPLETIONRUNNING WORKWITHOUTADDITIONALBOPETESTING. 2/14/2023 3,4528.7 NOACCIDENTS,INCIDENTSORSPILLS.POOHFROM710'TO421',INSPECTINGESP&ACPCABLE.FOUNDACPASSEMBLY TOBEBAD.CIRCULATEBOTTOMSUP.WAITONREPLACEMENTACPPARTS.PERFORMRIGSERVICE&HOUSEKEEPING. 2/15/2023 3,4528.7 NOACCIDENTS,INCIDENTSORSPILLS.PERFORMRIGMAINTENANCE&HOUSEKEEPING.CHANGEDOUT6Ͳ5/8"DERRICK FINGERSTO5".PULLDAMAGEDSECTIONOFESPCABLEOUT&DRESSNEWEND. 2/16/2023 3,4528.8 NOACCIDENTS,INCIDENTSORSPILLS.CONTINUETOPERFORMRIGHOUSEKEEPING&PREVENTATIVEMAINTENANCE. CONTINUECHANGINGOUTDERRICKFINGERSONMONKEYBOARD. 2/17/2023 3,4528.8 NOACCIDENTS,INCIDENTSORSPILLS.CONTINUETOPERFORMRIGHOUSEKEEPING&PREVENTATIVEMAINTENANCE. 2/18/2023 3,4528.8 NOACCIDENTS,INCIDENTSORSPILLS.CONTINUETOPERFORMRIGHOUSEKEEPING&PREVENTATIVEMAINTENANCE. 2/19/2023 3,4528.8 NOACCIDENTS,INCIDENTSORSPILLS.CONTINUETOPERFORMRIGHOUSEKEEPING&PREVENTATIVEMAINTENANCE. 2/20/2023 3,4528.8 NOACCIDENTS,INCIDENTSORSPILLS.ACPPARTSARRIVED,INSTALLNEWACPPARTS,P/U&RIHWITH7"UPPER COMPLETIONASSEMBLIES#11Ͳ#13,MAKINGSPLICES&PRESSURETESTINGLINESFROM460'TO713'. 2/21/2023 3,4528.8 NOACCIDENTS,INCIDENTSORSPILLS.P/U&RIHWITH7"UPPERCOMPLETIONASSEMBLIES#13Ͳ#14,MAKINGSPLICES& PRESSURETESTINGLINESFROM713'TO2048'. 2/22/2023 3,4528.8 NOACCIDENTS,INCIDENTSORSPILLS.P/U&RIHWITH7"UPPERCOMPLETIONASSEMBLY#15,MAKINGSPLICES& PRESSURETESTINGLINESFROM2048'TO2883'.M/UHANGERASSEMBLY&ORIENT.MAKETERMINATIONSATHANGER FORCONTROLLINES&FEEDTHROUGHTUBINGHANGER. 2/23/2023 3,4528.8 1SPILL,NOACCIDENTSORINCIDENTS.COMPLETETERMINATIONSATHANGER&PRESSUREPENETRATIONSATHANGER. LANDHANGER.PRESSURETESTHANGERSEAL&ORBITVALVES.BEGINN/D16Ͳ3/4"BOPE.R/D&REMOVE3RDPARTY EQUIPFROMRIGFLOOR. 2/24/2023 3,4528.8 1INCIDENT,NOACCIDENTSORSPILLS.N/D16Ͳ3/4"BOPE.SETTREETESTPLUG,N/UWELLHEADADAPTERSPOOL. 2/25/2023 3,4528.8 1INCIDENT&1SPILL.NOACCIDENTS.FINISHTERMINATINGLINESATADAPTERSPOOL.N/U&TESTDRYHOLETREE. DISPLACEWELLTO9.4PPGNACL.SETTESTPLUGAT2711'ONSLICKLINE.PRESSURETESTEDANNULUS. 2/26/2023 3,4528.8 NOACCIDENTS,INCIDENTSORSPILLS.TESTEDTUBINGͲGOOD.RIHWITHGRTOOL&RETRIEVESTANDINGVALVE,TESTED ORBITVALVEͲGOOD.RIHWITH4.5"SLIDINGSLEEVETOOL.RIHWITH7"SLIDINGSLEEVETOOL.RIHWITHESP ASSEMBLIES#1Ͳ#3.DISPLACEWELLWITHCORROSIONINHIBITEDBRINE.DISPLACETUBING&ANNULUSWITH SAFETHERM. 2/27/2023 3,4528.8 NOACCIDENTS,INCIDENTSORSPILLS.RIHWITHESPASSEMBLIES#3&#4.TESTPACKOFFͲGOOD.ACCESSESPTESTED ELECTRICALLINESͲGOOD.R/DHESSLICKLINE.N/UPRODUCTIONTREE&SWABVALVE&TESTͲGOOD.REMOVE3RD PARTYEQUIPFROMRIGFLOOR&PIPESHED.LOADOUTDRILLCOOLEQUIP. 2/28/2023 3,4528.8 NOACCIDENTS,INCIDENTSORSPILLS.LOADOUTREMAININGSUPPORTEQUIPMENT.BREAKDOWNCONTAINMENTS. PREPARERIGFORRIGMOVE.ROADRIGTOENTRANCEOFWͲPAD.RIGRELEASEDTOHILCORP. CONFIDENTIAL TD Shoe Depth: PBTD: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type: Arctic Cem Yield (Ft3/sack): Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm): Tail Slurry Type: Tuned Light Yield (Ft3/sack): Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Water Density (ppg) 8.6 Rate (bpm): 1 Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: Plug Bumped?X Yes No Casing Rotated? Yes x No Reciprocated? Yes x No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type: Yield (Ft3/sack): Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm): Tail Slurry Type: Yield (Ft3/sack): Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No % Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: CEMENTING REPORT - SURFACE Visual - 114 bbl cement returns to surface (Inner String Cement Job) 11 893 bbl 5 881 100% 580 rig 114bblcementtosurface Drilling Mud 9.5 6 FI R S T S T A G E SE C O N D S T A G E 10MudPush Spacer 75 12.5 287 bbl 5 16:21 1/10/2023 surface 63.3/63.3 2.55 Bump press 1.75 10 Remarks: ASRC Consulting & Environmental Services (ACES) CASING & CEMENTING REPORT Well No./ PTD # Hydrate-P1 / PTD 222-141 Date 10-Jan-23 VICCasing 16x14 166.5 L80 VAMTop 2,199.00 2,199.00 0.00 CASING RECORD - Surface Casing County Alaska State Alaska Supv. M. Martyn 2215' MD / 2171' TVD 2199' MD / 2155' TVD N/A Casing (Or Liner) Detail Setting Depths Size Wt. Grade THD Make Length Bottom Top CONFIDENTIAL CONFIDENTIAL TD Shoe Depth: PBTD: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type: Arctic Cem Yield (Ft3/sack): Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm): Tail Slurry Type: Tuned Light Yield (Ft3/sack): Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: N/A Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: Plug Bumped?X Yes No Casing Rotated? Yes x No Reciprocated? Yes x No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type: Yield (Ft3/sack): Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm): Tail Slurry Type: Yield (Ft3/sack): Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No % Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: County Alaska State Alaska Supv. D. Hammons ASRC Consulting & Environmental Services (ACES) CASING & CEMENTING REPORT Well No./ PTD # Hydrate-P1 / PTD 222-141 Date 24-Jan-23 CEMENTING REPORT - PRODUCTION FI R S T S T A G E MudPush Spacer 10 65 2.87 10.7 228 bbl 5 1.75 12.5 145 bbl 5 Brine 9 6 295/295 SE C O N D S T A G E 700 cement Bump press 1350 100% 174bblcementtosurface 8:01 1/24/2023 surface Visual - 174 bbl cement returns to surface Grade THD Make Length Bottom Top CASING RECORD - Production Casing 3452' MD / 3379' TVD 3443' MD / 3370' TVD 3314' MD tag Casing (Or Liner) Detail Setting Depths Size Wt. Remarks: 3,443.00 2,670.00 2,670.00 2,670.00 0.00 9Ͳ5/8 47 L80 VAMTop 773.00 10Ͳ3/4 55.5 L80 VAMTop CONFIDENTIAL Hy d r a t e - P 1 S u r v e y G e o d e t i c R e p o r t (D e f S u r v e y ) 2. 1 0 . 8 3 3 . 1 Co m m e n t s MD (f t ) In c l (° ) Az i m T r u e (° ) TV D S S (f t ) TV D (f t ) VS E C (f t ) NS (f t ) EW (f t ) TF (° ) DL S (° / 1 0 0 f t ) Di r e c t i o n a l Di f f i c u l t y I n d e x Ex c l u s i o n Z o n e Al e r t Ex c l u s i o n Z o n e An g l e (° ) Ge o M a g T h (n T ) No r t h i n g (f t U S ) Ea s t i n g (f t U S ) La t i t u d e (N / S ° ' " ) Lo n g i t u d e (E / W ° ' " ) RT E 0. 0 0 0. 0 0 0. 0 0 -8 2 . 6 5 0. 0 0 0. 0 0 0. 0 0 0. 0 0 0M N/ A 0. 0 0 9. 3 3 92 7 2 . 9 3 59 6 6 1 7 9 . 4 8 59 8 6 7 3 . 2 1 N 7 0 1 9 1 . 4 1 W 1 4 9 1 2 0 . 6 3 Ma r k e r M u d L i n e 30 . 6 5 0 . 0 0 0 . 0 0 - 5 2 . 0 0 3 0 . 6 5 0 . 0 0 0 . 