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HomeMy WebLinkAbout222-038Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/21/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260121 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 16RD 50133205540100 207125 12/3/2025 AK E-LINE PPROF T41253 BRU 211-35 50283201890000 223050 11/7/2025 AK E-LINE Perf T41254 BRU 213-26 50283201920000 223069 11/23/2025 AK E-LINE Perf T41255 BRU 213-26T 50283202040000 225038 11/4/2025 AK E-LINE Perf T41256 BRU 241-34S 50283201980000 224077 11/9/2025 AK E-LINE Perf T41257 BRU 241-34T 50283201810000 220052 11/6/2025 AK E-LINE Perf T41258 BRU 244-27 50283201850000 222038 12/13/2025 AK E-LINE Perf T41259 BRU 244-27 50283201850000 222038 12/19/2025 AK E-LINE StripGun T41259 GP ST 17586 9 50733204480000 193062 11/13/2025 AK E-LINE Perf T41260 IRU 241-01 50283201840000 221076 12/21/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/30/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/16/2025 AK E-LINE Plug T41261 IRU 241-01 50283201840000 221076 11/26/2025 AK E-LINE Plug/Perf T41261 KALOTSA 01 50133206570000 216132 11/19/2025 AK E-LINE Perf T41262 KBU 31-18 50133206490000 215024 11/8/2025 AK E-LINE Drift/PPROF T41263 KU 12-17 50133205770000 208089 11/14/2025 AK E-LINE StimGun T41264 LRU C-01RD 50283200610100 201168 11/27/2025 AK E-LINE RCT/Perf T41265 MPI 2-32 50029220840000 190119 12/10/2025 AK E-LINE LDL T41266 MPI 2-38 50029220900000 190129 12/5/2025 AK E-LINE LDL T41267 MPU H-16 50029232270000 204190 12/3/2025 AK E-LINE CBL T41268 MPU H-16 50029232270000 204190 11/19/2025 AK E-LINE TubingCut T41268 MPU I-14 50029232140000 204119 11/13/2025 AK E-LINE CBL T41269 NCIU A-06A 50883200260100 225071 11/28/2025 AK E-LINE Perf/Plug T41270 NCIU A-08 50883200280000 169063 12/2/2025 AK E-LINE GPT T41271 NCIU A-19 50883201940000 224026 12/16/2025 AK E-LINE GPT T41272 NCIU A-19 50883201940000 224026 12/12/2025 AK E-LINE GPT/Perf/Plug T41272 NCIU A-19 50883201940000 224026 12/17/2025 AK E-LINE Perf T41272 NCIU A-21A 50883201990100 225075 12/30/2025 AK E-LINE PPROF T41273 OP19-T1N 50029234910000 213068 11/19/2025 AK E-LINE TubingPunch T41274 T41259BRU 244-27 50283201850000 222038 12/13/2025 AK E-LINE Perf BRU 244-27 50283201850000 222038 12/19/2025 AK E-LINE StripGun Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:35 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU D-10 50283202080000 225082 12/9/2025 AK E-LINE Perf T41275 SCU 322C-04 50133101040100 215217 12/4/2025 AK E-LINE TubingPunch T41276 SRU 222-33 50133207150000 223100 12/7/2025 AK E-LINE Plug T41277 SU 43-10 50133207390000 225107 11/26/2025 AK E-LINE CBL T41278 TBU A-12RD 50733200760100 171029 11/29/2025 AK E-LINE Perf T41279 TBU D-24A 50733202240100 174064 12/2/2025 AK E-LINE TubingPunch T41280 TBU D-24A 50733202240100 174064 11/21/2025 AK E-LINE TubingPunch T41280 TBU M-10 50733205880000 209154 11/15/2025 AK E-LINE Perf T41281 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:51 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 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): 7,303' N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi 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 chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 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 Chad Helgeson, Operations Engineer AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA029657 222-038 50-283-20185-00-00 Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 2,700' 8,430psi 2,589' Size 138' 2,898' MD See Attached Schematic 2,980psi 6,880psi 120'120' 2,898' October 28, 2025 Tieback 4-1/2" 7,303' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beluga River Unit (BRU) 244-27CO 802A Same 6,871'4-1/2" ~1905psi 4,609' 5,905' Length Baker HRD-E ZXP; N/A 2,694' MD/2,414' TVD; N/A 6,871' 5,905' 5,903' Beluga River Sterling-Beluga Gas 16" 7-5/8" See Attached Schematic m n P s 66 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:14 am, Oct 09, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.10.08 15:36:28 - 08'00' Noel Nocas (4361) 10-404 BJM 10/13/25 A.Dewhurst 14OCT25 325-615 DSR-10/15/25 10/16/2025 Well Prognosis Well Name: BRU 244-27 API Number: 50-283-20185-00-00 Current Status: Gas Producer Permit to Drill Number: 222-038 First Call Engineer: Chad Helgeson (907) 777-8504 (O) (907) 229-4824 (C) Second Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8663 (C) Maximum Expected BHP: ~2125 psi @ 5489’ TVD (0.43 psi/ft to deepest perf) Max. Potential Surface Pressure: ~1905 psi (0.04 psi/ft gas to surface) Applicable Overpressure Gradient: 0.72 psi/ft using 13.83 ppg EMW FIT at the Surface shoe (2898 ft) Shallowest Allowable Perf TVD: MPSP/(0.72-0.04) = 1905 psi / 0.68 = 2,801‘ TVD Top of SBGP (CO 802A): ~3,117’ MD/ ~2,786’ TVD Well Status: Online Producer making 2817 mcfd at 230 psi FTP with 5 bw Brief Well Summary BRU 244-27 is a 2022 grass roots producer drilled and completed in the Beluga G-H sands with an IP of 3700 mcfd when first brought online. Mid-2023 perforations were added uphole in the Beluga G2-G9 sands increasing the rate to over 4MM. Additional perforations were added in February 2024 increasing rate, and again in April & May of 2025. Objective: The purpose of this work/sundry is to increase production by adding additional perforations in the Beluga D and E sands. All sands lie in the BRU SBGP. Notes Regarding Wellbore Condition: 3-1/2” TOC @ ~2680’ from CBL 9-13-22 Procedure 1. RU E-line, PT lubricator to 2000 psi 2. Perforate Beluga sands from the bottom up within the below intervals: Zone Top MD Btm MD Top TVD Btm TVD FT Top of SBGP (CO 802A):~3,117’ MD/ ~2,786’ TVD Beluga D1 ±3,947’ ±3,952’ ±3,587’ ±3,592’ ±5’ Beluga D1 ±3,961’ ±3,967’ ±3,601’ ±3,607’ ±6’ Beluga D2 ±3,975’ ±3,980’ ±3,615’ ±3,620’ ±5’ Beluga D3 ±3,989’ ±3,993’ ±3,628’ ±3,632’ ±4’ Beluga D3 ±4,005’ ±4,011’ ±3,644’ ±3,650’ ±6’ Beluga D4 ±4,028’ ±4,035’ ±3,667’ ±3,673’ ±7’ Beluga D5 ±4,052’ ±4,068’ ±3,690’ ±3,706’ ±16’ Beluga D6 ±4,093’ ±4,111’ ±3,730’ ±3,748’ ±18’ Beluga D7 ±4,121’ ±4,125’ ±3,758’ ±3,762’ ±4’ Beluga E6 ±4,439’ ±4,444’ ±4,069’ ±4,074’ ±5’ Beluga E6 ±4,456’ ±4,482’ ±4,086’ ±4,112’ ±26’ 3. Return well to production. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic _____________________________________________________________________________________ Updated by DMA 05-28-25 SCHEMATIC Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 H10 1 2 3 RKB to GL = 17.6’ PBTD = 7,214’ MD / TVD = 6,784’ TD = 7,303’ MD / TVD = 6,871’ H12 H7 H4 G1 H6 G2-G3 G-4-G5 G7 G8 G9 H2-H3 E1-E3 F1-F10 SL tagged @ 5433’ 2/1/25 4 E5-E6 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8"Surf Csg 29.7 L-80 USS-CDC 6.875”Surf 2,898’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C-HT 3.958”2,694’7,303’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C-HT 3.958”Surf 2,700’ JEWELRY DETAIL No. Depth ID OD Item 1 521’3.958”4.500”VanOil Chemical Injection Mandrel 2 2,694’4.875”6.540”5-1/2” Flex lock V Liner hanger / HRD-E ZXP LTP 3 2,700’3.930”5.630”5-1/2” Bullet Assembly 3.42’ off NO-GO 4 5,905’CIBP set 12/22/22 OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (Cement to surface on 6/3/2022) 4-1/2”TOC @ 2680’ CBL 9/13/22 PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status Top of Pool (CO 802A) 3117’ MD; 2786’ TVD Bel E1 4,165’4,175’3,801’3,811’10'4/20/2025 Open Bel E1 4,187’4,197’3,822’3,832’10'4/9/2025 Open Bel E1 4,187’4,191’3,822’3,826’4'5/15/2025 Open Bel E1 4,204'4,207'3,839’3,842’3'4/9/2025 Open Bel E1 4,204'4,320'3,839’3,953’14’5/15/2025 Open Bel E3 4,224’4,233’3,859’3,867’9'4/9/2025 Open Bel E3 4,227’4,230’3,862’3,864’3’4/19/2025 Open Bel E3 4,237'4,243'3,871’3,877’6’4/9/2025 Open Bel E3 4,237'4,240'3,871’3,874’3’4/19/2025 Open Bel E3 4,317’4,320’3,950’3,953’3'4/8/2025 Open Bel E3 4,317'4,320'3,950’3,053’3’5/15/2025 Open Bel E5 4,369’4,372’4,001’4,004’3'5/15/2025 Open Bel E5 4,381' 4,392' 4,013' 4,024' 11' 2/28/2024 Open Bel E5 4,425' 4,428' 4,055' 4,058' 3' 2/28/2024 Open Bel E6 4,456’ 4,482’ 4,086’ 4,112’26' 4/8/2025 Open Bel E6 4,460' 4,470'4,090’ 4,110’10' 4/19/2025 Open Bel E6 4,496' 4,510' 4,125' 4,139' 14' 2/28/2024 Open Bel F1 4,560' 4,570' 4,188' 4,198' 10' 2/28/2024 Open Bel F4 4,597' 4,602' 4,223' 4,229' 5' 2/28/2024 Open Bel F4 4,644' 4,650' 4,270' 4,276' 6' 2/28/2024 Open Bel F5 4,662' 4,670' 4,288' 4,296' 8' 2/28/2024 Open Bel F5 4,676' 4,680' 4,301' 4,305' 4' 2/28/2024 Open Bel F5 4,697' 4,701' 4,323' 4,327' 4' 2/28/2024 Open Bel F6 4,708' 4,718' 4,334' 4,344' 10' 2/28/2024 Open Bel F6 4,708' 4,718' 4,334' 4,344' 10' 2/27/2024 Open Bel F6 4,728' 4,735' 4,353' 4,360' 7' 2/27/2024 Open Bel F6 4,755' 4,761' 4,379' 4,385' 6' 2/27/2024 Open Bel F7 4,842' 4,848' 4,464' 4,468' 6' 2/27/2024 Open Bel F7 4,858' 4,861' 4,479' 4,484' 3' 2/27/2024 Open Bel F7 4,886' 4,892' 4,507' 4,513' 6' 2/27/2024 Open Bel F7 4,924' 4,939' 4,544' 4,559' 15' 2/27/2024 Open Bel F10 5,021' 5,026' 4,639' 4,643' 5' 2/27/2024 Open Bel G1 5,072' 5,086' 4,689' 4,703' 14' 2/27/2024 Open Bel G2 5,101' 5,103' 4,717' 4,719' 2' 6/30/2023 Open Perforations Continued on Page 2 Page 2 of 2 Updated by DMA 05-28-25 SCHEMATIC Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 PERFORATION DETAIL (Continued from Previous Page) Zone Top MD Btm MD Top TVD Btm TVD FT Date Status Bel G3 5,124' 5,128' 4,740' 4,744' 4' 6/30/2023 Open Bel G3 5,139' 5,145' 4,754' 4,760' 6' 6/30/2023 Open Bel G4 5,155' 5,158' 4,770' 4,773' 3' 2/27/2024 Open Bel G4 5,164' 5,168' 4,779' 4,783' 4' 2/27/2024 Open Bel G5 5,215’ 5,228’ 4,829’ 4,842’ 13’ 12/22/2022 Open Bel G7 5,303' 5,311' 4,915' 4,923' 8' 6/30/2023 Open Bel G8 5,332' 5,340' 4,943' 4,951' 8' 6/30/2023 Open Bel G9 5,356' 5,359' 4,967' 4,970' 3' 6/29/2023 Open Bel H2 5,535’ 5,548’ 5,142’ 5,154’ 13’ 12/22/2022 Open Bel H3 5,582’ 5,587’ 5,188’ 5,193’ 5’ 6/13/2023 Open Bel H3 5,589’ 5,593’ 5,195’ 5,297’ 4’ 6/13/2023 Open Bel H4 5,604’ 5,609’ 5,210’ 5,215’ 5’ 6/13/2023 Open Bel H4 5,632’ 5,637’ 5,237’ 5,242’ 5’ 6/13/2023 Open Bel G4 5,155' 5,158' 4,770' 4,773' 3' 2/27/2024 Open Bel G4 5,164' 5,168' 4,779' 4,783' 4' 2/27/2024 Open Bel H4 5,632’ 5,637’ 5,237’ 5,242’ 5’ 6/13/2023 Open Bel H6 5,707’ 5,712’ 5,310’ 5,315’ 5’ 6/12/2023 Open Bel H6 5,716’ 5,721’ 5,319’ 5,324’ 5’ 6/12/2023 Open Bel H7 5,730’ 5,750’ 5,333’ 5,352’ 20’ 12/22/2022 Open Bel H10 5,850’ 5,855’ 5,450’ 5,455’ 5’ 6/12/2023 Open Bel H10 5,870’ 5,890’ 5,469’ 5,489’ 20’ 11/22/2022 Open Bel H12 5,930’ 5,950’ 5,527’ 5,547’ 20’ 12/21/2022 Plugged _____________________________________________________________________________________ Page 1 of 2 Updated by DMA 08-28-25 PROPOSED Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 H10 1 2 3 RKB to GL = 17.6’ PBTD = 7,214’ MD / TVD = 6,784’ TD = 7,303’ MD / TVD = 6,871’ H12 H7 H4 G1 H6 G2-G3 G-4-G5 G7 G8 G9 H2-H3 E1-E3 F1-F10 SL tagged @ 5433’ 2/1/25 4 E5-E6 D-D7 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8"Surf Csg 29.7 L-80 USS-CDC 6.875”Surf 2,898’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C-HT 3.958”2,694’7,303’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C-HT 3.958”Surf 2,700’ JEWELRY DETAIL No. Depth ID OD Item 1 521’3.958”4.500”VanOil Chemical Injection Mandrel 2 2,694’4.875”6.540”5-1/2” Flex lock V Liner hanger / HRD-E ZXP LTP 3 2,700’3.930”5.630”5-1/2” Bullet Assembly 3.42’ off NO-GO 4 5,905’CIBP set 12/22/22 OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (Cement to surface on 6/3/2022) 4-1/2”TOC @ 2680’ CBL 9/13/22 PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status Top of Pool (CO 802A) 3,117’ MD; 2,786’ TVD BEL D1 ±3,947'±3,952'±3,587'±3,592'±5'Proposed TBD BEL D1 ±3,961'±3,967'±3,601'±3,607'±6'Proposed TBD BEL D2 ±3,975'±3,980'±3,615'±3,620'±5'Proposed TBD BEL D3 ±3,989'±3,993'±3,628'±3,632'±4'Proposed TBD BEL D3 ±4,005'±4,011'±3,644'±3,650'±6'Proposed TBD BEL D4 ±4,028'±4,035'±3,667'±3,673'±7'Proposed TBD BEL D5 ±4,052'±4,068'±3,690'±3,706'±16'Proposed TBD BEL D6 ±4,093'±4,111'±3,730'±3,748'±18'Proposed TBD BEL D7 ±4,121'±4,125'±3,758'±3,762'±4'Proposed TBD Bel E1 4,165’4,175’3,801’3,811’10'4/20/2025 Open Bel E1 4,187’4,197’3,822’3,832’10'4/9/2025 Open Bel E1 4,187’ 4,191’ 3,822’ 3,826’4' 5/15/2025 Open Bel E1 4,204' 4,207'3,839’ 3,842’3' 4/9/2025 Open Bel E1 4,204' 4,320'3,839’ 3,953’ 14’5/15/2025 Open Bel E3 4,224’ 4,233’ 3,859’ 3,867’9' 4/9/2025 Open Bel E3 4,227’ 4,230’ 3,862’ 3,864’ 3’4/19/2025 Open Bel E3 4,237' 4,243'3,871’ 3,877’ 6’4/9/2025 Open Bel E3 4,237' 4,240'3,871’ 3,874’ 3’4/19/2025 Open Bel E3 4,317' 4,320'3,950’ 3,053’ 3’5/15/2025 Open Bel E3 4,317’ 4,320’ 3,950’ 3,953’3' 4/8/2025 Open Bel E5 4,369’ 4,372’ 4,001’ 4,004’3' 5/15/2025 Open Bel E5 4,381' 4,392' 4,013' 4,024' 11' 2/28/2024 Open Bel E5 4,425' 4,428' 4,055' 4,058' 3' 2/28/2024 Open BEL E6 ±4,439' ±4,444' ±4,069' ±4,074' ±5' Proposed TBD BEL E6 ±4,456' ±4,482' ±4,086' ±4,112' ±26' Proposed TBD Bel E6 4,456’ 4,482’ 4,086’ 4,112’26' 4/8/2025 Open Bel E6 4,460' 4,470'4,090’ 4,110’10' 4/19/2025 Open Bel E6 4,496' 4,510' 4,125' 4,139' 14' 2/28/2024 Open PERFORATION DETAIL (Continued from Following Page) _____________________________________________________________________________________ Page 2 of 2 Updated by DMA 08-28-25 PROPOSED Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 PERFORATION DETAIL (Continued from Previous Page) Zone Top MD Btm MD Top TVD Btm TVD FT Date Status Bel F1 4,560' 4,570' 4,188' 4,198' 10' 2/28/2024 Open Bel F4 4,597' 4,602' 4,223' 4,229' 5' 2/28/2024 Open Bel F4 4,644' 4,650' 4,270' 4,276' 6' 2/28/2024 Open Bel F5 4,662' 4,670' 4,288' 4,296' 8' 2/28/2024 Open Bel F5 4,676' 4,680' 4,301' 4,305' 4' 2/28/2024 Open Bel F5 4,697' 4,701' 4,323' 4,327' 4' 2/28/2024 Open Bel F6 4,708' 4,718' 4,334' 4,344' 10' 2/28/2024 Open Bel F6 4,708' 4,718' 4,334' 4,344' 10' 2/27/2024 Open Bel F6 4,728' 4,735' 4,353' 4,360' 7' 2/27/2024 Open Bel F6 4,755' 4,761' 4,379' 4,385' 6' 2/27/2024 Open Bel F7 4,842' 4,848' 4,464' 4,468' 6' 2/27/2024 Open Bel F7 4,858' 4,861' 4,479' 4,484' 3' 2/27/2024 Open Bel F7 4,886' 4,892' 4,507' 4,513' 6' 2/27/2024 Open Bel F7 4,924' 4,939' 4,544' 4,559' 15' 2/27/2024 Open Bel F10 5,021' 5,026' 4,639' 4,643' 5' 2/27/2024 Open Bel G1 5,072' 5,086' 4,689' 4,703' 14' 2/27/2024 Open Bel G2 5,101' 5,103' 4,717' 4,719' 2' 6/30/2023 Open Bel G3 5,124' 5,128' 4,740' 4,744' 4' 6/30/2023 Open Bel G3 5,139' 5,145' 4,754' 4,760' 6' 6/30/2023 Open Bel G4 5,155' 5,158' 4,770' 4,773' 3' 2/27/2024 Open Bel G4 5,164' 5,168' 4,779' 4,783' 4' 2/27/2024 Open Bel G5 5,215’ 5,228’ 4,829’ 4,842’ 13’ 12/22/2022 Open Bel G7 5,303' 5,311' 4,915' 4,923' 8' 6/30/2023 Open Bel G8 5,332' 5,340' 4,943' 4,951' 8' 6/30/2023 Open Bel G9 5,356' 5,359' 4,967' 4,970' 3' 6/29/2023 Open Bel H2 5,535’ 5,548’ 5,142’ 5,154’ 13’ 12/22/2022 Open Bel H3 5,582’ 5,587’ 5,188’ 5,193’ 5’ 6/13/2023 Open Bel H3 5,589’ 5,593’ 5,195’ 5,297’ 4’ 6/13/2023 Open Bel H4 5,604’ 5,609’ 5,210’ 5,215’ 5’ 6/13/2023 Open Bel H4 5,632’ 5,637’ 5,237’ 5,242’ 5’ 6/13/2023 Open Bel G4 5,155' 5,158' 4,770' 4,773' 3' 2/27/2024 Open Bel G4 5,164' 5,168' 4,779' 4,783' 4' 2/27/2024 Open Bel H4 5,632’ 5,637’ 5,237’ 5,242’ 5’ 6/13/2023 Open Bel H6 5,707’ 5,712’ 5,310’ 5,315’ 5’ 6/12/2023 Open Bel H6 5,716’ 5,721’ 5,319’ 5,324’ 5’ 6/12/2023 Open Bel H7 5,730’ 5,750’ 5,333’ 5,352’ 20’ 12/22/2022 Open Bel H10 5,850’ 5,855’ 5,450’ 5,455’ 5’ 6/12/2023 Open Bel H10 5,870’ 5,890’ 5,469’ 5,489’ 20’ 11/22/2022 Open Bel H12 5,930’ 5,950’ 5,527’ 5,547’ 20’ 12/21/2022 Plugged 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 . 