0 0 0 . 0 0 2 0 8 . 3 6 M 0 . 0 0 0 . 0 0 9 . 3 3 9 2 7 2 . 9 9 5 9 6 6 1 7 9 . 4 8 5 9 8 6 7 3 . 2 1 N 7 0 1 9 1 . 4 1 W 1 4 9 1 2 0 . 6 3 19 4 . 3 5 0. 2 6 20 8 . 3 6 11 1 . 7 0 19 4 . 3 5 -0 . 2 9 -0 . 3 3 -0 . 1 8 25 4 . 4 6 M 0. 1 6 0. 0 0 9. 5 9 95 2 2 . 5 4 59 6 6 1 7 9 . 1 5 59 8 6 7 3 . 0 4 N 7 0 1 9 1 . 4 1 W 1 4 9 1 2 0 . 6 3 22 5 . 7 9 0. 1 7 25 4 . 4 6 14 3 . 1 4 22 5 . 7 9 -0 . 3 9 -0 . 4 0 -0 . 2 6 25 1 . 5 1 M 0. 6 0 0. 0 0 9. 4 2 93 5 9 . 5 3 59 6 6 1 7 9 . 0 7 59 8 6 7 2 . 9 6 N 7 0 1 9 1 . 4 1 W 1 4 9 1 2 0 . 6 4 26 5 . 4 5 0. 0 9 25 1 . 5 1 18 2 . 8 0 26 5 . 4 5 -0 . 4 8 -0 . 4 3 -0 . 3 4 33 1 . 2 M 0. 2 0 0. 0 0 9. 3 8 93 2 2 . 6 4 59 6 6 1 7 9 . 0 5 59 8 6 7 2 . 8 7 N 7 0 1 9 1 . 4 1 W 1 4 9 1 2 0 . 6 4 32 6 . 7 3 0. 1 5 33 1 . 2 0 24 4 . 0 8 32 6 . 7 3 -0 . 5 4 -0 . 3 7 -0 . 4 3 43 . 6 1 M 0. 2 6 0. 0 0 9. 2 2 91 6 7 . 4 7 59 6 6 1 7 9 . 1 0 59 8 6 7 2 . 7 9 N 7 0 1 9 1 . 4 1 W 1 4 9 1 2 0 . 6 4 38 2 . 0 9 1. 3 9 43 . 6 1 29 9 . 4 3 38 2 . 0 8 0. 0 7 0. 1 8 0. 0 0 47 . 7 M 2. 4 4 0. 4 5 8. 1 4 80 9 6 . 6 1 59 6 6 1 7 9 . 6 6 59 8 6 7 3 . 2 1 N 7 0 1 9 1 . 4 1 W 1 4 9 1 2 0 . 6 3 41 2 . 8 4 2. 1 5 47 . 7 0 33 0 . 1 7 41 2 . 8 2 0. 9 6 0. 8 4 0. 6 9 58 . 6 M 2. 5 0 0. 8 2 7. 6 1 75 7 5 . 1 1 59 6 6 1 8 0 . 3 2 59 8 6 7 3 . 8 9 N 7 0 1 9 1 . 4 2 W 1 4 9 1 2 0 . 6 1 50 6 . 0 3 2. 7 4 58 . 6 0 42 3 . 2 7 50 5 . 9 2 4. 8 2 3. 1 7 3. 8 8 73 . 2 1 M 0. 8 0 1. 3 5 7. 5 9 75 4 9 . 3 8 59 6 6 1 8 2 . 7 0 59 8 6 7 7 . 0 5 N 7 0 1 9 1 . 4 4 W 1 4 9 1 2 0 . 5 2 59 7 . 5 8 4. 8 2 73 . 2 1 51 4 . 6 2 59 7 . 2 7 10 . 8 1 5. 4 2 9. 4 3 69 . 8 9 M 2. 4 9 1. 8 6 7. 9 2 78 8 4 . 8 1 59 6 6 1 8 5 . 0 3 59 8 6 8 2 . 5 7 N 7 0 1 9 1 . 4 6 W 1 4 9 1 2 0 . 3 5 68 8 . 4 4 7. 3 3 69 . 8 9 60 4 . 9 6 68 7 . 6 1 20 . 3 9 8. 5 2 18 . 5 3 70 . 9 2 M 2. 7 9 2. 2 6 7. 8 6 78 2 4 . 8 9 59 6 6 1 8 8 . 2 4 59 8 6 9 1 . 6 2 N 7 0 1 9 1 . 4 9 W 1 4 9 1 2 0 . 0 9 78 5 . 1 1 9. 6 5 70 . 9 2 70 0 . 5 7 78 3 . 2 2 34 . 6 3 13 . 2 9 31 . 9 8 3. 1 9 R 2. 4 0 2. 5 9 8. 8 7 88 2 2 . 9 9 59 6 6 1 9 3 . 1 9 59 8 7 0 5 . 0 1 N 7 0 1 9 1 . 5 4 W 1 4 9 1 1 5 9 . 7 0 87 8 . 1 8 11 . 2 2 71 . 3 7 79 2 . 1 0 87 4 . 7 5 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2 59 9 1 1 9 . 3 4 N 7 0 1 9 3 . 7 2 W 1 4 9 1 1 4 7 . 5 2 To p B 29 1 1 . 0 6 12 . 0 1 62 . 1 3 27 6 8 . 3 5 28 5 1 . 0 0 52 3 . 2 7 24 3 . 0 3 46 4 . 9 7 98 . 6 3 L 0. 6 3 4. 3 0 8. 8 4 87 9 3 . 2 5 59 6 6 4 2 8 . 5 8 59 9 1 3 4 . 9 0 N 7 0 1 9 3 . 8 0 W 1 4 9 1 1 4 7 . 0 6 29 2 1 . 0 8 12 . 0 0 61 . 8 3 27 7 8 . 1 5 28 6 0 . 8 0 52 5 . 3 5 24 4 . 0 1 46 6 . 8 1 9. 9 5 L 0. 6 3 4. 3 1 8. 7 9 87 3 9 . 6 6 59 6 6 4 2 9 . 5 8 59 9 1 3 6 . 7 3 N 7 0 1 9 3 . 8 1 W 1 4 9 1 1 4 7 . 0 1 30 1 3 . 8 0 12 . 6 1 61 . 3 4 28 6 8 . 7 4 29 5 1 . 3 9 54 5 . 0 4 25 3 . 4 1 48 4 . 1 9 11 3 . 6 R 0. 6 7 4. 3 3 9. 1 1 90 5 4 . 0 6 59 6 6 4 3 9 . 2 1 59 9 1 5 3 . 9 8 N 7 0 1 9 3 . 9 0 W 1 4 9 1 1 4 6 . 5 0 31 0 6 . 7 0 12 . 5 5 61 . 9 8 29 5 9 . 4 1 30 4 2 . 0 6 56 5 . 2 0 26 3 . 0 2 50 2 . 0 0 90 . 0 9 R 0. 1 6 4. 3 5 9. 1 7 91 1 6 . 6 8 59 6 6 4 4 9 . 0 5 59 9 1 7 1 . 6 6 N 7 0 1 9 4 . 0 0 W 1 4 9 1 1 4 5 . 9 8 32 0 1 . 6 6 12 . 5 6 64 . 4 0 30 5 2 . 1 0 31 3 4 . 7 5 58 5 . 8 0 27 2 . 3 3 52 0 . 4 2 11 5 . 2 2 R 0. 5 5 4. 3 7 9. 5 7 95 0 8 . 3 2 59 6 6 4 5 8 . 6 0 59 9 1 8 9 . 9 5 N 7 0 1 9 4 . 0 9 W 1 4 9 1 1 4 5 . 4 4 32 9 3 . 7 3 12 . 3 4 66 . 6 8 31 4 2 . 0 1 32 2 4 . 6 6 60 5 . 6 4 28 0 . 5 5 53 8 . 4 8 40 . 6 2 L 0. 5 8 4. 3 9 9. 7 9 97 2 4 . 4 8 59 6 6 4 6 7 . 0 5 59 9 2 0 7 . 9 1 N 7 0 1 9 4 . 1 7 W 1 4 9 1 1 4 4 . 9 2 33 9 2 . 9 1 12 . 3 7 66 . 5 6 32 3 8 . 8 9 33 2 1 . 5 4 62 6 . 8 6 28 8 . 9 7 55 7 . 9 6 HS 0. 0 4 4. 4 0 9. 7 9 97 2 5 . 3 0 59 6 6 4 7 5 . 7 3 59 9 2 2 7 . 2 7 N 7 0 1 9 4 . 2 5 W 1 4 9 1 1 4 4 . 3 5 TD 34 5 2 . 0 0 12 . 3 7 66 . 5 6 32 9 6 . 6 1 33 7 9 . 2 6 63 9 . 5 2 29 4 . 0 0 56 9 . 5 7 0. 0 0 4. 4 1 9. 7 9 97 2 5 . 3 8 59 6 6 4 8 0 . 9 2 59 9 2 3 8 . 8 2 N 7 0 1 9 4 . 3 0 W 1 4 9 1 1 4 4 . 0 1 We l l H e a d Lo c a l C o o r d R e f e r e n c e d T o : 14 . 9 9 0 ° Ma g n e t i c D e c l i n a t i o n : De c l i n a t i o n D a t e : 0. 9 9 9 9 1 1 0 6 Ma g n e t i c D e c l i n a t i o n M o d e l : N 7 0 ° 1 9 ' 1 . 4 1 1 1 8 " , W 1 4 9 ° 1 2 ' 0 . 6 2 8 7 8 " To r t / A H D / D D I / E R D R a t i o : CR S G r i d C o n v e r g e n c e A n g l e : Ja n u a r y 2 3 , 2 0 2 3 Lo c a t i o n L a t / L o n g : 0. 7 5 3 1 ° N 5 9 6 6 1 7 9 . 4 8 0 f t U S , E 5 9 8 6 7 3 . 2 1 0 f t U S UW I / A P I # : Hy d r a t e - P 1 St r u c t u r e / S l o t : We l l : Bo r e h o l e : 50 0 2 9 2 3 7 3 7 0 0 0 0 Hy d r a t e - P 1 Ku p a r u k S t a t e 0 7 - 1 1 - 1 2 P a d / H y d r a t e P 1 Lo c a t i o n G r i d N / E Y / X : NA D 2 7 A l a s k a S t a t e P l a n e , Z o n e 0 4 , U S F e e t 39 . 2 4 6 ° / 6 4 3 . 7 7 9 f t / 4 . 4 1 2 / 0 . 1 9 1 Co o r d i n a t e R e f e r e n c e S y s t e m : Su r v e y N a m e : Hy d r a t e - P 1 Su r v e y D a t e : 82 . 6 5 0 f t a b o v e M S L TV D R e f e r e n c e E l e v a t i o n : Se a b e d / G r o u n d E l e v a t i o n : 52 . 0 0 0 f t a b o v e M S L Fi e l d : Re p o r t D a t e : Pr u d h o e B a y U n i t - W O A Cl i e n t : JO G M E C Ja n u a r y 2 3 , 2 0 2 3 - 1 1 : 0 2 A M Mi n i m u m C u r v a t u r e / L u b i n s k i 66 . 5 6 0 ° ( T r u e N o r t h ) 0. 0 0 0 f t , 0 . 0 0 0 f t Ro t a r y T a b l e Su r v e y / D L S C o m p u t a t i o n : TV D R e f e r e n c e D a t u m : Ve r t i c a l S e c t i o n A z i m u t h : Ve r t i c a l S e c t i o n O r i g i n : To t a l G r a v i t y F i e l d S t r e n g t h : 10 0 1 . 9 9 9 9 m g n ( 9 . 8 0 6 6 5 B a s e d ) To t a l C o r r M a g N o r t h - > T r u e N o r t h : Gr a v i t y M o d e l : 57 1 8 6 . 8 8 1 n T DO X To t a l M a g n e t i c F i e l d S t r e n g t h : Ma g n e t i c D i p A n g l e : No r t h R e f e r e n c e : 80 . 6 6 8 ° De c e m b e r 2 0 , 2 0 2 2 BG G M 2 0 2 2 Tr u e N o r t h 0. 0 0 0 0 ° 14 . 9 9 0 2 ° Gr i d C o n v e r g e n c e U s e d : Gr i d S c a l e F a c t o r : Ve r s i o n / P a t c h : Dr i l l i n g O f f i c e 2 . 1 0 . 8 3 3 . 1 P r u d h o e B a y U n i t - W O A \ K u p a r u k S t a t e 0 7 - 1 1 - 1 2 P a d \ H y d r a t e - P 1 \ H y d r a t e - P 1 \ H y d r a t e - P 1 # S L B - P r i v a t e 1/ 2 3 / 2 0 2 3 1 1 : 2 8 A M P a g e 1 o f 2 Co m m e n t s MD (f t ) In c l (° ) Az i m T r u e (° ) TV D S S (f t ) TV D (f t ) VS E C (f t ) NS (f t ) EW (f t ) TF (° ) DL S (° / 1 0 0 f t ) Di r e c t i o n a l Di f f i c u l t y I n d e x Ex c l u s i o n Z o n e Al e r t Ex c l u s i o n Z o n e An g l e (° ) Ge o M a g T h (n T ) No r t h i n g (f t U S ) Ea s t i n g (f t U S ) La t i t u d e (N / S ° ' " ) Lo n g i t u d e (E / W ° ' " ) Pa r t MD F r o m ( f t ) MD T o ( f t ) EO U F r e q ( f t ) Ho l e S i z e (i n ) Ca s i n g D i a m e t e r (i n ) 1 0. 0 0 0 30 . 6 5 0 1/ 9 8 . 4 2 5 30 . 0 0 0 30 . 0 0 0 1 30 . 6 5 0 30 . 6 5 0 Ac t S t n s 30 . 0 0 0 30 . 0 0 0 1 30 . 6 5 0 78 5 . 1 1 0 Ac t S t n s 30 . 0 0 0 30 . 0 0 0 1 78 5 . 1 1 0 21 6 9 . 7 4 0 Ac t S t n s 30 . 0 0 0 30 . 0 0 0 1 2 1 6 9 . 7 4 0 3 3 9 2 . 9 1 0 A c t S t n s 3 0 . 0 0 0 3 0 . 0 0 0 1 33 9 2 . 9 1 0 34 5 2 . 0 0 0 Ac t S t n s 30 . 0 0 0 30 . 0 0 0 MD F r o m ( f t ) MD T o ( f t ) Gr i d Co n v e r g e n c e ( d e g ) De c l i n a t i o n ( d e g ) Di p A n g l e ( d e g ) Fi e l d S t r e n g t h ( n T ) Ge o m a g M o d e l G e o m a g D a t e G r a v i t y M o d e l Gr a v i t y ( m g n ( 9 . 8 0 6 6 5 Ba s e d ) ) Gr i d S c a l e F a c t o r 0. 0 0 0 34 5 2 . 0 0 0 0. 0 0 0 14 . 9 9 0 80 . 6 6 8 57 1 8 6 . 8 8 1 BG G M 2 0 2 2 De c - 2 0 2 2 1 5 : 0 7 : 4 1 DO X 10 0 2 . 0 0 0 0. 9 9 9 9 1 1 0 6 0 To p B 10 7 3 F S L 3 4 1 7 F E L 7 T 1 1 N R 1 2 E U M 59 6 6 4 2 8 . 5 8 0 5 9 9 1 3 4 . 9 0 0 Su r v e y T y p e : De f S u r v e y Su r v e y E r r o r M o d e l : IS C W S A R e v 3 * * * 3 - D 9 5 . 0 0 0 % C o n f i d e n c e 2 . 7 9 5 5 s i g m a Su r v e y P r o g r a m : GY D _ G W D 7 0 - D e p t h O n l y H y d r a t e - P 1 / H y d r a t e - P 1 GY D _ G W D 7 0 H y d r a t e - P 1 / H y d r a t e - P 1 De s c r i p t i o n Su r v e y T o o l T y p e B o r e h o l e / S u r v e y GY D _ G W D 7 0 - D e p t h O n l y H y d r a t e - P 1 / H y d r a t e - P 1 Hy d r a t e - P 1 / H y d r a t e - P 1 Le g a l D e s c r i p t i o n : No r t h i n g ( Y ) Ea s t i n g ( X ) GY D _ G W D 7 0 + S A G H y d r a t e - P 1 / H y d r a t e - P 1 A0 1 3 M b _ M W D + I F R 2 + S A G + M S H y d r a t e - P 1 / H y d r a t e - P 1 Su r f a c e : 82 9 . 6 F S L 3 8 8 2 . 7 F E L S 7 T 1 1 N R 1 2 E U M 59 6 6 1 7 9 . 4 8 0 59 8 6 7 3 . 2 1 0 BH L : 11 2 3 F S L 3 3 1 2 F E L 7 T 1 1 N R 1 2 E U M 59 6 6 4 8 0 . 9 2 0 59 9 2 3 8 . 8 2 0 A0 2 6 U a _ B L I N D Dr i l l i n g O f f i c e 2 . 1 0 . 8 3 3 . 1 P r u d h o e B a y U n i t - W O A \ K u p a r u k S t a t e 0 7 - 1 1 - 1 2 P a d \ H y d r a t e - P 1 \ H y d r a t e - P 1 \ H y d r a t e - P 1 # S L B - P r i v a t e 1/ 2 3 / 2 0 2 3 1 1 : 2 8 A M P a g e 2 o f 2 S T A T E O F ALA S K A 49 TH Pierre M. Stragier NO. LS-9812 10/11/2022 Da t a F r o m : L o g D a t e : D e s c r i p t i o n Bo t t o m L o g In t e r v a l ( f e e t ) To p L o g In t e r v a l ( f e e t ) LW D r e a l t i m e S u r f a c e H o l e : G R 2 , 1 5 0 ' 2 0 0 ' LW D r e a l t i m e Pr o d u c t i o n Ho l e : Re s i s t i v i t y , GR , De n s i t y / N e u t r o n , So n i c , NM R 3, 4 0 0 ' 2 , 2 0 0 ' Hy d r a t e - P 1 , A P I # 5 0 - 0 2 9 - 2 3 7 3 7 - 0 0 - 0 0 Lo g s L i s t CO N F I D E N T I A L Name Measured Depth TVD Permafrost base 2,002' 1,964' D Unit Top 2,408' 2,359' B Unit Top 2,911' 2,851' Name Measured Depth TVD None Name Measured Depth TVD None Abnormal Pressure Zones Geologic Markers CONFIDENTIAL Oil and Gas Shows Hydrate-P1, API# 50-029-23737-00-00 ❙CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Quick, Michael To:Brooks, James S (OGC) Subject:RE: 10-407 Completion Report for Hydrate-P1, PTD 222-141 Date:Wednesday, April 5, 2023 9:37:01 AM Hi James – Yes, it appears that we started with a form template with the elevations as submitted for the first well, not the changed elevations that were requested for the second well. The revised elevations are: KB: 84.5’ GL: 52.0’ Thanks, Mike From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Friday, March 31, 2023 8:55 AM To: Quick, Michael <mquick@asrcenergy.com> Subject: FW: 10-407 Completion Report for Hydrate-P1, PTD 222-141 Hi, Can you look at the values in box 9 ? I believe that the KB should be higher than the value for the GL. thanx From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Wednesday, March 22, 2023 9:41 AM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: FW: 10-407 Completion Report for Hydrate-P1, PTD 222-141 Forwarding From: Quick, Michael <mquick@asrcenergy.com> Sent: Wednesday, March 22, 2023 8:08 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> 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. You don't often get email from mquick@asrcenergy.com. Learn why this is important Cc: Dial, Amanda <ADial@asrcenergy.com> Subject: 10-407 Completion Report for Hydrate-P1, PTD 222-141 Hello – Attached please find the 10-407 well completion report package for the third ASRC methane hydrate well, Hydrate-P1, PTD 222-141. Please let me know if you have any questions. Thanks, Mike Michael Quick, PE Drilling Engineer / Sr. Petroleum Engineer ASRC Energy Services Alaska, Inc. 3900 C Street, Suite 701 Anchorage, AK 99503 Cell: 907-317-2969 One Crew, One Journey Honoring the values of our founders as we develop the future. 1 Regg, James B (OGC) From:Isaacson, William <wisaacson@asrcenergy.com> Sent:Monday, February 20, 2023 7:44 PM To:Regg, James B (OGC) Cc:DOA AOGCC Prudhoe Bay; ACES Company Man; Dial, Amanda Subject:RE: Hydrate-P1 Weekly BOP Test - PTD #222-141 Hello Jim, We finally received the equipment we were waiting on for our ESP downhole electrical connection and are back to running our completion. Our current timeline has us starting to nipple down the BOP equipment late Wednesday the 22nd to early Thursday the 23 rd. Thank you, and please let me know if I can answer any questions. Regards, Bill Isaacson Drilling Engineer ASRC Energy Services Alaska, Inc. 3900 C Street, Suite 701 Anchorage, AK 99503 Direct: 907-339-6455 | Cell: 907-242-7483 One Crew, One Journey Honoring the values of our founders as we develop the future. From:Isaacson, William Sent:Tuesday, February 14, 2023 3:14 PM To:Regg, James B (OGC) <jim.regg@alaska.gov> Cc:DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject:RE: Hydrate P1 Weekly BOP Test PTD #222 141 Thank you Jim. Unfortunately we have experienced another failure on our ESP electrical cable connection point and are waiting on additional parts from Houston. This delay will add at least another 2 days to my timeline outlined below, with the possibility of a longer delay. We have about 420of our ~3000completion assembly run and are monitoring the well and circulating periodically to ensure all is stable. I will keep you updated once our timeline becomes more clear. Thank you, and please let me know if you need any further information. Bill Isaacson Drilling Engineer ASRC Energy Services Alaska, Inc. 3900 C Street, Suite 701 Anchorage, AK 99503 Direct: 907-339-6455 | Cell: 907-242-7483 One Crew, One Journey Honoring the values of our founders as we develop the future. Some people who received this message don't often get email from wisaacson@asrcenergy.com. Learn why this is important 2 From:Regg, James B (OGC) <jim.regg@alaska.gov> Sent:Tuesday, February 14, 2023 11:08 AM To:Isaacson, William <wisaacson@asrcenergy.com> Cc:DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject:RE: Hydrate P1 Weekly BOP Test PTD #222 141 AOGCC waives the requirement to test BOPE due Wednesday so you can complete running the completion. If pulling the completion to surface becomes necessary, a BOPE test would be required prior to the next entry in Hydrate P1. Jim Regg Supervisor, Inspections AOGCC 333 W. 7 th Ave, Suite 100 Anchorage, AK 99501 907 793 1236 From:Isaacson, William <wisaacson@asrcenergy.com> Sent:Monday, February 13, 2023 1:44 PM To:Regg, James B (OGC) <jim.regg@alaska.gov> Subject:Hydrate P1 Weekly BOP Test PTD #222 141 Jim, As per our conversation this morning, we are currently running our completion on the Hydrate P1 well and are due for a weekly BOP test this coming Wednesday. The completion includes a total of seven power cables and control lines, which make it unfeasible to stop and perform a BOP test. Our last test was performed immediately prior to final rig up of completion running equipment and our forecast had us landing our completion assembly and rigging down the BOP within our 7 day window. Unfortunately we had an issue with both the primary and back up electrical connections for the ESP assembly, which set us back approximately two days. We are back on productive time as of this morning and are forecasting to start rigging down the BOP sometime late Wednesday. Although our forecast has us starting to remove the BOP within our 7 day window, we wanted make you aware of this issue and start an early conversation around the possibility of requesting a waiver for our upcoming BOP test. Thanks again for the conversation this morning and consideration of this request for a waiver. Please let me know if you require any further information. Regards, CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from wisaacson@asrcenergy.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. 3 Bill Isaacson Drilling Engineer ASRC Energy Services Alaska, Inc. 3900 C Street, Suite 701 Anchorage, AK 99503 Direct: 907-339-6455 | Cell: 907-242-7483 One Crew, One Journey Honoring the values of our founders as we develop the future. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________HYDRATE P1 JBR 03/31/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Tested with 7" test joint. FP on Test #7 choke ln valve. leaking double stud adapter, tighten and retest good Test Results TEST DATA Rig Rep:Robert BorgenOperator:ASRC Consulting & Environmental Servic Operator Rep:McGeehan Rig Owner/Rig No.:Nordic 3 PTD#:2221410 DATE:2/8/2023 Type Operation:EXPL Annular: 250/3000Type Test:WKLY Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopSTS230207192818 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6 MASP: 1241 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 13 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 16 3/4"P #1 Rams 1 7"P #2 Rams 1 blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"FP HCR Valves 2 3 1/8"P Kill Line Valves 1 3 1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P2900 Pressure After Closure P1250 200 PSI Attained P46 Full Pressure Attained P239 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P4@1950 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P24 #1 Rams P10 #2 Rams P10 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9999 9 9 9 FP FP on Test #7 choke ln valve. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:3 DATE:2/2/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #222-1410 Sundry # Operation:Drilling:Workover:Explor.:XXX Test:Initial:Weekly:XXX Bi-Weekly:Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:1241 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 16 3/4"P Pit Level Indicators P P #1 Rams 1 4"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)2950 P Kill Line Valves 1 3 1/8"P Pressure After Closure (psi)1350 P Check Valve 0 NA 200 psi Attained (sec)46 P BOP Misc 0 NA Full Pressure Attained (sec)175 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 x 2000psi P No. Valves 13 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 24 P #1 Rams 10 P Coiled Tubing Only:#2 Rams 10 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:7.5 HCR Choke 2 P Repair or replacement of equipment will be made within 0 days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2-1-23/6:29PM Waived By Test Start Date/Time:2/2/2023 13:30 (date)(time)Witness Test Finish Date/Time:2/2/2023 21:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nordic 85 Henry/Borgen AES Martyn/Mcgeehan Hydrate-P1 Test Pressure (psi): gmanager.rig3@nordic-calista.com CESCompanyMan@asrcenergy.co Form 10-424 (Revised 08/2022)2023-0202_BOP_Nordic3_Hydrate-P1        J. Regg; 6/2/2023 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:3 DATE:1/29/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2221410 Sundry # Operation:Drilling:Workover:Explor.:XXX Test:Initial:Weekly:XXX Bi-Weekly:Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:1241 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 16 3/4"P Pit Level Indicators P P #1 Rams 1 4"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)2950 