50 - 2 8 3 - 2 0 1 8 5 - 0 0 - 0 0 We l l N a m e / N o . BE L U G A R I V U N I T 2 4 4 - 2 7 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 11 / 2 2 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 3 8 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 73 0 3 TV D 68 7 1 Cu r r e n t S t a t u s 1- G A S 7/ 2 3 / 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 : Mu d l o g , L W D ( D G R , S P 4 , C T N , A L D ) , C B L 9 - 1 3 - 2 2 , P e r f , G P T No No 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 7/ 8 / 2 0 2 2 10 7 4 0 0 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 : B R U 2 4 4 - 2 7 . l a s 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 D a i l y R e p o r t s . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U - 2 4 4 - 2 7 F i n a l W e l l R e p o r t . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 D r i l l i n g D y n a m i c s Lo g M D 2 i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 D r i l l i n g D y n a m i c s Lo g M D 5 i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 D r i l l i n g D y n a m i c s Lo g T V D 2 i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 D r i l l i n g D y n a m i c s Lo g T V D 5 i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F o r m a t i o n L o g M D 2i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F o r m a t i o n L o g M D 5i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F o r m a t i o n L o g T V D 2i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F o r m a t i o n L o g T V D 5i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 G a s R a t i o L o g M D 2i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 G a s R a t i o L o g M D 5i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 G a s R a t i o L o g T V D 2i n . p d f 36 7 4 2 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 1 o f 5 BR U 2 4 4 - 2 7 . 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 . 50 - 2 8 3 - 2 0 1 8 5 - 0 0 - 0 0 We l l N a m e / N o . BE L U G A R I V U N I T 2 4 4 - 2 7 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 11 / 2 2 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 3 8 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 73 0 3 TV D 68 7 1 Cu r r e n t S t a t u s 1- G A S 7/ 2 3 / 2 0 2 5 UI C No DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 G a s R a t i o L o g T V D 5i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 L W D C o m b o L o g MD 2 i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 L W D C o m b o L o g MD 5 i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 L W D C o m b o L o g TV D 2 i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 L W D C o m b o L o g TV D 5 i n . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 D r i l l i n g D y n a m i c s Lo g M D 2 i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 D r i l l i n g D y n a m i c s Lo g M D 5 i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 D r i l l i n g D y n a m i c s Lo g T V D 2 i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 D r i l l i n g D y n a m i c s Lo g T V D 5 i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F o r m a t i o n L o g M D 2i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F o r m a t i o n L o g M D 5i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F o r m a t i o n L o g T V D 2i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F o r m a t i o n L o g T V D 5i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 G a s R a t i o L o g M D 2i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 G a s R a t i o L o g M D 5i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 G a s R a t i o L o g T V D 2i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 G a s R a t i o L o g T V D 5i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 L W D C o m b o L o g MD 2 i n . t i f 36 7 4 2 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 2 o f 5 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 . 50 - 2 8 3 - 2 0 1 8 5 - 0 0 - 0 0 We l l N a m e / N o . BE L U G A R I V U N I T 2 4 4 - 2 7 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 11 / 2 2 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 3 8 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 73 0 3 TV D 68 7 1 Cu r r e n t S t a t u s 1- G A S 7/ 2 3 / 2 0 2 5 UI C No DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 L W D C o m b o L o g MD 5 i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 L W D C o m b o L o g TV D 2 i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 L W D C o m b o L o g TV D 5 i n . t i f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 S h o w R e p o r t s . p d f 36 7 4 2 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 11 5 7 3 0 3 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 : B R U 2 4 4 - 2 7 LW D F I n a l . l a s 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F i n a l M D . c g m 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F i n a l T V D . c g m 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 - D e f i n i t i v e S u r v e y Re p o r t . p d f 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 - D S R G I S . t x t 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 - D S R . t x t 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 - F i n a l S u r v e y s . x l s x 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 D S R - P l a n P l o t . p d f 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 D S R - V s e c P l o t . p d f 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F i n a l M D . e m f 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F i n a l T V D . e m f 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F i n a l M D . p d f 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F i n a l T V D . p d f 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F i n a l M D . t i f 36 7 4 5 ED Di g i t a l D a t a DF 7/ 8 / 2 0 2 2 E l e c t r o n i c F i l e : B R U 2 4 4 - 2 7 F i n a l T V D . t i f 36 7 4 5 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 72 0 2 2 6 0 0 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 : B R U _ 2 4 4 - 27 _ R B T _ 1 3 S E P 2 2 _ M a i n P a s s . l a s 37 1 0 5 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B R U _ 2 4 4 - 2 7 _ R B T _ 1 3 S E P 2 2 . p d f 37 1 0 5 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B R U _ 2 4 4 - 27 _ R B T _ 1 3 S E P 2 2 _ i m g . t i f f 37 1 0 5 ED Di g i t a l D a t a DF 10 / 5 / 2 0 2 2 E l e c t r o n i c F i l e : B R U _ 2 4 4 - 27 _ R B T _ 1 3 S E P 2 2 _ M a i n P a s s . d l i s 37 1 0 5 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 3 o f 5 BR U 2 4 4 - 2 7 LW D F I n al. l as 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 . 50 - 2 8 3 - 2 0 1 8 5 - 0 0 - 0 0 We l l N a m e / N o . BE L U G A R I V U N I T 2 4 4 - 2 7 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 11 / 2 2 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 3 8 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 73 0 3 TV D 68 7 1 Cu r r e n t S t a t u s 1- G A S 7/ 2 3 / 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 DF 12 / 2 / 2 0 2 2 60 2 3 5 7 1 0 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 : B R U _ 2 4 4 - 27 _ P e r f _ G P T _ 2 3 - N o v - 2 0 2 2 _ ( 4 0 8 2 ) . l a s 37 3 4 7 ED Di g i t a l D a t a DF 12 / 2 / 2 0 2 2 E l e c t r o n i c F i l e : B R U _ 2 4 4 - 2 7 _ P e r f _ G P T _ 2 3 - N o v - 20 2 2 _ ( 4 0 8 2 ) . p d f 37 3 4 7 ED Di g i t a l D a t a DF 12 / 2 9 / 2 0 2 2 72 0 8 6 0 1 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 : B R U _ 2 4 4 - 27 _ G P T _ 1 3 - N o v - 2 0 2 2 _ ( 4 0 6 4 ) . l a s 37 4 0 5 ED Di g i t a l D a t a DF 12 / 2 9 / 2 0 2 2 E l e c t r o n i c F i l e : B R U _ 2 4 4 - 2 7 _ G P T _ 1 3 - N o v - 20 2 2 _ ( 4 0 6 4 ) . p d f 37 4 0 5 ED Di g i t a l D a t a DF 7/ 1 0 / 2 0 2 3 58 6 8 5 5 1 4 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 : B R U _ 2 4 4 - 27 _ P e r f _ 1 3 - J u n - 2 0 2 3 _ ( 4 3 4 2 ) . l a s 37 8 1 2 ED Di g i t a l D a t a DF 7/ 1 0 / 2 0 2 3 E l e c t r o n i c F i l e : B R U _ 2 4 4 - 2 7 _ P e r f _ 1 3 - J u n - 20 2 3 _ ( 4 3 4 2 ) . p d f 37 8 1 2 ED Di g i t a l D a t a DF 7/ 2 5 / 2 0 2 3 57 1 8 4 9 9 3 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 : B R U _ 2 4 4 - 27 _ P e r f _ 3 0 - J u n - 2 0 2 3 _ ( 4 3 6 2 ) . l a s 37 8 7 4 ED Di g i t a l D a t a DF 7/ 2 5 / 2 0 2 3 E l e c t r o n i c F i l e : B R U _ 2 4 4 - 2 7 _ P e r f _ 3 0 - J u n - 20 2 3 _ ( 4 3 6 2 ) . p d f 37 8 7 4 ED Di g i t a l D a t a DF 3/ 1 8 / 2 0 2 4 53 1 8 4 9 9 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 : B R U _ 2 4 4 - 27 _ G P T _ P e r f _ 2 7 - F e b - 2 0 2 4 _ ( 4 7 0 0 ) . l a s 38 6 3 3 ED Di g i t a l D a t a DF 3/ 1 8 / 2 0 2 4 E l e c t r o n i c F i l e : B R U _ 2 4 4 - 2 7 _ G P T _ P e r f _ 2 7 - F e b - 20 2 4 _ ( 4 7 0 0 ) . p d f 38 6 3 3 ED Di g i t a l D a t a DF 4/ 2 8 / 2 0 2 5 47 1 0 4 1 0 0 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 : B R U _ 2 4 4 - 27 _ P e r f _ 0 8 - A p r i l - 2 0 2 5 _ ( 5 3 8 9 ) . l a s 40 3 3 1 ED Di g i t a l D a t a DF 4/ 2 8 / 2 0 2 5 E l e c t r o n i c F i l e : B R U _ 2 4 4 - 2 7 _ P e r f _ 0 8 - A p r i l - 20 2 5 _ ( 5 3 8 9 ) . p d f 40 3 3 1 ED Di g i t a l D a t a DF 5/ 8 / 2 0 2 5 45 4 7 4 2 9 6 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 : B R U _ 2 4 4 - 27 _ P e r f _ 1 9 - A p r i l - 2 0 2 5 _ ( 5 4 0 6 ) . l a s 40 3 7 3 ED Di g i t a l D a t a DF 5/ 8 / 2 0 2 5 E l e c t r o n i c F i l e : B R U _ 2 4 4 - 2 7 _ P e r f _ 1 9 - A p r i l - 20 2 5 _ ( 5 4 0 6 ) . p d f 40 3 7 3 ED Di g i t a l D a t a DF 6/ 1 6 / 2 0 2 5 44 5 4 4 0 9 6 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 : B R U _ 2 4 4 - 27 _ P e r f _ 1 5 - M a y - 2 0 2 5 _ ( 5 4 5 2 ) . l a s 40 5 5 0 ED Di g i t a l D a t a DF 6/ 1 6 / 2 0 2 5 E l e c t r o n i c F i l e : B R U _ 2 4 4 - 2 7 _ P e r f _ 1 5 - M a y - 20 2 5 _ ( 5 4 5 2 ) . p d f 40 5 5 0 ED Di g i t a l D a t a We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 4 o f 5 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 . 50 - 2 8 3 - 2 0 1 8 5 - 0 0 - 0 0 We l l N a m e / N o . BE L U G A R I V U N I T 2 4 4 - 2 7 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 11 / 2 2 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 3 8 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 73 0 3 TV D 68 7 1 Cu r r e n t S t a t u s 1- G A S 7/ 2 3 / 2 0 2 5 UI C No 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 : 11 / 2 2 / 2 0 2 2 Re l e a s e D a t e : 5/ 1 1 / 2 0 2 2 8/ 1 5 / 2 0 2 2 29 3 0 7 3 0 3 41 8 0 7 Cu t t i n g s We d n e s d a y , J u l y 2 3 , 2 0 2 5 AO G C C P a g e 5 o f 5 M. G u h l 7/ 2 3 / 2 0 2 5 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250613 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN-17A 50733203110100 213049 4/14/2025 AK E-LINE GPT T40549 AN-17A 50733203110100 213049 4/16/2025 AK E-LINE Perf T40549 BRU 244-27 50283201850000 222038 5/15/2025 AK E-LINE Perf T40550 IRU 241-01 50283201840000 221076 5/16/2025 AK E-LINE Perf T40551 KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP T40552 KU 13-06A 50133207160000 223112 5/9/2025 AK E-LINE Perf T40552 KU 33-08 50133207180000 224008 5/30/2025 AK E-LINE Perf T40553 MPU K-33 50029227290000 196202 5/2/2025 AK E-LINE Caliper T40554 Aurora S-100A 50029229620100 224083 5/8/2025 BAKER MRPM Borax #2 T40555 PBU 06-12C 50029204560300 225022 5/15/2025 BAKER MRPM T40556 PBU B-30B 50029215420200 225009 4/9/2025 BAKER MRPM T40557 PBU D-03B 50029200570300 225008 5/2/2025 BAKER MRPM T40558 PBU H-29B 50029218130200 225005 5/7/2025 BAKER MRPM T40559 END 1-25A 50029217220100 197075 5/4/2025 HALLIBURTON MFC40 T40560 END 3-03 50029223060000 192121 5/18/2025 HALLIBURTON PPROF T40561 NS-33A 50029233250100 208189 5/13/2025 HALLIBURTON MFC24 T40562 PBU D-03B 50029200570300 225008 5/2/2025 HALLIBURTON RBT T40558 PBU H-29B 50029218130200 225005 5/7/2025 HALLIBURTON RBT T40559 PBU L-108 50029230900000 202109 5/16/2025 HALLIBURTON IPROF T40563 Please include current contact information if different from above. BRU 244-27 50283201850000 222038 5/15/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.17 11:38:14 -08'00' 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 3. Address: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 7,303 feet 5,905 feet true vertical 6,871 feet 5,433' (fill) feet Effective Depth measured 5,905 feet 2,694 feet true vertical 5,903 feet 2,414 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)Liner Top Pkr; N/A 2,694' MD 2,414' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 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: Chad Helgeson, Operations Engineer 325-119 Sr Pet Eng: 7,500psi Sr Pet Geo:Sr Res Eng: WINJ WAG 2269 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A chelgeson@hilcorp.com 907-777-8405 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 120' 4 202744 0 2702 273 measured TVD 8,430psi 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-038 50-283-20185-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA029657 Beluga River / Sterling-Beluga Gas Beluga River Unit (BRU) 244-27 Plugs Junk measured Length Production Liner 4,609' 2,700' Casing Structural 6,871' 4-1/2" 7,303' 2,700'2,419' 120'Conductor Surface Intermediate 16 7-5/8" 138' 2,898' 7,500psi 2,980psi 6,880psi 8,430psi 2,898'2,589' Burst Collapse 1,410psi 4,790psi p k ft t Fra O s O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:05 pm, Jun 06, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.06.06 14:51:10 - 08'00' Noel Nocas (4361) BJM 9/23/25 RBDMS JSB 061325 DSR-6/18/25 Page 1/1 Well Name: BRU 244-27 Report Printed: 6/2/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-283-20185-00-00 Field Name:Beluga River State/Province:ALASKA Permit to Drill (PTD) #:222-038 Sundry #:325-119 Rig Name/No: Jobs Actual Start Date:2/13/2025 End Date: Report Number 1 Report Start Date 4/8/2025 Report End Date 4/9/2025 Last 24hr Summary PJSM, Crew mob to location, Spot in & rig up, Pick up lube & tool string (1 x wt bar, 1 x CCL/GR, 1 x SS, 1 x 13' x 2" gun), Pressure test 250/2000-good, Run in the hole, Correlate, Perf BEL E6 (4469-4482), Pull out of the hole, Pick up run #2, (1 x wt bar, 1 x CCL/GR, 1 x SS, 1 x 13' x 2" gun) Correlate, Perf BEL E6 (4456- 4469), Pull out of the hole, Pick up & make up run #3 (1 x wt bar, 1 x CCL/GR, 1 x SS, 1 x 3' x 2" gun), Correlate, Perf E5 (4369-4372), Pull out of hole, Pick up & make up run #4 (1 x wt bar, 1 x CCL/GR, 1 x SS, 1 x 3' x 2" gun), Correlate, Perf E3 (4317-4320), Pull out of the hole, Secure well, Rig down for the night. Report Number 2 Report Start Date 4/9/2025 Report End Date 4/10/2025 Last 24hr Summary PJSM, Crew travel to location, Pick up lube & tool string (1 x wt bar, 1 x CCL/GR, 1 x SS, 1 x 2" x 6'), Pressure test 250/2000-good, Run in the hole, Correlate, Perf BEL E3 (4237-4243), Pull out of the hole, Pick up & make up run #2 (1 x wt bar, 1 x CCL/GR, 1 x SS. 1 x 2" x 9'Gun) Run in hole, Correlate, Perf Bel E3 (4224- 4233), Pull out of hole, Pick up & make up run #3 (1 x wt bar, 1 x CCL/GR, 1 x SS, 1 x 2" x 3' gun), Run in the hole, Correlate, Perf BEL E1 (4204-4207), Pull out of the hole, Pick up & make up run #4, Run in the hole, Correlate, Perf BEL E1 (4187-4197), Pull out of the hole, Secure well, Rig down & release AK Eline. Report Number 3 Report Start Date 4/19/2025 Report End Date 4/20/2025 Last 24hr Summary MIRU Ak e-line on BRU 244-27. PT 250/2500, pass. RIH w/GPT and 3.55" drift, tagging at 5370', log to surface, no fluid seen. Run 3ea 2.5" strip guns (4spf) and re -perf Beluga E6 from 4460'-4470', Beluga E2 from 4237'-4240' and 4227'-4230'. Flowing well at 314psi while shooting. No increase in pressure or flow after shots. Secure well, l/d lubricator and SDFN. Report Number 4 Report Start Date 4/20/2025 Report End Date 4/21/2025 Last 24hr Summary Stab lubricator. PT 250/2500, RIH w/ 2-1/2"x10' strip gun, make correlation pass, send pass to town, shift up 1', pull gun into position, shoot Beluga E1 4165'-4175'. Well flowing at 1600 mscf, 308psi, increased to 1650 mscf, 311psi in 15 minutes. POOH. RDMO e-line Report Number 5 Report Start Date 5/14/2025 Report End Date 5/15/2025 Last 24hr Summary PTW/PJSM. Ak Eline spot up and partial rig up. Report Number 6 Report Start Date 5/15/2025 Report End Date 5/16/2025 Last 24hr Summary PTW/PJSM, PT 250/2000. Ran GPT & 2.75" JB, SD @ 5338', no fluid level observed, slight cooling from 5000' - 5338'. Re-Perforated following zones with 2.50" strip guns (4spf), BEL E5 (4369'-4372'), BEL E3 (4317'-4320')BEL E1 (4204'-4207' & 4187'-4191') Report Number 7 Report Start Date 5/19/2025 Report End Date 5/20/2025 Last 24hr Summary PTW/PJSM, MIRU PWL, PT 250/2500 With well flowing ran 4 1/2" BLB(tight), 3.70" G-ring. SD @ 5324' SLM, 5342' KB, work a tight spot and clean up @ 5202' SLM. Make ~15 passes through perfs. _____________________________________________________________________________________ Updated by DMA 05-28-25 SCHEMATIC Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 H10 1 2 3 RKB to GL = 17.6’ PBTD = 7,214’ MD / TVD = 6,784’ TD = 7,303’ MD / TVD = 6,871’ H12 H7 H4 G1 H6 G2-G3 G-4-G5 G7 G8 G9 H2-H3 E1-E3 F1-F10 SL tagged @ 5433’ 2/1/25 4 E5-E6 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8"Surf Csg 29.7 L-80 USS-CDC 6.875”Surf 2,898’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C-HT 3.958”2,694’7,303’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C-HT 3.958”Surf 2,700’ JEWELRY DETAIL No.Depth ID OD Item 1 521’3.958”4.500”VanOil Chemical Injection Mandrel 2 2,694’4.875”6.540”5-1/2” Flex lock V Liner hanger / HRD-E ZXP LTP 3 2,700’3.930”5.630”5-1/2” Bullet Assembly 3.42’ off NO-GO 4 5,905’CIBP set 12/22/22 OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (Cement to surface on 6/3/2022) 4-1/2”TOC @ 2680’ CBL 9/13/22 PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status Top of Pool (CO 802A) 3117’ MD; 2786’ TVD Bel E1 4,165’4,175’3,801’3,811’10'4/20/2025 Open Bel E1 4,187’4,197’3,822’3,832’10'4/9/2025 Open Bel E1 4,187’4,191’3,822’3,826’4'5/15/2025 Open Bel E1 4,204'4,207'3,839’3,842’3'4/9/2025 Open Bel E1 4,204'4,320'3,839’3,953’14’5/15/2025 Open Bel E3 4,224’4,233’3,859’3,867’9'4/9/2025 Open Bel E3 4,227’4,230’3,862’3,864’3’4/19/2025 Open Bel E3 4,237'4,243'3,871’3,877’6’4/9/2025 Open Bel E3 4,237'4,240'3,871’3,874’3’4/19/2025 Open Bel E3 4,317’4,320’3,950’3,953’3'4/8/2025 Open Bel E3 4,317'4,320'3,950’3,053’3’5/15/2025 Open Bel E5 4,369’4,372’4,001’4,004’3'5/15/2025 Open Bel E5 4,381'4,392'4,013'4,024'11'2/28/2024 Open Bel E5 4,425'4,428'4,055'4,058'3'2/28/2024 Open Bel E6 4,456’4,482’4,086’4,112’26'4/8/2025 Open Bel E6 4,460'4,470'4,090’4,110’10'4/19/2025 Open Bel E6 4,496'4,510'4,125'4,139'14'2/28/2024 Open Bel F1 4,560'4,570'4,188'4,198'10'2/28/2024 Open Bel F4 4,597'4,602'4,223'4,229'5'2/28/2024 Open Bel F4 4,644'4,650'4,270'4,276'6'2/28/2024 Open Bel F5 4,662'4,670'4,288'4,296'8'2/28/2024 Open Bel F5 4,676'4,680'4,301'4,305'4'2/28/2024 Open Bel F5 4,697'4,701'4,323'4,327'4'2/28/2024 Open Bel F6 4,708'4,718'4,334'4,344'10'2/28/2024 Open Bel F6 4,708'4,718'4,334'4,344'10'2/27/2024 Open Bel F6 4,728'4,735'4,353'4,360'7'2/27/2024 Open Bel F6 4,755'4,761'4,379'4,385'6'2/27/2024 Open Bel F7 4,842'4,848'4,464'4,468'6'2/27/2024 Open Bel F7 4,858'4,861'4,479'4,484'3'2/27/2024 Open Bel F7 4,886'4,892'4,507'4,513'6'2/27/2024 Open Bel F7 4,924'4,939'4,544'4,559'15'2/27/2024 Open Bel F10 5,021'5,026'4,639'4,643'5'2/27/2024 Open Bel G1 5,072'5,086'4,689'4,703'14'2/27/2024 Open Bel G2 5,101'5,103'4,717'4,719'2'6/30/2023 Open Perforations Continued on Page 2 Page 2 of 2 Updated by DMA 05-28-25 SCHEMATIC Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 PERFORATION DETAIL (Continued from Previous Page) Zone Top MD Btm MD Top TVD Btm TVD FT Date Status Bel G3 5,124' 5,128' 4,740' 4,744' 4' 6/30/2023 Open Bel G3 5,139' 5,145' 4,754' 4,760' 6' 6/30/2023 Open Bel G4 5,155' 5,158' 4,770' 4,773' 3' 2/27/2024 Open Bel G4 5,164' 5,168' 4,779' 4,783' 4' 2/27/2024 Open Bel G5 5,215’ 5,228’ 4,829’ 4,842’ 13’ 12/22/2022 Open Bel G7 5,303' 5,311' 4,915' 4,923' 8' 6/30/2023 Open Bel G8 5,332' 5,340' 4,943' 4,951' 8' 6/30/2023 Open Bel G9 5,356' 5,359' 4,967' 4,970' 3' 6/29/2023 Open Bel H2 5,535’ 5,548’ 5,142’ 5,154’ 13’ 12/22/2022 Open Bel H3 5,582’ 5,587’ 5,188’ 5,193’ 5’ 6/13/2023 Open Bel H3 5,589’ 5,593’ 5,195’ 5,297’ 4’ 6/13/2023 Open Bel H4 5,604’ 5,609’ 5,210’ 5,215’ 5’ 6/13/2023 Open Bel H4 5,632’ 5,637’ 5,237’ 5,242’ 5’ 6/13/2023 Open Bel G4 5,155' 5,158' 4,770' 4,773' 3' 2/27/2024 Open Bel G4 5,164' 5,168' 4,779' 4,783' 4' 2/27/2024 Open Bel H4 5,632’ 5,637’ 5,237’ 5,242’ 5’ 6/13/2023 Open Bel H6 5,707’ 5,712’ 5,310’ 5,315’ 5’ 6/12/2023 Open Bel H6 5,716’ 5,721’ 5,319’ 5,324’ 5’ 6/12/2023 Open Bel H7 5,730’ 5,750’ 5,333’ 5,352’ 20’ 12/22/2022 Open Bel H10 5,850’ 5,855’ 5,450’ 5,455’ 5’ 6/12/2023 Open Bel H10 5,870’ 5,890’ 5,469’ 5,489’ 20’ 11/22/2022 Open Bel H12 5,930’ 5,950’ 5,527’ 5,547’ 20’ 12/21/2022 Plugged Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/08/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250508 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-26 50283201970000 224068 4/15/2025 AK E-LINE Perf BRU 244-27 50283201850000 222038 4/19/2025 AK E-LINE Perf IRU 11-06 50283201300000 208184 4/14/2025 AK E-LINE CIBP PBU S-22B 50029221190200 197051 4/15/2025 AK E-LINE IPROF SRU 231-33 50133101630100 223008 4/13/2025 AK E-LINE CIBP PBU 14-33B 50029210020200 223067 1/22/2025 BAKER MRPM END 1-65A 50029226270100 203312 4/15/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON LDL END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON MFC40 MPU R-105 50029238150000 225017 4/20/2025 HALLIBURTON CAST-CBL NS-19 50029231220000 202207 4/12/2025 HALLIBURTON RBT PBU 06-12B 50029204560200 211115 3/22/2025 HALLIBURTON RBT PBU 07-22A 50029209250200 212085 3/31/2025 HALLIBURTON RBT PBU B-30B 50029215420100 201105 4/9/2025 HALLIBURTON RBT-COILFLAG PBU H-17A 50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU H-29B 50029218130200 225005 5/1/2025 HALLIBURTON RBT PBU J-10B 50029204440200 215112 4/15/2025 HALLIBURTON RBT PBU M-207 50029238070000 224141 4/21/2025 HALLIBURTON IPROF PBU Z-25 50029219020000 188159 4/23/2025 HALLIBURTON IPROF PBU Z-31 50029218710000 188112 4/25/2025 HALLIBURTON IPROF Please include current contact information if different from above. T40372 T40373 T40374 T40375 T40376 T40377 T40378 T40379 T40379 T40380 T40381 T40382 T40383 T40384 T40385 T40386 T40387 T40388 T40389 T40390 BRU 244-27 50283201850000 222038 4/19/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 12:42:44 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz Subject:RE: BRU 244-27 (PTD# 222-038) Sundry # 325-119 Additional perf interval Date:Thursday, April 17, 2025 3:20:00 PM Chad, Hilcorp has approval to add the additional perf interval requested in your email below. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Thursday, April 17, 2025 10:15 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: BRU 244-27 (PTD# 222-038) Sundry # 325-119 Additional perf interval Bryan, We would like to add one additional perf interval to our Sundry # 325-119 in our well BRU 244- 27 (PTD# 222-038). We are currently approved to add perfs in the Beluga E sands from 4187-4471. We would like an additional sand stringer in the Beluga E1 sand package (4165-4178MD, 3800-3813ft TVD). The current shallowest allowable perf TVD from the sundry is 3100’ TVD. All perfs are still with the top of the SBGP, which is 2786’ TVD. Attached is an updated proposed schematic (new sand is highlighted green). Please let me know if we can add this additional sand to our proposed perfs in this well or if you need any additional information. Thanks Chad Helgeson Operations Engineer Kenai Asset Team 907-777-8405 - O 907-229-4824 - C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. 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No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. _____________________________________________________________________________________ Updated by CAH 04-17-25 PROPOSED Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 H10 1 2 3 RKB to GL = 17.6’ PBTD = 7,214’ MD / TVD = 6,784’ TD = 7,303’ MD / TVD = 6,871’ H12 H7 H4 G1 H6 G2-G3 G-4-G5 G7 G8 G9 H2-H3 E5-E6 F1-F10 SL tagged @ 5433’ 2/1/25 4 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8"Surf Csg 29.7 L-80 USS-CDC 6.875”Surf 2,898’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C-HT 3.958”2,694’7,303’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C-HT 3.958”Surf 2,700’ JEWELRY DETAIL No.Depth ID OD Item 1 521’3.958”4.500”VanOil Chemical Injection Mandrel 2 2,694’4.875”6.540”5-1/2” Flex lock V Liner hanger / HRD-E ZXP LTP 3 2,700’3.930”5.630”5-1/2” Bullet Assembly 3.42’ off NO-GO 4 5,905’CIBP set 12/22/22 OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (Cement to surface on 6/3/2022) 4-1/2”TOC @ 2680’ CBL 9/13/22 PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status Top of Pool (CO 802A) 3117’ MD; 2786’ TVD Bel E1 ±4,165’±4,178’±3,800’±3,813’±20 TBD Proposed Bel E1 ±4,187’±4,207’±3,822’±3,842’±20 TBD Proposed Bel E2 ±4,224’±4,243’±3,859’±3,877’±19 TBD Proposed Bel F3 ±4,317’±4,320’±3,950’±3,953’±3 TBD Proposed Bel F5 ±4,369’±4,372’±4,001’±4,004’±3 TBD Proposed Bel E5 4,381'4,392'4,013'4,024'11'02/28/24 Open Bel E5 4,425'4,428'4,055'4,058'3'02/28/24 Open Bel F6 ±4,456’±4,482’±4,086’±4,112’±26 TBD Proposed Bel E6 4,496'4,510'4,125'4,139'14'02/28/24 Open Bel F1 4,560'4,570'4,188'4,198'10'02/28/24 Open Bel F4 4,597'4,602'4,223'4,229'5'02/28/24 Open Bel F4 4,644'4,650'4,270'4,276'6'02/28/24 Open Bel F5 4,662'4,670'4,288'4,296'8'02/28/24 Open Bel F5 4,676'4,680'4,301'4,305'4'02/28/24 Open Bel F5 4,697'4,701'4,323'4,327'4'02/28/24 Open Bel F6 4,708'4,718'4,334'4,344'10'02/28/24 Open Bel F6 4,708'4,718'4,334'4,344'10'02/27/24 Open Bel F6 4,728'4,735'4,353'4,360'7'02/27/24 Open Bel F6 4,755'4,761'4,379'4,385'6'02/27/24 Open Bel F7 4,842'4,848'4,464'4,468'6'02/27/24 Open Bel F7 4,858'4,861'4,479'4,484'3'02/27/24 Open Bel F7 4,886'4,892'4,507'4,513'6'02/27/24 Open Bel F7 4,924'4,939'4,544'4,559'15'02/27/24 Open Bel F10 5,021'5,026'4,639'4,643'5'02/27/24 Open Bel G1 5,072'5,086'4,689'4,703'14'02/27/24 Open Bel G2 5,101'5,103'4,717'4,719'2'06/30/23 Open Bel G3 5,124'5,128'4,740'4,744'4'06/30/23 Open Bel G3 5,139'5,145'4,754'4,760'6'06/30/23 Open Bel G4 5,155'5,158'4,770'4,773'3'02/27/24 Open Bel G4 5,164'5,168'4,779'4,783'4'02/27/24 Open Bel G5 5,215’5,228’4,829’4,842’13’12/22/22 Open Bel G7 5,303'5,311'4,915'4,923'8'06/30/23 Open Bel G8 5,332'5,340'4,943'4,951'8'06/30/23 Open Bel G9 5,356'5,359'4,967'4,970'3'06/29/23 Open Bel H2 5,535’5,548’5,142’5,154’13’12/22/22 Open Bel H3 5,582’5,587’5,188’5,193’5’06/13/23 Open Bel H3 5,589’5,593’5,195’5,297’4’06/13/23 Open Bel H4 5,604’5,609’5,210’5,215’5’06/13/23 Open Bel H4 5,632’5,637’5,237’5,242’5’06/13/23 Open Perforations Continued on Page 2 Page 2 of 2 Updated by CAH 02-27-25 PROPOSED Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 PERFORATION DETAIL (Continued from Previous Page) Zone Top MD Btm MD Top TVD Btm TVD FT Date Status Bel H4 5,632’ 5,637’ 5,237’ 5,242’ 5’ 06/13/23 Open Bel H6 5,707’ 