P Kill Line Valves 1 3 1/8"P Pressure After Closure (psi)1200 P Check Valve 0 NA 200 psi Attained (sec)24 P BOP Misc 0 NA Full Pressure Attained (sec)207 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 x 2000psi P No. Valves 13 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 24 P #1 Rams 10 P Coiled Tubing Only:#2 Rams 10 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:9.5 HCR Choke 2 P Repair or replacement of equipment will be made within 0 days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1-25-23/02:34 Waived By Test Start Date/Time:1/29/2023 14:30 (date)(time)Witness Test Finish Date/Time:1/29/2023 23:45 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Nordic Test with 4" test joint, surface testing equipment leak on test #4, fix leak & retest high pressure to 3000psi Henry/Bondietti AES Martyn/Wall Hydrate-P1 Test Pressure (psi): gmanager.rig3@nordic-calista.com CESCompanyMan@asrcenergy.co Form 10-424 (Revised 08/2022)2023-0129_BOP_Nordic3_Hydrate-P1          J. Regg; 6/1/2023 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:3 DATE:1/20/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2221410 Sundry # Operation:Drilling:Workover:Explor.:XXXX Test:Initial:Weekly:XXXX Bi-Weekly:Other: Rams:250/3000 Annular:250/2500 Valves:250/3000 MASP:1241 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 16 3/4"FP Pit Level Indicators P P #1 Rams 1 10 3/4"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)3000 P Kill Line Valves 1 3 1/8"FP Pressure After Closure (psi)1300 P Check Valve 0 NA 200 psi Attained (sec)43 P BOP Misc 1 3"P Full Pressure Attained (sec)233 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 @ 2000 P No. Valves 13 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 20 P #1 Rams 8 P Coiled Tubing Only:#2 Rams 8 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:2 Test Time:8.0 HCR Choke 2 P Repair or replacement of equipment will be made within 0 days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1-19-23/5:01 Waived By Test Start Date/Time:1/20/2023 4:00 (date)(time)Witness Test Finish Date/Time:1/20/2023 12:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nordic Test with 10 3/4" test joint,250/3000psi 250/2500psi Annular,Manual kill valve fail greased cycle valve retest pass,Leak on10 3/4" casing swedge on annular test,removed swedge re dope make up re test pass Hansen/Bondietti AES Hammons/Wall Hydrate-P1 Test Pressure (psi): gmanager.rig3@nordic-calista.com CESCompanyMan@asrcenergy.co Form 10-424 (Revised 08/2022)2023-0120_BOP_Nordic3_Hydrate-P1          J. Regg; 5/31/2023 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________HYDRATE P1 JBR 02/21/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Tested with 6 5/8" test joint, test number 4 - test joint to pump in sub connection leaking, tighten and retest good. Between test 4 and 5 closed rams while shut in and shot pressure up to 750 psi bleed off pressure and start test 5. Test Results TEST DATA Rig Rep:Shane McgeehanOperator:ASRC Consulting & Environmental Servic Operator Rep:Robert Borgen Rig Owner/Rig No.:Nordic 3 PTD#:2221410 DATE:1/14/2023 Type Operation:EXPL Annular: 250/2500Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopSTS230113164907 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 8.5 MASP: 1241 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 13 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 16 3/4"P #1 Rams 1 6 5/8"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"P Kill Line Valves 1 3 1/8"P Check Valve 0 NA BOP Misc 1 3" demco P System Pressure P2900 Pressure After Closure P1250 200 PSI Attained P27 Full Pressure Attained P208 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2000 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P24 #1 Rams P7 #2 Rams P8 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P2      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:Isaacson, William Cc:Dial, Amanda; Quick, Michael Subject:RE: Casing Pressure Test Value - PTD 222-125 and 222-141 Date:Thursday, December 8, 2022 3:54:00 PM Bill, ASRC has approval in the two referenced wells (Hydrate P2 & Hydrate P1) to pressure test the 14” x 16” casing to the lower test pressure of 2000 psi, which is 53% of burst when taking into account a full column of 9 ppg mud and the vacuum on the backside. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Isaacson, William <wisaacson@asrcenergy.com> Sent: Thursday, December 8, 2022 3:32 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dial, Amanda <ADial@asrcenergy.com>; Quick, Michael <mquick@asrcenergy.com> Subject: Casing Pressure Test Value - PTD 222-125 and 222-141 Bryan, As per our discussion, the planned test value for the 14” x 16” VIC surface casing submitted in the Hydrate-P1 & P2 permit to drill was 3000 psi. This value was used based upon a requirement to meet a minimum 50% of internal yield for the test. The 14” casing has an internal yield of 5620 psi, therefore requiring a minimum 2810 psi test pressure, which was then raised to 3000 psi for simplicity. However, in preparation for this test on the well, the rig team took into account the fact that the VIC casing does not allow external hydrostatic or other back-up to the test pressure due to the void between the 14” and 16” casing in the VIC. Therefore, when we consider the internal hydrostatic pressure from a 9.0 ppg column of mud without any back-up support from a fluid column in the annulus, we are exceeding 70% of the internal yield rating for the 16” x 14” casing near the bottom of the surface casing string with a 3000 psi casing test. The request is to lower the casing test pressure (for both the Hydrate-P1 & P2 wells) to a value bringing this differential back in line with the minimum 50% of internal yield test requirement (for the pipe near TD), yet still provide more than adequate surface pressure to exceed any possible surface pressure arising from a well control event. The proposed pressure test value is 2000 psi, which would result in 53% of internal yield for the 16” x 14” at the bottom of the string. This value is also well in excess of the Maximum Anticipated Surface Pressure of 1241 psi which would result from a well control event with a gas column to surface over the Maximum Anticipated Bottom Hole Pressure of 1578 psi, as outline in the Permit to Drill. Please let me know if the AOGCC is aligned and approves this change, or is there are any questions I can answer. Thanks Bill Isaacson Drilling Engineer ASRC Energy Services Alaska, Inc. 3900 C Street, Suite 701 Anchorage, AK 99503 Direct: 907-339-6455 | Cell: 907-242-7483One Crew, One JourneyHonoring the values of our founders as we develop the future. 