5,712’ 5,310’ 5,315’ 5’ 06/12/23 Open Bel H6 5,716’ 5,721’ 5,319’ 5,324’ 5’ 06/12/23 Open Bel H7 5,730’ 5,750’ 5,333’ 5,352’ 20’ 12/22/22 Open Bel H10 5,850’ 5,855’ 5,450’ 5,455’ 5’ 06/12/23 Open Bel H10 5,870’ 5,890’ 5,469’ 5,489’ 20’ 11/22/22 Open Bel H12 5,930’ 5,950’ 5,527’ 5,547’ 20’ 12/21/22 Plugged Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#2025022 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 14B 50133205390200 222057 4/10/2025 AK E-LINE CBL BRU 241-23 50283201910000 223061 4/7/2025 AK E-LINE Perf BRU 241-26 50283201970000 224068 4/12/2025 AK E-LINE CIBP BRU 244-27 50283201850000 222038 4/8/2025 AK E-LINE Perf MPU B-21 50029215350000 186023 4/7/2025 AK E-LINE LDL MPU C-24A 50029230200100 209134 4/6/2025 AK E-LINE CBL MPU J-25 50029232070000 204073 4/5/2025 AK E-LINE JetCut NCIU A-21 50883201990000 224086 4/4/2025 AK E-LINE Perf NCIU A-18 50883201890000 223033 4/5/2025 AK E-LINE Perf PBU Z-235 50029237600000 223055 4/1/2025 READ InjectiojnProfile HVB 13A 50231200320100 224160 3/16/2025 YELLOWJACKET SCBL HVB 18 50231201210000 225001 4/4/2025 YELLOWJACKET SCBL Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40328 T40329 T40330 T40331 T40332 T40333 T40334 T40335 T40336 T40337 T40338 T40339 BRU 244-27 50283201850000 222038 4/8/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.28 08:42:09 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 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): 7,303'N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi 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 Baker HRD-E ZXP; N/A 2,694' MD/2,414' TVD; N/A 6,871'7,214'6,784' Beluga River Sterling-Beluga Gas Pool 16" 7-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beluga River Unit (BRU) 244-27CO 802A Same 6,871'4-1/2" ~1,673psi 4,609' 5,905' Length April 2, 2025 Tieback 4-1/2" 7,303' Perforation Depth MD (ft): See Attached Schematic 2,980psi 6,880psi 120'120' 2,898' Size 138' 2,898' MD Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 2,700' 8,430psi 2,589' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA029657 222-038 50-283-20185-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY Tubing Grade: chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 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: m n P s 66 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-119 By Gavin Gluyas at 8:17 am, Mar 03, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.02.28 10:44:02 - 09'00' Noel Nocas (4361) A.Dewhurst 05MAR25BJM 3/18/25 DSR-3/10/25 1905 psi -bjm 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.19 10:24:23 -08'00'03/19/25 RBDMS JSB 032125 Well Prognosis Well Name: BRU 244-27 API Number: 50-283-20185-00-00 Current Status: Gas Producer Permit to Drill Number: 222-038 First Call Engineer: Chad Helgeson (907) 777-8504 (O) (907) 229-4824 (C) Second Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8663 (C) Maximum Expected BHP: ~1809 psi @ 4112’ TVD (0.44 psi/ft gradient to bottom perf) Max. Potential Surface Pressure: ~1673 psi (0.03 psi/ft gas to surface) Applicable Frac Gradient: 0.77 psi/ft using 14.8 ppg EMW FIT at the Surface shoe (2898 ft) Shallowest Allowable Perf TVD: MPSP/(0.77-0.1) = 1673 psi / 0.67 = 2,497‘ TVD Top of SBGP (CO 802A): ~3,117’ MD/ ~2,786’ TVD Well Status: Online Producer making 2265 mcfd at 270 psi FTP with 5 bw Brief Well Summary BRU 244-27 is a 2022 grass roots producer drilled and completed in the Beluga G-H sands with an IP of 3700 mcfd when first brought online. Mid-2023 perforations were added uphole in the Beluga G2-G9 sands increasing the rate to over 4MM. The objective of this sundry is to increase productivity by perforating additional Beluga sands within and above the current producing intervals. The E sands have been tested in nearby wells and determined low risk perf adds. Objective: The purpose of this work/sundry is to increase production by adding additional perforations in the Beluga E sands. All sands lie in the BRU SBGP. Notes Regarding Wellbore Condition: x 3-1/2” TOC @ ~2680’ from CBL 9-13-22 x 2.72” GR tagged @ 5433’ on 2-1-25 Procedure 1. RU E-line, PT lubricator to 2000 psi 2. Perforate Beluga sands from the bottom up within the below intervals: Zone Top MD Btm MD Top TVD Btm TVD FT Bel E1 ±4,187’ ±4,207’ ±3,822’ ±3,842’ ±20 Bel E2 ±4,224’ ±4,243’ ±3,859’ ±3,877’ ±19 Bel F3 ±4,317’ ±4,320’ ±3,950’ ±3,953’ ±3 Bel F5 ±4,369’ ±4,372’ ±4,001’ ±4,004’ ±3 Bel F6 ±4,456’ ±4,482’ ±4,086’ ±4,112’ ±26 3. Return well to production. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic Shallowest perf = 3100' TVD -bjm 13.8 ppg EMW FIT -bjm MPSP = 1905 psi per Chad Helgeson email attached. -bjm _____________________________________________________________________________________ Updated by CAH 02-27-25 SCHEMATIC Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 H10 1 2 3 RKB to GL = 17.6’ PBTD = 7,214’ MD / TVD = 6,784’ TD = 7,303’ MD / TVD = 6,871’ H12 H7 H4 G1 H6 G2-G3 G-4-G5 G7 G8 G9 H2-H3 E5-E6 F1-F10 SL tagged @ 5433’ 2/1/25 4 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8"Surf Csg 29.7 L-80 USS-CDC 6.875”Surf 2,898’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C-HT 3.958”2,694’7,303’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C-HT 3.958”Surf 2,700’ JEWELRY DETAIL No.Depth ID OD Item 1 521’3.958”4.500”VanOil Chemical Injection Mandrel 2 2,694’4.875”6.540”5-1/2” Flex lock V Liner hanger / HRD-E ZXP LTP 3 2,700’3.930”5.630”5-1/2” Bullet Assembly 3.42’ off NO-GO 4 5,905’CIBP set 12/22/22 OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (Cement to surface on 6/3/2022) 4-1/2”TOC @ 2680’ CBL 9/13/22 PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status Bel E5 4,381'4,392'4,013'4,024'11'02/28/24 Open Bel E5 4,425'4,428'4,055'4,058'3'02/28/24 Open Bel E6 4,496'4,510'4,125'4,139'14'02/28/24 Open Bel F1 4,560'4,570'4,188'4,198'10'02/28/24 Open Bel F4 4,597'4,602'4,223'4,229'5'02/28/24 Open Bel F4 4,644'4,650'4,270'4,276'6'02/28/24 Open Bel F5 4,662'4,670'4,288'4,296'8'02/28/24 Open Bel F5 4,676'4,680'4,301'4,305'4'02/28/24 Open Bel F5 4,697'4,701'4,323'4,327'4'02/28/24 Open Bel F6 4,708'4,718'4,334'4,344'10'02/28/24 Open Bel F6 4,708'4,718'4,334'4,344'10'02/27/24 Open Bel F6 4,728'4,735'4,353'4,360'7'02/27/24 Open Bel F6 4,755'4,761'4,379'4,385'6'02/27/24 Open Bel F7 4,842'4,848'4,464'4,468'6'02/27/24 Open Bel F7 4,858'4,861'4,479'4,484'3'02/27/24 Open Bel F7 4,886'4,892'4,507'4,513'6'02/27/24 Open Bel F7 4,924'4,939'4,544'4,559'15'02/27/24 Open Bel F10 5,021'5,026'4,639'4,643'5'02/27/24 Open Bel G1 5,072'5,086'4,689'4,703'14'02/27/24 Open Bel G2 5,101'5,103'4,717'4,719'2'06/30/23 Open Bel G3 5,124'5,128'4,740'4,744'4'06/30/23 Open Bel G3 5,139'5,145'4,754'4,760'6'06/30/23 Open Bel G4 5,155'5,158'4,770'4,773'3'02/27/24 Open Bel G4 5,164'5,168'4,779'4,783'4'02/27/24 Open Bel G5 5,215’5,228’4,829’4,842’13’12/22/22 Open Bel G7 5,303'5,311'4,915'4,923'8'06/30/23 Open Bel G8 5,332'5,340'4,943'4,951'8'06/30/23 Open Bel G9 5,356'5,359'4,967'4,970'3'06/29/23 Open Bel H2 5,535’5,548’5,142’5,154’13’12/22/22 Open Bel H3 5,582’5,587’5,188’5,193’5’06/13/23 Open Bel H3 5,589’5,593’5,195’5,297’4’06/13/23 Open Bel H4 5,604’5,609’5,210’5,215’5’06/13/23 Open Bel H4 5,632’5,637’5,237’5,242’5’06/13/23 Open Bel H6 5,707’5,712’5,310’5,315’5’06/12/23 Open Bel H6 5,716’5,721’5,319’5,324’5’06/12/23 Open Bel H7 5,730’5,750’5,333’5,352’20’12/22/22 Open Bel H10 5,850’5,855’5,450’5,455’5’06/12/23 Open Bel H10 5,870’5,890’5,469’5,489’20’11/22/22 Open Bel H12 5,930’5,950’5,527’5,547’20’12/21/22 Plugged _____________________________________________________________________________________ Updated by CAH 02-27-25 PROPOSED Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 H10 1 2 3 RKB to GL = 17.6’ PBTD = 7,214’ MD / TVD = 6,784’ TD = 7,303’ MD / TVD = 6,871’ H12 H7 H4 G1 H6 G2-G3 G-4-G5 G7 G8 G9 H2-H3 E5-E6 F1-F10 SL tagged @ 5433’ 2/1/25 4 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8"Surf Csg 29.7 L-80 USS-CDC 6.875”Surf 2,898’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C-HT 3.958”2,694’7,303’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C-HT 3.958”Surf 2,700’ JEWELRY DETAIL No.Depth ID OD Item 1 521’3.958”4.500”VanOil Chemical Injection Mandrel 2 2,694’4.875”6.540”5-1/2” Flex lock V Liner hanger / HRD-E ZXP LTP 3 2,700’3.930”5.630”5-1/2” Bullet Assembly 3.42’ off NO-GO 4 5,905’CIBP set 12/22/22 OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (Cement to surface on 6/3/2022) 4-1/2”TOC @ 2680’ CBL 9/13/22 PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status Top of Pool (CO 802A) 3117’ MD; 2786’ TVD Bel E1 ±4,187’±4,207’±3,822’±3,842’±20 TBD Proposed Bel E2 ±4,224’±4,243’±3,859’±3,877’±19 TBD Proposed Bel F3 ±4,317’±4,320’±3,950’±3,953’±3 TBD Proposed Bel F5 ±4,369’±4,372’±4,001’±4,004’±3 TBD Proposed Bel E5 4,381'4,392'4,013'4,024'11'02/28/24 Open Bel E5 4,425'4,428'4,055'4,058'3'02/28/24 Open Bel F6 ±4,456’±4,482’±4,086’±4,112’±26 TBD Proposed Bel E6 4,496'4,510'4,125'4,139'14'02/28/24 Open Bel F1 4,560'4,570'4,188'4,198'10'02/28/24 Open Bel F4 4,597'4,602'4,223'4,229'5'02/28/24 Open Bel F4 4,644'4,650'4,270'4,276'6'02/28/24 Open Bel F5 4,662'4,670'4,288'4,296'8'02/28/24 Open Bel F5 4,676'4,680'4,301'4,305'4'02/28/24 Open Bel F5 4,697'4,701'4,323'4,327'4'02/28/24 Open Bel F6 4,708'4,718'4,334'4,344'10'02/28/24 Open Bel F6 4,708'4,718'4,334'4,344'10'02/27/24 Open Bel F6 4,728'4,735'4,353'4,360'7'02/27/24 Open Bel F6 4,755'4,761'4,379'4,385'6'02/27/24 Open Bel F7 4,842'4,848'4,464'4,468'6'02/27/24 Open Bel F7 4,858'4,861'4,479'4,484'3'02/27/24 Open Bel F7 4,886'4,892'4,507'4,513'6'02/27/24 Open Bel F7 4,924'4,939'4,544'4,559'15'02/27/24 Open Bel F10 5,021'5,026'4,639'4,643'5'02/27/24 Open Bel G1 5,072'5,086'4,689'4,703'14'02/27/24 Open Bel G2 5,101'5,103'4,717'4,719'2'06/30/23 Open Bel G3 5,124'5,128'4,740'4,744'4'06/30/23 Open Bel G3 5,139'5,145'4,754'4,760'6'06/30/23 Open Bel G4 5,155'5,158'4,770'4,773'3'02/27/24 Open Bel G4 5,164'5,168'4,779'4,783'4'02/27/24 Open Bel G5 5,215’5,228’4,829’4,842’13’12/22/22 Open Bel G7 5,303'5,311'4,915'4,923'8'06/30/23 Open Bel G8 5,332'5,340'4,943'4,951'8'06/30/23 Open Bel G9 5,356'5,359'4,967'4,970'3'06/29/23 Open Bel H2 5,535’5,548’5,142’5,154’13’12/22/22 Open Bel H3 5,582’5,587’5,188’5,193’5’06/13/23 Open Bel H3 5,589’5,593’5,195’5,297’4’06/13/23 Open Bel H4 5,604’5,609’5,210’5,215’5’06/13/23 Open Bel H4 5,632’5,637’5,237’5,242’5’06/13/23 Open Perforations Continued on Page 2 Page 2 of 2 Updated by CAH 02-27-25 PROPOSED Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 PERFORATION DETAIL (Continued from Previous Page) Zone Top MD Btm MD Top TVD Btm TVD FT Date Status Bel H4 5,632’ 5,637’ 5,237’ 5,242’ 5’ 06/13/23 Open Bel H6 5,707’ 5,712’ 5,310’ 5,315’ 5’ 06/12/23 Open Bel H6 5,716’ 5,721’ 5,319’ 5,324’ 5’ 06/12/23 Open Bel H7 5,730’ 5,750’ 5,333’ 5,352’ 20’ 12/22/22 Open Bel H10 5,850’ 5,855’ 5,450’ 5,455’ 5’ 06/12/23 Open Bel H10 5,870’ 5,890’ 5,469’ 5,489’ 20’ 11/22/22 Open Bel H12 5,930’ 5,950’ 5,527’ 5,547’ 20’ 12/21/22 Plugged 1 McLellan, Bryan J (OGC) From:Chad Helgeson <chelgeson@hilcorp.com> Sent:Tuesday, March 18, 2025 3:07 PM To:McLellan, Bryan J (OGC) Cc:Donna Ambruz Subject:RE: [EXTERNAL] BRU 244-27 (PTD 222-038) perfs Bryan, I am not sure where I got the 14.8 ppg. I must have had a typo on it because I got the depth correct for it. Our drilling report and LOT Form lists it at a 13.83 ppg. I also did not use the 0.04 psi/ft gradient for this well (I thought I changed all of mine recent sundries to new gas gradient), see below for what I have for the top section of the procedure.) Maximum Expected BHP: ~2125 psi @ 5489’ TVD (0.43 psi/ft to deepest perf) Max. Potential Surface Pressure: ~1905 psi (0.04 psi/ft gas to surface) Applicable Overpressure Gradient: 0.72 psi/ft using 13.83 ppg EMW FIT at the Surface shoe (2898 ft) Shallowest Allowable Perf TVD: MPSP/(0.72-0.04) = 1905 psi / 0.68 = 2,801‘ TVD Top of SBGP (CO 802A): ~3,117’ MD/ ~2,786’ TVD The shallowest allowable perf TVD is still above the top of the Pool, so even with these changes are good. Please let me know if we need to resubmit the sundry with these changes. Chad From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, March 18, 2025 8:55 AM To: Chad Helgeson <chelgeson@hilcorp.com> Subject: [EXTERNAL] BRU 244-27 (PTD 222-038) perfs Chad, Wondering where you got the frac pressure of 14.9 ppg for your calculation on this well. I have it at 13.9 ppg from the LOT sent when the well was drilled. See attached. Also, same issue of using the new perfs for MPSP calculation Should use deep perfs unless you have data to support that the pressure in the deep perfs would result in a lower MPSP. 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. DO NOT open links or attachments from UNKNOWN senders. 