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STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume.6. Sold Pool Name Pool Code 7. Reinjected 8. Flared or vented 1 hour or less 12. Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9. Flared or vented more than 1 hour (see instr.) 10. Pilot and Purge 11. Assist Gas Safety:MCF 13. Other (see instructions) Lease Use:MCF 14. TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15. NGL Gas Equivalent Waste:MCF 16. Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19. Remarks: 17. Transferred from: 18. Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 8 0 0 0 0.0 0.0 0 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas Jan, 2025 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation 0 0 014. TOTALContact Email: sshirzadi@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-6462 Title: Subsurface and Wells Development Authorized Name and Digital Signature with date: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume.6. Sold Pool Name Pool Code 7. Reinjected 8. Flared or vented 1 hour or less 12. Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9. Flared or vented more than 1 hour (see instr.) 10. Pilot and Purge 11. Assist Gas Safety:MCF 13. Other (see instructions) Lease Use:MCF 14. TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15. NGL Gas Equivalent Waste:MCF 16. Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19. Remarks: 17. Transferred from: 18. Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 8 0 0 0 0.0 0.0 0 0 0 0 0 014. TOTALContact Email: sshirzadi@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-6462 Title: Subsurface and Wells Development Authorized Name and Digital Signature with date: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas Dec, 2024 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume.6. Sold Pool Name Pool Code 7. Reinjected 8. Flared or vented 1 hour or less 12. Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9. Flared or vented more than 1 hour (see instr.) 10. Pilot and Purge 11. Assist Gas Safety:MCF 13. Other (see instructions) Lease Use:MCF 14. TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15. NGL Gas Equivalent Waste:MCF 16. Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19. Remarks: 17. Transferred from: 18. Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 8 0 0 0 0.0 0.0 0 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas Nov, 2024 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation 0 0 014. TOTALContact Email: sshirzadi@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-6462 Title: Subsurface and Wells Development Authorized Name and Digital Signature with date: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume.6. Sold Pool Name Pool Code 7. Reinjected 8. Flared or vented 1 hour or less 12. Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9. Flared or vented more than 1 hour (see instr.) 10. Pilot and Purge 11. Assist Gas Safety:MCF 13. Other (see instructions) Lease Use:MCF 14. TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15. NGL Gas Equivalent Waste:MCF 16. Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19. Remarks: 17. Transferred from: 18. Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 8 0 0 0 0.0 0.0 0 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas Oct, 2024 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation 0 0 014. TOTALContact Email: sshirzadi@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-6462 Title: Subsurface and Wells Development Authorized Name and Digital Signature with date: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume.6. Sold Pool Name Pool Code 7. Reinjected 8. Flared or vented 1 hour or less 12. Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9. Flared or vented more than 1 hour (see instr.) 10. Pilot and Purge 11. Assist Gas Safety:MCF 13. Other (see instructions) Lease Use:MCF 14. TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15. NGL Gas Equivalent Waste:MCF 16. Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19. Remarks: 17. Transferred from: 18. Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 8 0 0 0 0.0 0.0 0 0 0 0 0 014. TOTALContact Email: sshirzadi@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-6462 Title: Subsurface and Wells Development Authorized Name and Digital Signature with date: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas Sep, 2024 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume.6. Sold Pool Name Pool Code 7. Reinjected 8. Flared or vented 1 hour or less 12. Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9. Flared or vented more than 1 hour (see instr.) 10. Pilot and Purge 11. Assist Gas Safety:MCF 13. Other (see instructions) Lease Use:MCF 14. TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15. NGL Gas Equivalent Waste:MCF 16. Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19. Remarks: 17. Transferred from: 18. Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 8 0 0 0 0.0 0.0 0 0 0 0 0 014. TOTALContact Email: sshirzadi@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-6462 Title: Subsurface and Wells Development Authorized Name and Digital Signature with date: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas Aug, 2024 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20.For production from multiple pools, list contribution of each pool as a percent of Total Volume.6.Sold Pool Name Pool Code 7. Reinjected 8.Flared or vented 1 hour or less 12.Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9.Flared or vented more than 1 hour (see instr.) 10.Pilot and Purge 11.Assist Gas Safety:MCF 13.Other (see instructions) Lease Use:MCF 14.TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15.NGL Gas Equivalent Waste:MCF 16.Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19.Remarks: 17.Transferred from: 18.Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakley on Aug. 15, 2024 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 5 27 160 0 17.5 5.9 0 473 159 0 473 15914. TOTALContact Email: roakley@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-6218 Title: Petroleum Engineer Authorized Name and Digital Signature with date: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas July, 2024 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakleyon Aug. 15, 2024 Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20.For production from multiple pools, list contribution of each pool as a percent of Total Volume.6.Sold Pool Name Pool Code 7. Reinjected 8.Flared or vented 1 hour or less 12.Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9.Flared or vented more than 1 hour (see instr.) 10.Pilot and Purge 11.Assist Gas Safety:MCF 13.Other (see instructions) Lease Use:MCF 14.TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15.NGL Gas Equivalent Waste:MCF 16.Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19.Remarks: 17.Transferred from: 18.Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakley on July 19, 2024 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 5 27 191 0 25.4 68.8 0 686 1,858 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas June, 2024 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation 0 686 1,85814. TOTALContact Email: roakley@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-6218 Title: Petroleum Engineer Authorized Name and Digital Signature with date: Signed by Ray Oakley on July 19, 2024 Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20.For production from multiple pools, list contribution of each pool as a percent of Total Volume.6.Sold Pool Name Pool Code 7. Reinjected 8.Flared or vented 1 hour or less 12.Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9.Flared or vented more than 1 hour (see instr.) 10.Pilot and Purge 11.Assist Gas Safety:MCF 13.Other (see instructions) Lease Use:MCF 14.TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15.NGL Gas Equivalent Waste:MCF 16.Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19.Remarks: 17.Transferred from: 18.Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakley on June 19, 2024 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 5 9 287 0 28.6 87.4 0 257 787 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas May, 2024 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation 0 257 78714. TOTALContact Email: roakley@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-6218 Title: Petroleum Engineer Authorized Name and Digital Signature with date: Signed by Ray Oakley on June 19, 2024 Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20.For production from multiple pools, list contribution of each pool as a percent of Total Volume.6. Sold Pool Name Pool Code 7. Reinjected 8. Flared or vented 1 hour or less 12. Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9. Flared or vented more than 1 hour (see instr.) 10. Pilot and Purge 11. Assist Gas Safety:MCF 13. Other (see instructions) Lease Use:MCF 14. TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15. NGL Gas Equivalent Waste:MCF 16. Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19. Remarks: 17. Transferred from: 18. Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakley on May 14, 2024 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 5 11 322 0 12.8 42.3 0 141 465 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas April, 2024 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation 0 141 46514. TOTALContact Email: roakley@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-6218 Title: Petroleum Engineer Authorized Name and Digital Signature with date: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakleyon May 14, 2024 Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20.For production from multiple pools, list contribution of each pool as a percent of Total Volume.6. Sold Pool Name Pool Code 7. Reinjected 8. Flared or vented 1 hour or less 12. Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9. Flared or vented more than 1 hour (see instr.) 10. Pilot and Purge 11. Assist Gas Safety:MCF 13. Other (see instructions) Lease Use:MCF 14. TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15. NGL Gas Equivalent Waste:MCF 16. Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19. Remarks: 17. Transferred from: 18. Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakley on Apr. 20, 2024 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 5 31 566 0 15.4 58.9 0 477 1,826 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas March, 2024 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation 0 477 1,82614.TOTALContact Email: roakley@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-6218 Title: Petroleum Engineer Authorized Name and Digital Signature with date: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakley 4/19/2024 Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20.For production from multiple pools, list contribution of each pool as a percent of Total Volume.6.Sold Pool Name Pool Code 7. Reinjected 8.Flared or vented 1 hour or less 12.Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9.Flared or vented more than 1 hour (see instr.) 10.Pilot and Purge 11.Assist Gas Safety:MCF 13.Other (see instructions) Lease Use:MCF 14.TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15.NGL Gas Equivalent Waste:MCF 16.Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19.Remarks: 17.Transferred from: 18.Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakley on Mar. 20, 2024 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 5 29 540 0 15.4 57.7 0 447 1,673 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas February, 2024 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation 0 447 1,67314. TOTALContact Email: roakley@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-6218 Title: Petroleum Engineer Authorized Name and Digital Signature with date: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakleyon Mar. 19, 2024 Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume.6. Sold Pool Name Pool Code 7. Reinjected 8. Flared or vented 1 hour or less 12. Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9. Flared or vented more than 1 hour (see instr.) 10. Pilot and Purge 11. Assist Gas Safety:MCF 13. Other (see instructions) Lease Use:MCF 14. TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15. NGL Gas Equivalent Waste:MCF 16. Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19. Remarks: 17. Transferred from: 18. Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov 8. OIL (BBL) 9. WATER (BBL) 10. GAS (MCF) 11. OIL (BBL) 12. WATER (BBL) 13. GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 5 31 545 0 16.7 52.3 0 518 1,621 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas January, 2024 3. Type 5. Method 7. Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1. Well Number 2. API Number: XX-XXX-XXXXX-XX-XX 4. Field & Pool Code 6. Days in Operation 0 518 1,62114. TOTALContact Email: roakley@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-7218 Title: Petroleum Engineer Authorized Name and Digital Signature with date: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakleyon Mar. 1, 2024 Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20.For production from multiple pools, list contribution of each pool as a percent of Total Volume.6.Sold Pool Name Pool Code 7. Reinjected 8.Flared or vented 1 hour or less 12.Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9.Flared or vented more than 1 hour (see instr.) 10.Pilot and Purge 11.Assist Gas Safety:MCF 13.Other (see instructions) Lease Use:MCF 14.TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15.NGL Gas Equivalent Waste:MCF 16.Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19.Remarks: 17.Transferred from: 18.Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakley on Mar. 20, 2024 8.OIL (BBL) 9.WATER (BBL) 10.GAS (MCF) 11.OIL (BBL) 12.W ATER (BBL) 13.GAS (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 5 28 496 0 12.8 49.2 0 358 1,378 0 358 1,37814.TOTALContact Email: roakley@ASRCenergy.com Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Contact Phone: 907-339-7218 Title: Petroleum Engineer Authorized Name and Digital Signature with date: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas December, 2023 3.Type 5.Method 7.Average FTP (psig) DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION1.Well Number 2.API Number: XX-XXX-XXXXX-XX-XX 4.Field & Pool Code 6.Days in Operation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator:Field and Pool:Month and Year: Form 10-405 Revised 10/2021 20 AAC 25.230 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakley on Mar. 1, 2024 Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20.For production from multiple pools, list contribution of each pool as a percent of Total Volume.6.Sold Pool Name Pool Code 7. Reinjected 8.Flared or vented 1 hour or less 12.Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9.Flared or vented more than 1 hour (see instr.) 10.Pilot and Purge 11.Assist Gas Safety:MCF 13.Other (see instructions) Lease Use:MCF 14.TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15.NGL Gas Equivalent Waste:MCF 16.Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19.Remarks: 17.Transferred from: 18.Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakley on Mar. 20, 2024 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator: Field and Pool: Month and Year. ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas November, 2023 1. Well 2. API Number: 3. Type 4. Field & 5. Method 6. Days in 7. Average FTP DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION Number XX-XXX-XXXXX-XX-XX Pool Code Operation (psig) 8. OIL 9. WATER % GAS 11. OIL 12. WATER 13. GAS (BBL) (BBL) (MCF) (BBL) (BBL) (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 5 27 508 0 12.6 50.5 0 340 1,364 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Petroleum Engineer Authorized Name and Digital Signature with date: Revision? r7 Date of Revision: �O Signed by Ray Oakley Contact Phone 907-339-7218 on Mar. 1, 2024 Contact Email roakley@ASRCenergy.com Y@ 9Y.00m 14. TOTAL 0 340 1,364 Submit in PDF format to Form 10-405 Revised 10/2021 20 AAC 25.230 aogcc.reporting@alaska.gov Percent Comm.Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Disposition Volume MCF 20.For production from multiple pools, list contribution of each pool as a percent of Total Volume.6.Sold Pool Name Pool Code 7. Reinjected 8.Flared or vented 1 hour or less 12.Fuel gas used in lease operations AOGCC Use Only Authorization >1 hr: 9.Flared or vented more than 1 hour (see instr.) 10.Pilot and Purge 11.Assist Gas Safety:MCF 13.Other (see instructions) Lease Use:MCF 14.TOTAL VOLUME (ITEMS 6-13) Conservation:MCF 15.NGL Gas Equivalent Waste:MCF 16.Purchased gas 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. Month/Year of Disposition Reviewed by: COMMISSIONER Authorized Name and Digital Signature with date: I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phone: Contact Email: Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235. Revision? Date of Revision:Title: 19.Remarks: 17.Transferred from: 18.Transferred to: (Express as a negative #) Form 10‐422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.gov Signed by Ray Oakley on Mar. 20, 2024 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT Name of Operator: Field and Pool: Month and Year: ASRC Consulting and Environmental Services Prudhoe Bay, Undefined Gas October, 2023 1. Well 2. API Number: 3. Type 4. Field & 5. Method 6. Days in 7. Average FTP DAILY AVERAGE PRODUCTION TOTAL MONTHLY PRODUCTION Number XX-XXX-XXXXX-XX-XX Pool Code Operation (psig) 8. OIL 9. WATER 10. GAS 11. OIL 12. WATER 13. GAS (BBL) (BBL) (MCF) (BBL) (BBL) (MCF) Hydrate-P1 50-029-23737-00-00 2 640500 5 6 767 0 9.9 8.2 0 59 49 1 hereby certify that the foregoing is true and coned to the best of my knowledge. Title: Petroleum Engineer Revision? O Date of Revision: Authorized Name and Digital Signature with date: Signed by Ray Oakley ContactPhone: 907-339-7218 404 on Mar. 1, 2024 Contact Email: roakley@ASRCenergy.wm 14. TOTAL 0 59 49 Submit in PDF format to Form 10-405 Revised 10/2021 20 AAC 25.230 aogcc.reporting@alaska.gov