2 Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/15/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240315 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 12/6/2023 AK E-LINE Cement-JetCut BCU 13 50133205250000 203138 2/11/2024 AK E-LINE CIBP-Perf BCU 19RD 50133205790100 219188 2/20/2024 AK E-LINE Perf-CIBP BRU 232-26 50283200770000 184138 11/26/2023 AK E-LINE GPT-PLUG-PERF BRU 244-27 50283201850000 222038 2/27/2024 AK E-LINE GPT-Perf GP ST 18742 37 (AN- 37) 50733203940000 187109 11/22/2023 AK E-LINE Perf KBU 22-06Y 50133206500000 215044 11/3/2023 AK E-LINE GPT-PERF KBU 42-6 50133205460000 204209 2/16/2024 AK E-LINE Patch PBU L-122 50029231470000 203051 12/7/2023 AK E-LINE Patch NCIU A-12B 50883200320200 223053 12/6/2023 AK E-LINE Perf-GPT NCIU A-17 50883201880000 223031 12/10/2023 AK E-LINE Perf-GPT NCIU B-02 50883200900100 197210 3/9/2024 AK E-LINE GPT-Perf SRU 241-33B 50133206960000 221053 3/6/2024 AK E-LINE GPT-Cmnt-CIBP- Perf Please include current contact information if different from above. T38630 T38630 T38631 T38632 T38633 T38634 T38635 T38636 T38637 T38638 T38639 T38640 T38641 BRU 244-27 50283201850000 222038 2/27/2024 AK E-LINE GPT-Perf Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.18 08:49:06 -08'00' 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 3. Address: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 7,303 feet 5,905 feet true vertical 6,871 feet N/A feet Effective Depth measured 5,905 feet 2,694 feet true vertical 5,903 feet 2,414 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)Liner Top Pkr; N/A 2,694' MD 2,414' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 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: 7,500psi 2,980psi 6,880psi 8,430psi 2,898'2,589' Burst Collapse 1,410psi 4,790psi Production Liner 4,609' 2,700' Casing Structural 6,871' 4-1/2" 7,303' 2,700'2,419' 120'Conductor Surface Intermediate 16 7-5/8" 138' 2,898' measured TVD 8,430psi 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-038 50-283-20185-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA029657 Beluga River / Sterling-Beluga Gas Beluga River Unit (BRU) 244-27 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 120' 1 1006256 0 2880 359 Jake Flora, Operations Engineer 324-058 Sr Pet Eng: 7,500psi Sr Pet Geo:Sr Res Eng: WINJ WAG 505 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 jake.flora@hilcorp.com 907-777-8442 N/A p k ft t Fra O s O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 10:00 am, Mar 12, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.03.11 14:00:28 - 08'00' Noel Nocas (4361) DSR-3/12/24 RBDMS JSB 031424 Page 1/1 Well Name: BRU 244-27 Report Printed: 3/6/2024www.peloton.com Well Operations Summary Jobs Actual Start Date:2/26/2024 End Date: Report Number 1 Report Start Date 2/26/2024 Report End Date 2/27/2024 Operation Crew mobilize to location, Spot in & rig up Report Number 2 Report Start Date 2/27/2024 Report End Date 2/28/2024 Operation PJSM, Crew travel to location, Pick up CCL/GR/GPT & lube stab on, Pressure test 250/2500-good. Run #1 CCL/GR/GPT to 5200', (no fluid) Pull out of hole & lay down GPT Run #2 G-4 sands (5164-'5168 & 5155'-5158') CCL- TS= 10.3, OG rate: 0 OG PSI: 539, 5 min-552, 10 min- 560, 15 min: 564, Post rate: 0, Pull out of the hole & lay down run #1 (2-3/4", 15 gram, 60 deg., 6 spf) Run #3, G-1 (5072'-5086') CCL- TS= 15.5, OG rate: 0 OG PSI: 479, 5 min-485, 10 min- 501, 15 min: 568, Post rate: 0 F-10 Sand (5021'-5026'CCL- TS= 9, OG rate: 0, OG PSI: 536, 5 min-560, 10 min- 563, 15 min: 568, Post rate: 0, Pull out of the hole & lay down run #3, (2-3/4", 15 gram, 60 deg., 6 spf) Run #4, F7 sands (4924-4939) CCL- TS=14.3, OG rate: 0, OG PSI: 617, 5 min-623, 10 min- 628, 15 min: 634, Post rate: 0, Pull out of the hole & lay down run #4 (2-3/4", 15 gram, 60 deg., 6 spf) Run #5, F7 sands (4886-4892) CCL- TS= 15.5, OG rate: 0 OG PSI: 672, 5 min-674, 10 min- 680, 15 min: 686, Post rate: 0, F 7 sands (4858-4861) CCL- TS= 11, OG rate: 0, OG PSI: 686, 5 min-693, 10 min- 704, 15 min: 730, Post rate: 0, Pull out of the hole & lay down run #5 (2-3/4", 15 gram, 60 deg., 6 spf) Run #6, F7 sands (4842-4848) CCL-TS= 15.5, OG rate: 0 OG PSI: 896, 5 min-900, 10 min- 905, 15 min: 910, Post rate: 0. F6 sands (4755-4761) CCL-TS= 11, OG rate: 0 OG PSI: 910, 5 min-916, 10 min- 920, 15 min: 922, Post rate: 0, Pull out of the hole & lay down run #6 (2-3/4", 15 gram, 60 deg., 6 spf) Run #7, F6 sands (4728-4735) CCL- TS= 22.3, OG rate: 0, OG PSI: 954, 5 min-956, 10 min- 958, 15 min: 961, Post rate: 0, F6 sands (4708-4718) CCL- TS= 8.3, (Switches misfired), Pull out of the hole & lay down run #7 (2-3/4", 15 gram, 60 deg., 6 spf) Lay down lube & secure well for the night. Flow well with production. Report Number 3 Report Start Date 2/28/2024 Report End Date 2/29/2024 Operation PJSM, Crew travel to location, Start & warm equipment, Rehead & fix hoses, Pick up GPT & lube, Stab onto well & test to 250/3000-good. Run #1 with CCL/GR/GPT for fluid and & tag @ 5352', Fluid height @ 4340', Pull out of hole & lay down Run #1 Run #2, F6 sands (4708-4718) CCL- TS= 8.3' OG PSI: 956, 5 min-956, 10 min- 960, 15 min: 971, Pull out of the hole & lay down run #2 (2-3/4", 15 gram, 60 deg., 6 spf) Run #3, F5 sands (4697-4701) CCL- TS= 17.5, OG PSI: 1000, 5 min-1000, 10 min- 1001, 15 min: 1001, F5 sands (4676-4680) CCL- TS=10.8',OG PSI: 1002, 5 min-1002, 10 min- 1003, 15 min: 1003, Pull out of the hole & lay down run #3 (2-3/4", 15 gram, 60 deg., 6 spf) Run #4, F5 sands (4662-4670) CCL- TS= 17.5, OG PSI: 1003, 5 min-1003, 10 min- 1003, 15 min: 1003, F4 sands (4644-4650) CCL- TS= 8.3, OG PSI: 1005, 5 min -1005, 10 min- 1005, 15 min: 1005, Pull out of the hole & lay down run #4 (2-3/4", 15 gram, 60 deg., 6 spf) Run #5, F4 sands (4597-4602) CCL- TS= 16, OG PSI: 1008, 5 min-1008, 10 min- 1008, 15 min: 1008, Pull out of the hole & lay down run #5 (2-3/4", 15 gram, 60 deg., 6 spf) Run #6, F1 sands (4560-4570) CCL- TS= 16, OG PSI: 1013, 5 min-1013, 10 min- 1013, 15 min: 1013, Pull out of the hole & lay down run #6 (2-3/4", 15 gram, 60 deg., 6 spf) Run #7, E6 sands (4496-4510) CCL- TS= 15.5,OG PSI: 1015, 5 min-1015, 10 min- 1015, 15 min: 1016, E5 sands (4425-4428) CCL- TS= 11, OG PSI: 1016, 5 min-1005, 10 min- 999, 15 min: 994, Pull out of the hole & lay down run #7 (2-3/4", 15 gram, 60 deg., 6 spf) Run #8, E5 sands (4381-4392) CCL- TS= 12.3, OG PSI: 946, 5 min-934, 10 min- 873, 15 min: 833, Pull out of the hole & lay down run #8 (2-3/4", 15 gram, 60 deg., 6 spf) Secure well & Rig down eline tools & equipment API: 50-283-20185-00-00 Field: Beluga River Sundry #: 324-058 State: Alaska Rig/Service:Permit to Drill (PTD) #:222-038 _____________________________________________________________________________________ Updated by DMA 03-08-24 SCHEMATIC Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 H10 1 2 3 RKB to GL = 18.5’ PBTD = 7,214’ MD / TVD = 6,784’ TD = 7,303’ MD / TVD = 6,871’ H12 H7 H4 G1 H6 G2-G3 G-4-G5 G7 G8 G9 H2-H3 E5-E6 F1-F10 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8"Surf Csg 29.7 L-80 USS-CDC 6.875”Surf 2,898’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C-HT 3.958”2,694’7,303’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C-HT 3.958”Surf 2,700’ JEWELRY DETAIL No.Depth ID OD Item 1 521’3.958”4.500”VanOil Chemical Injection Mandrel 2 2,694’4.875”6.540”Liner hanger / LTP Assembly 3 2,700’4.790”6.340”Seal Stem 4 5,905’CIBP set 12/22/22 OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (Cement to surface on 6/3/2022) 4-1/2”TOC @ 2680’ CBL 9/13/22 PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status Bel E5 4,381'4,392'4,013'4,024'11'02/28/24 Open Bel E5 4,425'4,428'4,055'4,058'3'02/28/24 Open Bel E6 4,496'4,510'4,125'4,139'14'02/28/24 Open Bel F1 4,560'4,570'4,188'4,198'10'02/28/24 Open Bel F4 4,597'4,602'4,223'4,229'5'02/28/24 Open Bel F4 4,644'4,650'4,270'4,276'6'02/28/24 Open Bel F5 4,662'4,670'4,288'4,296'8'02/28/24 Open Bel F5 4,676'4,680'4,301'4,305'4'02/28/24 Open Bel F5 4,697'4,701'4,323'4,327'4'02/28/24 Open Bel F6 4,708'4,718'4,334'4,344'10'02/28/24 Open Bel F6 4,708'4,718'4,334'4,344'10'02/27/24 Open Bel F6 4,728'4,735'4,353'4,360'7'02/27/24 Open Bel F6 4,755'4,761'4,379'4,385'6'02/27/24 Open Bel F7 4,842'4,848'4,464'4,468'6'02/27/24 Open Bel F7 4,858'4,861'4,479'4,484'3'02/27/24 Open Bel F7 4,886'4,892'4,507'4,513'6'02/27/24 Open Bel F7 4,924'4,939'4,544'4,559'15'02/27/24 Open Bel F10 5,021'5,026'4,639'4,643'5'02/27/24 Open Bel G1 5,072'5,086'4,689'4,703'14'02/27/24 Open Bel G2 5,101'5,103'4,717'4,719'2'06/30/23 Open Bel G3 5,124'5,128'4,740'4,744'4'06/30/23 Open Bel G3 5,139'5,145'4,754'4,760'6'06/30/23 Open Bel G4 5,155'5,158'4,770'4,773'3'02/27/24 Open Bel G4 5,164'5,168'4,779'4,783'4'02/27/24 Open Bel G5 5,215’5,228’4,829’4,842’13’12/22/22 Open Bel G7 5,303'5,311'4,915'4,923'8'06/30/23 Open Bel G8 5,332'5,340'4,943'4,951'8'06/30/23 Open Bel G9 5,356'5,359'4,967'4,970'3'06/29/23 Open Bel H2 5,535’5,548’5,142’5,154’13’12/22/22 Open Bel H3 5,582’5,587’5,188’5,193’5’06/13/23 Open Bel H3 5,589’5,593’5,195’5,297’4’06/13/23 Open Bel H4 5,604’5,609’5,210’5,215’5’06/13/23 Open Bel H4 5,632’5,637’5,237’5,242’5’06/13/23 Open Bel H6 5,707’5,712’5,310’5,315’5’06/12/23 Open Bel H6 5,716’5,721’5,319’5,324’5’06/12/23 Open Bel H7 5,730’5,750’5,333’5,352’20’12/22/22 Open Bel H10 5,850’5,855’5,450’5,455’5’06/12/23 Open Bel H10 5,870’5,890’5,469’5,489’20’11/22/22 Open Bel H12 5,930’5,950’5,527’5,547’20’12/21/22 Plugged 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): 7,303'N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi Liner 7,500psi 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 Liner Top Hanger; N/A 2,694' MD/2,414' TVD; N/A 6,871'7,214'6,784' Beluga River Sterling-Beluga Gas 16" 7-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beluga River Unit (BRU) 244-27CO 802 Same 6,871'4-1/2" ~1,704psi 4,609' 5,905' Length February 14, 2024 2,700'2,700' N/A 2,419' 7,303' Perforation Depth MD (ft): 4-1/2" See Attached Schematic 2,980psi 6,880psi 138'138' 2,898' Size 138' 2,898' MD Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 8,430psi 2,589' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA029657 222-038 50-283-20185-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY 8,430psi Tubing Grade: jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 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: m n P s 66 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 2:29 pm, Feb 07, 2024 324-058 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.02.06 19:00:06 - 09'00' Noel Nocas (4361) *Per Well Completion Report filed 1/18/2023 SFD BJM 2/14/24 SFD 2/8/2024 120' * Perforate 10-404 Sterling-Beluga Gas 120' * DSR-2/13/24*&:JLC 2/14/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.14 16:19:52 -06'00'02/14/24 RBDMS JSB 022124 Well Prognosis Well Name:BRU 244-27 API Number:50-283-20185-00-00 Current Status:Gas Producer Permit to Drill Number:222-038 First Call Engineer:Jake Flora (907) 777-8442 (O)(720) 988-5375 (M) Second Call Engineer:Chad Helgeson (907) 777-8420 (O)(907) 229-4824 (M) Maximum Expected BHP: ~2415 psi @ 5489’ TVD (0.44 psi/ft gradient to bottom perf) Max. Potential Surface Pressure: ~1867 psi (Max expected BHP - gas to surface) Well Status: Online Producer making 1000 mcfd at 161 psi FTP with 30 bw Brief Well Summary BRU 244-27 is a 2022 grass roots producer drilled and completed in the Beluga G-H sands with an IP of 3700 mcfd when first brought online. Mid-2023 perforations were added uphole in the Beluga G2-G9 sands increasing the rate to over 4MM. Currently the well is continuing to decline and requires multiple soap drops per day to keep the water unloading. The objective of this sundry is to increase productivity by perforating additional Beluga sands within and above the current producing intervals. Notes Regarding Wellbore Condition: Current Gross Perf Interval: 5101-5890’ MD (4717-5489’ TVD) 12/22/22 perforated Beluga G-H sands 5215-5890’, brought online 06/12/23 perforate H-10 while flowing 06/29/23 perforate G9-G2 while flowing, rate increase if 2.7MM 08/13/23 2.5” DDB to 5854’, course sand 08/16/23 bail with 3” DDB to 5876’ – 5880’, recover course sand Procedure 1. RU E-line, PT lubricator to 2500 psi 2. Perforate Beluga sands from the bottom up within the below intervals: Sand MD TOP MD Base Total Ftg TVD TOP TVD Bot E5 4381 4392 11 4013 4024 E5 4425 4428 3 4055 4058 E6 4496 4510 14 4125 4139 F1 4560 4570 10 4188 4198 F4 4597 4602 5 4223 4229 F4 4644 4650 6 4270 4276 F5 4662 4670 8 4288 4296 F5 4676 4680 4 4301 4305 F5 4697 4701 4 4323 4327 F6 4708 4718 10 4334 4344 F6 4728 4735 7 4353 4360 y perforating additional Beluga sands w ~1867 psi Well Prognosis F6 4755 4761 6 4379 4385 F7 4842 4848 6 4464 4468 F7 4858 4861 3 4479 4484 F7 4886 4892 6 4507 4513 F7 4924 4939 15 4544 4559 F10 5021 5026 5 4639 4643 G1 5072 5086 14 4689 4703 G4 5155 5158 3 4770 4773 G4 5164 5168 4 4779 4783 a. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. b. Frac Calcs: Using 14.8 ppg EMW (0.77 psi/ft) frac gradient at from SC shoe depth c. Shallowest Allowable Perf TVD = MPSP/(0.77-0.1) = 1867 psi / 0.67 = 2786‘ TVD Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic Shallowest Allowable Perf TVD = MPSP/(0.77-0.1) = 1867 psi / 0.67 = 2786‘ TVD Shallowest potential perf -bjm , equivalent to 3,118' MD SFD _____________________________________________________________________________________ Updated by DMA 08-21-23 SCHEMATIC Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 H10 1 2 3 RKB to GL = 18.5’ PBTD = 7,214’ MD / TVD = 6,784’ TD = 7,303’ MD / TVD = 6,871’ H12 H7 H4 G1 H6 G3 G5 G7 G8 G9 H3 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8"Surf Csg 29.7 L-80 USS-CDC 6.875”Surf 2,898’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C-HT 3.958”2,694’7,303’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C-HT 3.958”Surf 2,700’ JEWELRY DETAIL No.Depth ID OD Item 1 521’3.958”4.500”VanOil Chemical Injection Mandrel 2 2,694’4.875”6.540”Liner hanger / LTP Assembly 3 2,700’4.790”6.340”Seal Stem 4 5,905’CIBP set 12/22/22 OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (Cement to surface on 6/3/2022) 4-1/2”TOC @ 2680’ CBL 9/13/22 PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Bel G1 5,101'5,103'4,717'4,719'2'06/30/23 Open Bel G3 5,124'5,128'4,740'4,744'4'06/30/23 Open Bel G3 5,139'5,145'4,754'4,760'6'06/30/23 Open Bel G5 5,215’5,228’4,829’4,842’13’12/22/22 Open Bel G7 5,303'5,311'4,915'4,923'8'06/30/23 Open Bel G8 5,332'5,340'4,943'4,951'8'06/30/23 Open Bel G9 5,356'5,359'4,967'4,970'3'06/29/23 Open Bel H2 5,535’5,548’5,142’5,154’13’12/22/22 Open Bel H3 5,582’5,587’5,188’5,193’5’06/13/23 Open Bel H3 5,589’5,593’5,195’5,297’4’06/13/23 Open Bel H4 5,604’5,609’5,210’5,215’5’06/13/23 Open Bel H4 5,632’5,637’5,237’5,242’5’06/13/23 Open Bel H6 5,707’5,712’5,310’5,315’5’06/12/23 Open Bel H6 5,716’5,721’5,319’5,324’5’06/12/23 Open Bel H7 5,730’5,750’5,333’5,352’20’12/22/22 Open Bel H10 5,850’5,855’5,450’5,455’5’06/12/23 Open Bel H10 5,870’5,890’5,469’5,489’20’11/22/22 Open Bel H12 5,930’5,950’5,527’5,547’20’12/21/22 Plugged _____________________________________________________________________________________ Updated by DMA 01-31-24 PROPOSED Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 H10 1 2 3 RKB to GL = 18.5’ PBTD = 7,214’ MD / TVD = 6,784’ TD = 7,303’ MD / TVD = 6,871’ H12 H7 H4 G1 H6 G3 G5 G7 G8 G9 H3 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8"Surf Csg 29.7 L-80 USS-CDC 6.875”Surf 2,898’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C-HT 3.958”2,694’7,303’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C-HT 3.958”Surf 2,700’ JEWELRY DETAIL No.Depth ID OD Item 1 521’3.958”4.500”VanOil Chemical Injection Mandrel 2 2,694’4.875”6.540”Liner hanger / LTP Assembly 3 2,700’4.790”6.340”Seal Stem 4 5,905’CIBP set 12/22/22 OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (Cement to surface on 6/3/2022) 4-1/2”TOC @ 2680’ CBL 9/13/22 PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status E5 ±4,381'±4,392'±4,013'±4,024'±11'Proposed TBD E5 ±4,425'±4,428'±4,055'±4,058'±3'Proposed TBD E6 ±4,439'±4,444'±4,070'±4,075'±5'Proposed TBD E6 ±4,458'±4,473'±4,088'±4,103'±15'Proposed TBD E6 ±4,496'±4,510'±4,125'±4,139'±14'Proposed TBD F1 ±4,560'±4,570'±4,188'±4,198'±10'Proposed TBD F4 ±4,597'±4,602'±4,223'±4,229'±5'Proposed TBD F4 ±4,644'±4,650'±4,270'±4,276'±6'Proposed TBD F5 ±4,662'±4,670'±4,288'±4,296'±8'Proposed TBD F5 ±4,676'±4,680'±4,301'±4,305'±4'Proposed TBD F5 ±4,697'±4,701'±4,323'±4,327'±4'Proposed TBD F6 ±4,708'±4,718'±4,334'±4,344'±10'Proposed TBD F6 ±4,728'±4,735'±4,353'±4,360'±7'Proposed TBD F6 ±4,755'±4,761'±4,379'±4,385'±6'Proposed TBD F7 ±4,842'±4,848'±4,464'±4,468'±6'Proposed TBD F7 ±4,858'±4,861'±4,479'±4,484'±3'Proposed TBD F7 ±4,886'±4,892'±4,507'±4,513'±6'Proposed TBD F7 ±4,924'±4,939'±4,544'±4,559'±15'Proposed TBD F10 ±5,021'±5,026'±4,639'±4,643'±5'Proposed TBD G1 ±5,072'±5,086'±4,689'±4,703'±14'Proposed TBD Bel G1 5,101'5,103'4,717'4,719'2'06/30/23 Open Bel G3 5,124'5,128'4,740'4,744'4'06/30/23 Open Bel G3 5,139'5,145'4,754'4,760'6'06/30/23 Open G4 ±5,155'±5,158'±4,770'±4,773'±3'Proposed TBD G4 ±5,164'±5,168'±4,779'±4,783'±4'Proposed TBD Bel G5 5,215’5,228’4,829’4,842’13’12/22/22 Open Bel G7 5,303'5,311'4,915'4,923'8'06/30/23 Open Bel G8 5,332'5,340'4,943'4,951'8'06/30/23 Open Bel G9 5,356'5,359'4,967'4,970'3'06/29/23 Open Bel H2 5,535’5,548’5,142’5,154’13’12/22/22 Open Bel H3 5,582’5,587’5,188’5,193’5’06/13/23 Open Bel H3 5,589’5,593’5,195’5,297’4’06/13/23 Open Bel H4 5,604’5,609’5,210’5,215’5’06/13/23 Open Bel H4 5,632’5,637’5,237’5,242’5’06/13/23 Open Bel H6 5,707’5,712’5,310’5,315’5’06/12/23 Open Bel H6 5,716’5,721’5,319’5,324’5’06/12/23 Open Bel H7 5,730’5,750’5,333’5,352’20’12/22/22 Open Bel H10 5,850’5,855’5,450’5,455’5’06/12/23 Open Bel H10 5,870’5,890’5,469’5,489’20’11/22/22 Open Bel H12 5,930’5,950’5,527’5,547’20’12/21/22 Plugged Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/25/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230725 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 222-34 50283201860000 222039 6/29/2023 AK E-LINE Perf-ProductionProfile BRU 223-34 50283201880000 223041 7/14/2023 AK E-LINE CBL/Perf BRU 223-34 50283201880000 223041 7/16/2023 AK E-LINE Perf BRU 244-27 50283201850000 222038 6/30/2023 AK E-LINE Perf END 1-01 50029218010000 188037 7/9/2023 AK E-LINE Plug/Cement END DIU 1-01 50029218010000 188037 7/7/2023 AK E-LINE Cross-Flow-Detect GO 8 50133206510000 215077 7/13/2023 AK E-LINE Perf KBU 33-06X 50133205290000 203183 7/18/2023 AK E-LINE GPT/Patch PBU F-29B 50029216270200 211147 7/8/2023 AK E-LINE CIBP Please include current contact information if different from above. T37872 T37873 T37873 T37874 T37875 T37875 T37876 T37877 T37878 BRU 244-27 50283201850000 222038 6/30/2023 AK E-LINE Perf Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.25 12:04:00 -08'00' 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 3. Address: 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 7,303 feet 5,905 feet true vertical 6,871 feet N/A feet Effective Depth measured 7,214 feet 2,694 feet true vertical 6,784 feet 2,414 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth) Liner Top Pkr; N/A 2,694' MD 2,414' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 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: Jake Flora, Operations Engineer 323-136 Sr Pet Eng: 7,500psi Sr Pet Geo: Sr Res Eng: WINJ WAG 2 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 jake.flora@hilcorp.com 907-777-8442 N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 138' 33 554181 0 41349 305 measured TVD 8,430psi 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-038 50-283-20185-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA029657 Beluga River / Sterling-Beluga Gas Beluga River Unit (BRU) 244-27 Plugs Junk measured Length Production Liner 4,609' 2,700' Casing Structural 6,871' 4-1/2" 7,303' 2,700' 2,419' 138'Conductor Surface Intermediate 16 7-5/8" 138' 2,898' 7,500psi 2,980psi 6,880psi 8,430psi 2,898' 2,589' Burst Collapse 1,410psi 4,790psi p k ft t Fra O s O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:43 am, Jul 14, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.07.13 16:58:02 - 08'00' Noel Nocas (4361) Rig Start Date End Date 6/12/23 6/30/23 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 244-27 50-283-20185-00-00 222-038 06/12/2023 - Monday Company rep catches flight from Kenai to Beluga. Pollard eline crew catches flight from Kenai to Beluga. Eline crew arrives. Checks in and goes over job with Company rep and leads. Eline crew gathers equipment from storage, begins spotting equipment and rig up. PT equipment 300# low and 2500# high. RIH w/ (Gun#1) 5' x 2-7/8" perf gun (GEO Rchrgs - 15 gram - 6 SPF - 60 deg phasing) Tagged TD @ 5867.3. Pulled tie in pass and sent to town. Town approves tie in pass on depth Shot interval 5850' - 5855' (H10 sands) (CCL to TS = 16.9' ) (CCL stop depth = 5833.1') Good ind. of firing. POOH & confirmed all shots fired. ****Bullnose packed full of form sand**** Tbg psi pre shot = 261 / 0 / 0 Tbg psi post shot = 258 / 0 / 0. RIH w/ (Gun#2) 5' x 2-7/8" perf gun (GEO RZR chrgs - 15 gram - 6 SPF - 60 deg phasing). Pulled tie in pass and sent to town. Town approves tie in pass on depth Shot interval 5716' - 5721' (H6 sands) (CCL to TS = 16.9' ) (CCL stop depth = 5699.1') Good indication of firing. POOH & confirmed all shots fired ****Bullnose has some slurry sand mix**** Tbg psi pre shot = 270 / 0 / 0 Tbg psi post shot = 274 / 0 / 0. RIH w/ (Gun#3) 5' x 2-7/8" perf gun (GEO RZR chrgs - 15 gram - 6 SPF - 60 deg phasing). Pulled tie in pass and sent to town. Town approves tie in pass on depth Shot interval 5707' - 5712' (H6 sands) (CCL to TS = 16.9' ) (CCL stop depth = 5690.1') Good indication of firing. POOH & confirmed all shots fired Tbg psi pre shot = 274 / 0 / 0 Tbg psi post shot = 274 / 0 / 0. Laid down equipment for the night. Cont runs on next day Daily Operations: Rig Start Date End Date 6/12/23 6/30/23 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 244-27 50-283-20185-00-00 222-038 Daily Operations: 06/13/2023 - Tuesday Attend morning meeting w/ Beluga team. Fill out permit. Head to location. Rig up equipment. PT 300 low and 2500 high. RIH w/ (Gun#4) 5' x 2-7/8" perf gun (GEO RZR chrgs - 15 gram - 6 SPF - 60 deg phasing). Pulled tie in pass and sent to town. Town approves tie in pass on depth Shot interval 5632' - 5637' (H4 sands) (CCL to TS = 16.9' ) (CCL stop depth = 5615.1') ****BULL NOSE FULL OF FORMATION SAND**** Good indication of firing. POOH & confirmed all shots fired Tbg psi pre shot = 269 / 0 / 0 Tbg psi post shot = 272 / 0 / 0. RIH w/ (Gun#5) 5' x 2-75" perf gun (GEO RZR chrgs - 15 gram - 6 SPF - 60 deg phasing). Pulled tie in pass and sent to town. Town approves tie in pass on depth Shot interval 5604' - 5609' (H4 sands) (CCL to TS = 16.9' ) (CCL stop depth = 5587.1') *****Bullnose has slurry of sand**** Good indication of firing. POOH & confirmed all shots fired Tbg psi pre shot = 267 / 0 / 0 Tbg psi post shot = 267 / 0 / 0. RIH w/ (Gun#6) 4' x 2-7/8" perf gun (GEO RZR chrgs - 15 gram - 6 SPF - 60 deg phasing). Pulled tie in pass and sent to town. Town approves tie in pass on depth Shot interval 5589' - 5593' (H3 sands) (CCL to TS = 17.9' ) (CCL stop depth = 5571.1') Good indication of firing. POOH & confirmed all shots fired Tbg psi pre shot = 273 / 0 / 0 Tbg psi post shot = 273 / 0 / 0. RIH w/ (Gun#7) 5' x 2-7/8" perf gun (GEO RZR chrgs - 15 gram - 6 SPF - 60 deg phasing). Pulled tie in pass and sent to town. Town approves tie in pass on depth Shot interval 5582' - 5687' (H3 sands) (CCL to TS = 16.9' ) (CCL stop depth = 5565.1') Good indication of firing. POOH & confirmed all shots fired Tbg psi pre shot = 266 / 0 / 0 Tbg psi post shot = 269 / 0 / 0 Begin rig down and moving over to 222-34. Rig down completed Rig Start Date End Date 6/12/23 6/30/23 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 244-27 50-283-20185-00-00 222-038 Daily Operations: Moved from 222-34 well. MU GR/CCL, Shock sub, 2-7/8" x 3' (6spf / 60D) perf gun loaded with 15gm GeoDynamic Rzr charges. CCL to top shot - 10' Move to well and PT 250 psi / 2500 psi. Pass. FTP - 276 psi / 2.00 mmcfd Open swab and RIH with Gun #1. Run correlation pass from 5500' to 5000'. Send log to Geo. Confirmed on depth. Position gun at 5346' (CCL depth) and shoot the G9 interval at 5356'-5359'. POOH Initial: 276 psi / 2.12 mmcfd 5 min.: 276 psi / 2.10 mmcfd 10 min.: 277 psi / 2.05 mmcfd 15 min.: 276 psi / 2.10 mmcfd. OOH. All shots fired. Gun bull plug and lower portion of gun full of formation sand. Secure well and SDFN. FTP - 277 psi / 2.60 mmcfd Continue with add perfs next day 06/29/2023 - Thursday Rig Start Date End Date 6/12/23 6/30/23 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 244-27 50-283-20185-00-00 222-038 Daily Operations: 06/30/2023- Friday AK E-line attend morning production meeting with Beluga team. Obtain PTW, hold PJSM and travel to location. RU wire, lubricator, MU Gun gamma ray/CCL, shock sub and arm 2-3/4" x 8' (6spf/60D) perf gun loaded with 15 gm charges. Gun #2 (8') - CCL to top shot = 11' Move to well head and stab on. FTP - 278 psi / 2.6 mmcfd Open swab and RIH. Run correlation pass, send to Geo and confirm on depth. Position gun at 5321' (CCL depth) and perforate the G8 sand interval 5332' - 5340'. POOH. Initial: 278 psi / 2.60 mmcfd 5 min: 278 psi / 2.8 mmcfd 10 min.: 278 psi / 2.7 mmcfd 15 min: 277 psi / 2.60 mmcfd OOH. All shots fired. Dry formation sand in bull plug. MU Gun #3 (8') (CCL T.S. - 11'). Open swab and RIH w/ Gun #3. Run correlation pass, send to Geo and confirm on depth. Position gun at 5292' (CCL) and perforate G7 interval 5303' - 5311'. POOH. Initial: 278 psi / 2.8 mmcfd 5 min: 285 psi / 4.5 mmcfd 10 min: 286 psi / 4.45 mmcfd 15 min: 287 psi / 5.30 mmcfd OOH. All shots fired. Dry sand in bull plug. MU Gun #4 (6') (CCL T.S. - 9'). Open swab and RIH w/ Gun #4. Correlate, send log to Geo and confirm on depth. Position gun at 5130' (CCL) and perforate the G3 interval 5139' - 5145'. POOH Initial: 285 psi / 5.48 mmcfd 5 min.: 287 psi / 5.40 mmcfd 10 min: 286 / 5.30 mmcfd 15 min: 285 psi / 5.5 mmcfd OOH. All shots fired. Wet gun. MU Gun #5 (4') (CCL T.S. - 9'). Open swab and RIH w/ Gun #5. Correlate, send log to Geo and confirm on depth. Position gun at 5115' (CCL) and perforate the G3 interval 5124' - 5128'. POOH. Initial: 286 psi / 5.50 mmcfd 5 min: 286 psi / 5.50 mmcfd 10 min: 286.5 psi / 5.50 mmcfd 15 min: 287 psi / 5.50 mmcfd OOH. All shots fired. Wet gun. MU Gun #6 (2') (CCL T.S. - 9'). Open swaband RIH w/ Gun #6. Correlate, send log to Geo and confirm on depth. Position gun at 5092' (CCL) and perforate the G1 interval 5101' - 5103'. POOH. Initial: 286 psi / 5.50 mmcfd 5 min.: 287.5 psi / 5.7 mmcfd 10 min: 287 psi / 5.8 mmcfd 15 min: 287 psi / 5.70 mmcfd OOH. All shots fired. RD and secure well. Move equipment to D pad. Load tools and crew on Otter and depart Beluga for Kenai. Final FTP - 290 psi / 5.60 mmcfd _____________________________________________________________________________________ Updated by DMA 7-13-23 SCHEMATIC Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 H10 1 2 3 RKB to GL = 18.5’ PBTD = 7,214’ MD / TVD = 6,784’ TD = 7,303’ MD / TVD = 6,871’ H12 H7 H4 G1 H6 G3 G5 G7 G8 G9 H3 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8"Surf Csg 29.7 L-80 USS-CDC 6.875”Surf 2,898’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C-HT 3.958”2,694’7,303’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C-HT 3.958”Surf 2,700’ JEWELRY DETAIL No. Depth ID OD Item 1 521’3.958”4.500”VanOil Chemical Injection Mandrel 2 2,694’4.875”6.540”Liner hanger / LTP Assembly 3 2,700’4.790”6.340”Seal Stem 4 5,905’CIBP set 12/22/22 OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (Cement to surface on 6/3/2022) 4-1/2”TOC @ 2680’ CBL 9/13/22 PERFORATION DETAIL Zone Top (MD)Btm (MD) Top (TVD) Btm (TVD)FT Date Status Bel G1 5,101'5,103'4,717'4,719'2'06/30/23 Open Bel G3 5,124'5,128'4,740'4,744'4'06/30/23 Open Bel G3 5,139'5,145'4,754'4,760'6'06/30/23 Open Bel G5 5,215’5,228’4,829’4,842’13’12/22/22 Open Bel G7 5,303'5,311'4,915'4,923'8'06/30/23 Open Bel G8 5,332'5,340'4,943'4,951'8'06/30/23 Open Bel G9 5,356' 5,359' 4,967' 4,970' 3' 06/29/23 Open Bel H2 5,535’ 5,548’ 5,142’ 5,154’ 13’12/22/22 Open Bel H3 5,582’ 5,687’ 5,188’ 5,291’ 5’06/13/23 Open Bel H3 5,589’ 5,593’ 5,195’ 5,297’ 4’06/13/23 Open Bel H4 5,604’ 5,609’ 5,210’ 5,215’ 5’06/13/23 Open Bel H4 5,632’ 5,637’ 5,237’ 5,242’ 5’06/13/23 Open Bel H6 5,707’ 5,712’ 5,310’ 5,315’ 5’06/12/23 Open Bel H6 5,716’ 5,721’ 5,319’ 5,324’ 5’06/12/23 Open Bel H7 5,730’ 5,750’ 5,333’ 5,352’ 20’12/22/22 Open Bel H10 5,850’ 5,855’ 5,450’ 5,455’ 5’06/12/23 Open Bel H10 5,870’ 5,890’ 5,469’ 5,489’ 20’11/22/22 Open Bel H12 5,930’ 5,950’ 5,527’ 5,547’ 20’12/21/22 Plugged Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/10/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230422 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 214-26 50283200830000 212050 6/2/2023 AK E-LINE PPROF BRU 222-34 50283201860000 222039 6/14/2023 AK E-LINE Perf BRU 244-27 50283201850000 222038 6/13/2023 AK E-LINE Perf KBU 33-06X 50133205290000 203183 6/17/2023 AK E-LINE Patch Paxton 12 50133207100000 223014 6/7/2023 AK E-LINE Perf PBU 18-29C 50029223160300 209055 6/2/2023 AK E-LINE CBL Pearl 10 50133207110000 223028 6/6/2023 AK E-LINE Perf Pearl 11 50133207120000 223032 6/8/2023 AK E-LINE Perf Please include current contact information if different from above. PTD: 190-042 T37810 T37811 T37812 T37813 T37814 T37815 T37816 T37817 BRU 244-27 50283201850000 222038 6/13/2023 AK E-LINE Perf Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.10 13:32:37 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Jacob Flora Cc:Donna Ambruz Subject:RE: BRU 244-27 AOGCC 10-403 323-136 PTD 222-038 (Request for additional perfs withinand below approved range) Date:Thursday, June 8, 2023 9:58:00 AM Attachments:BRU 244-27 7.625in Csg-Fit Test.xls image004.png image005.png Jake, Hilcorp has approval to add the additional perfs requested below, as part of sundry 323-136. Note that the LOT was 13.8 ppg, not 14.8 ppg as you used in your frac calcs below. See attached LOT chart. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Thursday, June 1, 2023 11:29 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: BRU 244-27 AOGCC 10-403 323-136 PTD 222-038 (Request for additional perfs withinand below approved range) Hi Bryan, We would like to request additional perfs to be added to the existing open sundry. They are all below and within the currently approved perf table. Please let me know if you need anything additional- Thanks, Jake Currently approved in Open Sundry 323-136 Request to add to Open Sundry (same top perfs, plus additional and deeper perf adds) Maximum Expected BHP: ~2400 psi @ 5455’ TVD (0.44 psi/ft gradient to bottom perf) Max. Potential Surface Pressure: ~1855 psi (Max expected BHP - gas to surface) Frac Calcs w new/deeper zone for MPSP: a. Frac Calcs: Using 14.8 ppg EMW (0.77 psi/ft) frac gradient at 3600’ TVD (top perf) b. Shallowest Allowable Perf TVD = MPSP/(0.77-0.1) = 1855 psi / 0.67 = 2768‘ TVD The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,303'N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi Liner 7,500psi 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8,430psi6,871'7,303' 8,430psi2,700'2,419' 138' 2,898' Perforation Depth MD (ft): 4,609' 4-1/2"2,700' 4-1/2" 16" 7-5/8" 138' 2,898' 2,980psi 6,880psi 138' 2,589' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6,871'7,214'6,784'~1,704psi 5,905' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA029657 222-038 50-283-20185-00-00 Beluga River Sterling/Beluga Gas Same CO 802 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beluga River Unit (BRU) 244-27 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: N/A N/A March 21, 2023 Liner Top Hanger; N/A 2,694' MD/2,414' TVD; N/A See Schematic See Schematic N/A 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: AOGCC USE ONLY Jake Flora, Operations Engineer jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 m n P s 66 t _ Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 1:48 pm, Mar 07, 2023 323-136 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.03.07 12:19:54 -09'00' Noel Nocas (4361) MDG 3/8/2023 120' MDG x 10-404 120' MDG DSR-3/7/23BJM 3/9/23 GCW 03/09/23JLC 3/9/2023 3/9/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.09 15:59:49 -09'00' RBDMS JSB 030923 Well Prognosis Well Name: BRU 244-27 API Number: 50-283-20185-00-00 Current Status: Gas Producer Permit to Drill Number: 222-038 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (M) Second Call Engineer: Chad Helgeson (907) 777-8420 (O) (907) 229-4824 (M) Maximum Expected BHP: ~2415 psi @ 5489’ TVD (0.44 psi/ft gradient to bottom perf) Max. Potential Surface Pressure: ~1867 psi (Max expected BHP - gas to surface) Well Status: Online Producer making 2400 mcfd at 278 psi FTP with 0 bw Brief Well Summary BRU 244-27 is a 2022 grass roots producer drilled and completed in the Beluga G-H sands with an IP of 3700 mcfd when first brought online. The objective of this sundry is to increase productivity by perforating additional Beluga sands within and above the current producing intervals. Notes Regarding Wellbore Condition: 12/22/22 Perforated Beluga G-H sands 5215-5890’, brought online Procedure 1. RU E-line, PT lubricator to 2500 psi 2. Perforate Beluga sands from the bottom up within the below intervals: Sand MD TOP MD Base Total Ftg TVD TOP TVD Bot E5 4381 4392 11 4013 4024 E6 4496 4512 16 4125 4141 F1 4560 4571 11 4188 4199 F4 4595 4601 6 4223 4229 F4 4644 4650 6 4270 4276 F5 4661 4670 9 4287 4296 F5 4676 4680 4 4301 4305 F5 4697 4701 4 4323 4327 F6 4708 4718 10 4334 4344 F6 4728 4735 7 4353 4360 F6 4755 4761 6 4379 4385 F7 4924 4939 15 4544 4559 F10 5021 5025 4 4639 4643 G3 5124 5128 4 4739 4743 G3 5139 5145 6 4755 4761 G7 5303 5311 8 4915 4923 G8 5332 5340 8 4942 4950 G9 5356 5359 3 4966 4969 G10 5393 5402 9 5003 5012 Well Prognosis a) If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic _____________________________________________________________________________________ Updated by CJD 01-18-23 CURRENT SCHEMATIC Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 H-10 1 2 3 RKB to GL = 18.5’ PBTD = 7,214’ MD / TVD = 6,784’ TD = 7,303’ MD / TVD = 6,871’ H-12 H-7 G-5 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8"Surf Csg 29.7 L-80 USS-CDC 6.875”Surf 2,898’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C-HT 3.958”2,694’7,303’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C-HT 3.958”Surf 2,700’ JEWELRY DETAIL No.Depth ID OD Item 1 521’3.958”4.500”VanOil Chemical Injection Mandrel 2 2,694’4.875”6.540”Liner hanger / LTP Assembly 3 2,700’4.790”6.340”Seal Stem 4 5,905’CIBP set 12/22/22 OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (Cement to surface on 6/3/2022) 4-1/2”TOC @ 2680’CBL 9/13/22 PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Bel G5 5,215’5,228’4,829’4,842’13’12/22/22 Open Bel H2 5,535’5,548’5,142’5,154’13’12/22/22 Open Bel H7 5,730’5,750’5,333’5,352’20’12/22/22 Open Bel H10 5,870’5,890’5,469’5,489’20’11/22/22 Open Bel H12 5,930’5,950’5,527’5,547’20’12/21/22 Plugged _____________________________________________________________________________________ Updated by DMA 02-21-23 PROPOSED Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 H-10 1 2 3 RKB to GL = 18.5’ PBTD = 7,214’ MD / TVD = 6,784’ TD = 7,303’ MD / TVD = 6,871’ H-12 H-7 G-5 E5-G10 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8"Surf Csg 29.7 L-80 USS-CDC 6.875”Surf 2,898’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C-HT 3.958”2,694’7,303’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C-HT 3.958”Surf 2,700’ JEWELRY DETAIL No.Depth ID OD Item 1 521’3.958”4.500”VanOil Chemical Injection Mandrel 2 2,694’4.875”6.540”Liner hanger / LTP Assembly 3 2,700’4.790”6.340”Seal Stem 4 5,905’CIBP set 12/22/22 OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (Cement to surface on 6/3/2022) 4-1/2”TOC @ 2680’ CBL 9/13/22 PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Bel E5-G10 ±4,381 ±5,402’±4,013’±5,012’Proposed TBD Bel G5 5,215’5,228’4,829’4,842’13’12/22/22 Open Bel H2 5,535’5,548’5,142’5,154’13’12/22/22 Open Bel H7 5,730’5,750’5,333’5,352’20’12/22/22 Open Bel H10 5,870’5,890’5,469’5,489’20’11/22/22 Open Bel H12 5,930’5,950’5,527’5,547’20’12/21/22 Plugged 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): Beluga River Field GL: 84.1' BF: N/A 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: 23. BOTTOM 16" X-56 120' 7-5/8" L-80 2,584' 4-1/2" L-80 6,871' 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 Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 00312 0 1/4/2023 24 Flow Tubing 0 3178 N/A31780 N/A N/A N/A 7,303' MD / 6,871' TVD 7,214' MD / 6,784' TVD 584' FSL, 566' FEL, Sec 27, T13N, R10W, SM, AK 961' FSL, 357' FEL, Sec 27, T13N, R10W, SM, AK Choke Size: Surface Per 20 AAC 25.283 (i)(2) attach electronic information 12.6# 2,413' 84# 29.7# 120' Water-Bbl: PRODUCTION TEST 12/1/2022 Date of Test: Oil-Bbl: Flowing *** Please see attached schematic for perforation detail *** Gas-Oil Ratio: AMOUNT PULLED 317374 317589 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. BRU 244-27June 17, 2022941' FNL, 1383' FEL, Sec 34, T13N, R10W, SM, AK 102.6' BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORD 2625747 SETTING DEPTH TVD 2626121 TOP HOLE SIZE Mudlog, LWD (DGR, SP4, CTN, ALD), CBL 9-13-22, Perf, GPT. Sterling-Beluga Gas Pool A029657 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 316530 2624242 50-283-20185-00-00May 31, 2022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 11/22/2022 222-038 / 322-378 N/A PACKER SET (MD/TVD) Conductor 9-7/8" Driven Surface L - 488 sx / T - 160 sx Surface 2,898' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 2,694' 7,303' Surface 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, TUBING RECORD L - 348 sx / T - 90 sx6-3/4" 2,700'4-1/2" Tieback SIZE DEPTH SET (MD) 2,694' MD / 2,413' TVD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment RECEIVED by James Brooks at 2:28PM on 1/18/2023 Completed 11/22/2022 JSB RBDMS JSB 013023 GDSR-2/1/23 222-038 / 322-378 BRU 244-27 WCB 1-24-2025 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval Bel G5 5,215' 4,829' 3201' 2864' 3351' 3007' 3569' 3218' 3716' 3362' 3923' 3564' 4129' 3766' 4514' 4143' 5045' 4662' 5431' 5040' 6201' 5792' 6783' 6362' 6,886' 6,463' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Digital Signature with Date:Contact Email:cdinger@hilcorp.com Contact Phone: 907-777-8389 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: INSTRUCTIONS Bel J2 Bel E Bel F Bel I Bel J Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Reports Authorized Title: Drilling Manager 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. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Bel H ST C ST X1 Bel D 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. Bel G ST A TPI (Top of Producing Interval). Authorized Name and ST B Formation Name at TD: 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. 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 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS No NoSidewall Cores: Yes No Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov 1.18.2023 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.01.18 14:22:10 -09'00' Monty M Myers _____________________________________________________________________________________ Updated by CJD 01-18-23 CURRENT SCHEMATIC Beluga River Unit BRU 244-27 PTD: 222-038 API: 50-283-20185-00-00 H-10 1 2 3 RKB to GL = 18.5’ PBTD = 7,214’ MD / TVD = 6,784’ TD = 7,303’ MD / TVD = 6,871’ H-12 H-7 G-5 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120' 7-5/8"Surf Csg 29.7 L-80 USS-CDC 6.875”Surf 2,898’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C-HT 3.958”2,694’7,303’ 4-1/2"Prod Tieback 12.6 L-80 DWC/C-HT 3.958”Surf 2,700’ JEWELRY DETAIL No.Depth ID OD Item 1 521’3.958”4.500”VanOil Chemical Injection Mandrel 2 2,694’4.875”6.540”Liner hanger / LTP Assembly 3 2,700’4.790”6.340”Seal Stem 4 5,905’CIBP set 12/22/22 OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (Cement to surface on 6/3/2022) 4-1/2”TOC @ 2680’CBL 9/13/22 PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Bel G5 5,215’5,228’4,829’4,842’13’12/22/22 Open Bel H2 5,535’5,548’5,142’5,154’13’12/22/22 Open Bel H7 5,730’5,750’5,333’5,352’20’12/22/22 Open Bel H10 5,870’5,890’5,469’5,489’20’11/22/22 Open Bel H12 5,930’5,950’5,527’5,547’20’12/21/22 Plugged Activity Date Ops Summary 5/31/2022 Rig Accepted at 06:00 on 5-31-22. Waiting on arrival of Quadco Rep (flight delayed), Cont inspecting handling equipment in prep for MU BHA, tear out tank #1 agitator for motor replacement, removed and staged multiple gauges for re-certification by Quadco Rep. Stage 2nd hurricane vac, Welder;fabricated centrifuge cuttings discharge chute. Crew installed same. Quadco Rep calibrated and tested all gas alarms and lights with no issues, then checked and certified 11 different pressure gauges. Re-installed gauges where applicable.;PU and hung joint of 4 1/2" DP in stack, performed diverter function test, measured diverter vent line and installed traffic blockades 75’ from outlet. Performed koomey drawdown test. LD joint. Witness of diverter test waived by both agencies (AOGCC on 5-30-22, BLM on 5-27-22).;PU 6 3/4" motor w/1.5° bend, MU 9 7/8" Kymera bit w/TFA of 1.06. Removed rotary table cover and free'd up table locks. MU IBS, DM, EWR, HOC collars, scribe tools w/RFO of 78.28°, plug in and upload MWD. PU 6 3/4" NM flex DC and XO. Run pumps and check for leaks (ok).;Tag bottom at 131' and spud well. Drill from 131' to 456', rot wob 5K, 503 gpm-923 psi, 50 rpm- 4100 ft/lbs on bott torque, 180 to 350 ft/hr ROP. MW 8.8/vis 111, ECD's at 9.5 ppg, BGG 0 units.;Drill Ahead 9 7/8'' hole Section f/ 456' t/ 1195' WOB 5-8k, 450 gpm 1045 psi SPP, 60 rpm 5500 ft/lbs of torque on bottom 250- 500 ft/hr ROP to get build rates 1'' gravel till 950' then firmed up, MW 8.85 ppg ECD 10 ppg , Distance f/ plan 4.5' 4.22' Low 1.44' Right.;Dragon Boxes Loaded 80 bbls Total Dragon Boxes 80 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 0 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls 6/1/2022 Cont drilling 9 7/8" surface hole from 1195' to 1443'. Sliding wob 4-6K, 427 gpm-1022 psi, 22 to 108 psi diff, 320 ft/hr ROP. Rot wob 1-2K, 442 gpm-1098 psi, 60 rpm-7120 ft/lbs on bott torque, 500 ft/hr ROP, MW 8.9/vis 171, ECD's at 10.1 ppg, BGG 0 units.;Circulate hole clean at 506 gpm-1348 psi, 56 rpm-6263 ft/lbs off bott torque. Sent notifications to AOGCC and BLM on upcoming initial BOP test.;Attempted to pull up hole on elevators, pulling 25 to 30K over, MU topdrive and pumped OOH from 1443' to 820' with no issue, up wt 52 to 55K, 400 gpm-823 psi, no rotary. Then pulled on elevators from 820' to 350', S/O and parked string at 392'.;Hole fill pump failed during trip, MU topdrive and pumped OOH last stand.;Serviced rig and topdrive while Sperry Rep C/O draw works depth encoder (failed just prior to wiper trip). Rig electrician troubleshot hole fill pump and it's bad, start chasing spare pump. Sperry encoder wobbling bad on shaft so removed that and swapped to WITZ for depth encoding.;TIH on elevators from 392' to 1378', dwn wt 35K. Set down twice at 1378', MU topdrive and filled pipe, washed and reamed to bottom at 1443'.;Resumed drilling surface hole from 1443' to TD at 2906' md/2594' tvd. Sliding wob 4-10K, 492 gpm-1492 psi, 131 psi diff, 200 to 400 ft/hr ROP. Rot wob 1-3K, 521 gpm-1604 psi, 65 rpm-9044 ft/lbs on bott torque, 500 down to 250 ft/hr ROP (to allow MWD to obtain better data coming to TD), MW 9.1/vis;101, ECD's at 9.8 ppg. BGG 0 units, max gas 5 units. Replaced trip tank pump while drilling. Distance to plan 5.64' 3.94' High 4.04' Low;Circulate bottoms up, obtain survey on bottom, Flow check well static;Make Wiper trip f/ 2906' t/ 1400' no hole issues, hole took correct fill;Service rig and top drive, grease blocks and crown, clean suction screens 10% packed off, check pulsation dampeners;RIh f/ 1400' t/ 2906' wash last stand to bottom, Pump sweep, no noticable fill;Circulate Sweep around 500 gpm 1700 psi Sweep back 18 bbls late;POOH on elevators f/ 2906' t/ 2001' no hole issues;Dragon Boxes Loaded 405 bbls Total Dragon Boxes 485 bbls Cuttings Totes Loaded 57 bbls Total Cuttings Totes 57 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls 6/2/2022 Cont POOH with directional BHA #1 from 2001' on elevators, up wt 60K, to 365’, LD jars and NM flex DC’s. Plugged in and downloaded MWD then LD remainder of BHA. Kymera bit graded 1-1-ER-G-E-I-PN-TD on cone side, 1-1-ER-G-X-I-PN-TD on PDC side.;Clean and clear rig floor, drain stack, MU run tool and retrieve wear ring, flushed stack, PU and dummy ran and marked surface hanger/landing joint (20.22'). LD hanger, RU Weatherford casing equipment, RU fill up line, staged centralizers and casing, held PJSM.;MU shoe track, filled and checked float equipment (ok), cont PU single in hole with total 74 joints 7 5/8" 29.7# L-80 CDC surface casing, torqued to optimum of 15,500 ft/lbs, to 2875'. MU landing joint and hanger, S/O and land hanger putting shoe at 2897'. No issues RIH. Up wt 78K, dwn wt 40K.;Decision made to waiting on additional cement coming on morning barge. Notified cementers and AOGCC Rep. MU topdrive and circ swedge on landing joint. Eased into circulation staging up to 241 gpm-0 psi, alternating with a slower gpm of 118 gpm-0 psi.;Cont. working pipe evert 15 min, shut down circulation, static loss rate 1.8 bph, at 0300 CBU staging pumps t/ 216 gpm 0 psi no change in cuttings on bottoms up, 74k PUW 44k SOW, MW 9.05 ppg OFF load excess mud f/ pits t/ ISO in preparation for cement job Cementers on location to begin rigging up;Dragon Boxes Loaded 80 bbls Total Dragon Boxes 565 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 57 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: BRU 244-27 Beluga River Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00035 BRU 244-27 Drilling Spud Date: Cont drilling 9 7/8" surface hole from 1195' to 1443'. g gqp cont PU single in hole with total 74 joints 7 5/8"p g g qp ()g j 29.7# L-80 CDC surface casing, torqued to optimum of 15,500 ft/lbs, to 2875'. MU landing joint and hanger, S/O and land hanger putting shoe at 2897'. 6/3/2022 Cont circ 7 5/8” casing at 66 gpm-0 psi, waiting on barge to deliver the bulk cement truck. Up wt 70K, down wt 45K. Spotted pump unit and one bulk truck, RU to cement line in sub base. Had bulk truck on location at 08:30, spotted and held PJSM.;Broke off topdrive and circ swedge, loaded plugs and MU launcher on stump while cementers batched up spacer and primed pumps. MU standpipe cement hose to plug launcher.;Halliburton loaded lines with 5 bbls water and checked for leaks. Halliburton pressure tested lines at 300 psi low 4000 psi high, good tests. Halliburton pumped 58 bbls 10.5 ppg Tuned Spacer at 4 bpm-190 to 136 psi, dropped bottom plug and pumped 193 bbls (488 sx) 12 ppg Type I II lead cement at 4;4 bpm-200 to 193 psi, followed by 33.5 bbls (160 sx) 15.8 ppg Type I II tail cement at 4 bpm-360 to 318 psi. Halliburton dropped top plug, then displaced with 9.1 ppg Spud Mud at 4 bpm-130 to 730 psi. Slowed pump to 2 bpm with 20 bbls to go. Did bump the plug at 125 bbls into displacement;(calculated 129 bbls). Held 1541 psi (FCP of 722 psi) for 3 minutes, bled off and floats held. Bled back .75 bbls back to truck. Had 58 bbls of Spacer returns to surface and 95 bbls lead cement to surface. Added LCM to lead cement at 2.4 ppb (Bridge Maker). Mix water temp 60 deg. Pumped 100% excess;on lead and 50% tail. Lost 2 bbls throughout the job. Did reciprocate string until lead cement well on it’s way up backside. Up wt 60K, dwn wt 40K. CIP at 11:51, 6/3/2022. Washed up, RD and released Halliburton.;Broke off plug launcher and LD, BO landing joint, flushed inside with water hose and LD. MU johnny whacker on joint of DP, MU topdrive, flushed stack and hanger top with black water. LD joint and johnny whacker, drained stack.;PU landing joint, MU packoff assembly, landed same, pulled inspection plug and verified landed properly, wellhead Rep RILD's, LD landing joint, Wellhead Rep tested packoff seal at 3000 psi for 15 minutes, good test.;ND diverter vent line, anchor blocks and knife valve. Spotted crane, folded over beaver slide, picked annular then diverter "T" and DSA from cellar entrance. Staged 11" 5M x 16 3/4" 3M "B" section with crane and transfered/set that with bridge cranes. Staged BOP stack, raised and RU on crane,;flew and staged stack at cellar entrance. Transferred BOP stack to bridge cranes. Released crane. Updated AOGCC Rep for initial BOP test in the morning and made flight arrangements.;M/U and N/U BOP stack, bolt up BOP stack and tighten flanges, Test pack of seals and void to 3000 psi f/ 15 min, M/U choke and kill lines, install flow box and flow lines, tighten bolts on flanges, open rams doors and clean cavities. Prep rams to be installed;Install 4.5'' Solid body rams, and blinds, M/U gas separator hose, function test rams, Fill stack and lines with water, Shell test Rams t/ 5000 psi and Annular t/ 3500 psi, tighten leak on flange below single gate, retest no leaks, Clean and organize pad, Build KCL Polymer Mud in premix;Dragon Boxes Loaded 320 bbls Total Dragon Boxes 885 bbls Cuttings Totes Loaded 18 bbls Total Cuttings Totes 75 bbls ISO Tanks Loaded 312 bbls ISO Tanks Total 312 bbls Losses Downhole 8 bbls Total Losses Downhole 8 bbls 6/4/2022 Cont cleaning and organizing while waiting for AOGCC Rep to arrive in Beluga. Started another shell test just prior to Rep’s arrival (08:15).;Found blind ram and upper ram shaft seals leaking out weep holes. Bled down and functioned rams numerous times, pulled test joint and tested at 5000 psi with no leaks in ram shaft seals.;Installed test joint and tested against bag at 3500 psi, upper ram seal no longer leaking, blind ram seal still occasional drip but would not hold 3500 psi. Also found a leak in choke house on 90° block, on top portion of choke manifold. Could not remove 90° block without choke house roof removal.;Quadco Rep arrived, tested all audio/visual alarms with State Rep witness, called out crane to remove choke hose roof. AOGCC Rep decided to fly back to town while BOP repairs made. Released Quadco Rep and Wellhead Rep. State Rep will stand by in Anchorage for call out.;LD test joint, drain stack and choke line. Removed choke house roof then used crane to pick 90° block from choke manifold. Opened blind ram doors, dis-assembled ram shaft seal assembly. Cleaned all components then re-assembled shaft seal assembly with new seals. Re-assembled choke manifold.;Flood surface lines and stack, function rams, install test joint and function bag. Shut in kill/choke lines and test annular with no weep hole issues, got good high test on annular. Shell test choke manifold. Attempt test on IBOP on topdrive, hydraulic valve failed. Change out IBOP while state Rep;traveled to field.;AOGCC Rep Adam Earl on location at 21:00, Test BOP's w/ 4.5'' Test jt t / 250 psi Low 5 min / 5000 psi high 10 min, Test Annular t/ 3500 high f/ 10 min, Test CMV 1-13, TIW and Dart, Auto and Man IBOP, HCR and Man choke and Kill valves, Upper lower and blind rams, kill line demco, Electric and Man;choke valves, Gas Alarms and PVT's tested, Perform Accumulator drawdown test 36 sec on 200 psi and 95 sec full pressure, Had 3 FP Ram shaft seals leaking replace and retested, Choke API ring leaking replace and retest, LPR - High test bleeding down, Bled pressure off and retested High test suspected;Air BLM Rep Allie Schoessler waived witness of initial BOP test on 6-2- 22 at 09:25;Pull test plug and set wear ring, R/U to test casing, fill stack;Test casing t/ 3500 psi f/ 30 min good test pumped 72.5 gallons in bled 72.5 gallons back;Clean and clear rig floor, Blow down lines, R/D test equipment, P/U BHA components;P/U BHA as per DD/MWD, M/U Bit ,Motor, MWD tools, Downloading MWD;Dragon Boxes Loaded 0 bbls Total Dragon Boxes 885 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 75 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 312 bbls Losses Downhole 0 bbls Total Losses Downhole 8 bbls 6/5/2022 Cont PU and MU directional BHA #2 to TM collar, MU topdrive and plugged in to upload MWD. ALD wouldn't communicate. L/D CTN-ALD collar, MU new tools, plugged in and uploaded same. shallow pulse tested and loaded sources. Cont MU BHA for a total length of 738.7’.;PU singled in hole 62 joints 4 1/2" CDS-40 DP to 2660’, RIH on stands to 2780’, filled pipe and shut down pump. S/O and tagged stringer at 2800’ (FC at 2819’). Up wt 56K, dwn wt 36K.;Pumping at 221 gpm-1262 psi, 44 rpm-7419 ft/lbs torque, washed and reamed down engaging wiper plugs at 2817’. Drilled shoe track, rat hole and 20' new formation to 2925'. 5 to 6K wob in new formation.;CBU at 230 gpm-1473 psi, 44 rpm-7700 ft/lbs off bott torque and prep to displace well to KCL mud.;Displace well over to 6% KCL mud at 192 gpm-670 psi.;With good KCL mud to surface, shut down and LD single. Pulled up hole and parked string inside surface casing. Lined up on kill line and down drill string simultaneously. Rolled pump to purge air from kill line. Down pump, closed upper rams. RU test pump and chart recorder on kill line. Pumped 28.75;gallons with test pump to achieve 775 psi, shut down and monitored pressure for 10 minutes. Bled to 540 psi over 10 minutes and bled back 23.5 gallons off well. Pressure broke over at +/- 650 psi giving us a 13.83 EMW with 15 bbls of kick tolerance at TD. Notified Drilling Engineer and approved to;drill ahead. RD test equipment while prepping pits/shakers for drilling.;Made hook and resumed drilling 6 3/4" production section, from 2925' to 3341', sliding wob 7K, 229 gpm-1022 psi, 100 psi diff, 120 ft/hr ROP. Rot wob 1-2K, 231 gpm-965 psi, 45 rpm-7350 ft/lbs on bott torque, 119 ft/hr ROP. MW 9.0/vis 45, ECD's at 9.7 ppg, BGG 0 units.;Drill Ahead 6 3/4'' hole section f/ 3341' t/ 3773' 240 gpm 1152 psi SPP 4-7k WOB Diff 120 psi, 130 ROP 760 ft/lbs of torque on bottom 9 ppg MW p.7 ppg ECD, PUW 60k SOW 42k ROT 50k ,Distance to plan 7.34' 1.32' Low 7.22' Left;Dragon Boxes Loaded 85 bbls Total Dragon Boxes 970 bbls Cuttings Totes Loaded 54 bbls Total Cuttings Totes 129 bbls ISO Tanks Loaded 104 bbls ISO Tanks Total 414 bbls Losses Downhole 0 bbls Total Losses Downhole 8 bbls p 13.83 EMW with 15 bbls of kick tolerance at TD pg Halliburton pumped 58 bbls 10.5 ppg Tuned Spacer at 4 bpm-190pppgg pp ppg p p to 136 psi, dropped bottom plug and pumped 193 bbls (488 sx) 12 ppg Type I II lead cement at 4;4 bpm-200 to 193 psi, followed by 33.5 bbls (160 sx) 15.8 ppgppp pgpp ( )ppgyp p p y()pp Type I II tail cement at 4 bpm-360 to 318 psi. Halliburton dropped top plug, then displaced with 9.1 ppg Spud Mud at 4 bpm-130 to 730 psi. Slowed pump to 2 yp p p pp p p g p ppg p p ppp bpm with 20 bbls to go. Did bump the plug at 125 bbls into displacement;(calculated 129 bbls). Held 1541 psi (FCP of 722 psi) for 3 minutes, bled off and floatspgppg p( )p(p) held. Bled back .75 bbls back to truck. Had 58 bbls of Spacer returns to surface and 95 bbls lead cement to surface. Added LCM to lead cement at 2.4 ppbp (Bridge Maker). Mix water temp 60 deg. Pumped 100% excess;on lead and 50% tail. Lost 2 bbls throughout the job Cont circ 7 5/8” casing at 66 gpm 6/6/2022 Cont drilling 6 3/4" hole from 3773' to 3960'. Rotating wob 2-3K, 231 gpm-1229 psi, 60 rpm-9000 ft/lbs on bott torque, 120 to 125 ft/hr ROP, MW 9.0/vis 44, ECD's at 9.9 ppg, BGG 26 units, max gas 135 units.;CBU twice at 242 gpm-1119 psi, 80 rpm-9226 ft/lbs off bott torque. Up wt 56K, dwn wt 50K while pumping and rotating. Obtained on bottom survey and SPR's.;Pulled up hole on elevators one stand and flow checked, very slight seepage, cont pull up hole from 3960', 17 stands to 2909'. Up wt 70K, dwn wt 35K. Calculated hole fill 9.6 bbls, actual hole fill 9 bbls. No issues pulling at all.;Serviced rig and topdrive. Cleaned suction screens on both mud pumps. Loaded trailer with mud product at staging area for upcoming possible losses.;PU and singled in hole with 12 jnts CDS-40 DP from 2909' to 3338'. Cont TIH on stands to 3897', MU topdrive and filled pipe. Washed to bottom at 3960' with no issues during trip.;Made hook, started 22 bbl hi-vis nutplug sweep down drill string and resumed drilling ahead from 3960'. Sweep back on time and had 100% increase in cuttings. Rotating wob 1-2K, 220 gpm- 1109 psi, 65 rpm-8801 ft/lbs on bott torque, 120 ft/hr ROP, MW 9.1/vis 46,ECD's at 9.8 ppg, BGG 22, max gas 186.;At 4164'md/3798' tvd our return flow rate dropped from 21% to 8%. Reduced pump rate from 220 gpm to 185 gpm and slowed ROP from 120 to 110 ft/hr. Cont drilling ahead, return flow back up to 15%. Built a 25 bbl-50 ppb LCM pill consisting of baracarb 5, 25, 50 and couple sacks nutplug on standby.;Flow rate continued to be up and down while slowly drilling ahead, wob 2-3K, reduced pump rate to 162 gpm-933 psi, 53 rpm-8900 ft/lbs on bott torque, 50 to 100 ft/hr ROP, ECD's at 9.6+. At 4262' return flow dropped to 1%, at 4266' return flow back up to 14%. Brought on water in pre-mix for building;volume with 30 ppb background LCM. At 4292' return flow dropped to 1% again drilling at 159 gpm and 15 ft/hr ROP. At 4300' we lost return flow completely but hole staying full. Backreamed up to 4263' and getting 9% returns. Eased back down and flow dropped off to 4%. Down to 130 bbls in active.;During all this, on the shakers we were seeing very fine ground coal at times, then sand at times.;Backreamed up hole full stand and pumped 22 bbls LCM pill and chased it out the drill string at 130 gpm-491 psi, 55 rpm-9000 ft/lbs off bott torque. Getting 5 to 6% return flow.;Pulled up hole from 4265' on elevators, up wt 80K with an occasional 20 to 25K overpull. Stopped at 4012' and flow checked. slight loss, Continued POOH on elevators to inside shoe @ 2835' no hole issues Hole took correct fill.;Build KCL Polymer mud as per Mud Engineer, Monitor well on trip tank 1.5 BPH initial loss rate final .4 bph loss rate, Build 930 bbls of mud;RIH f/ 2835' t/ 4302' Pill pipe seen loss zone @ 4164' took 10k to work through;CBU stage pumps t/ 178 gpm full returns 990 psi SPP 44 rpm 8.8k tq;Cycle Pumps f/ MWD ADL quit working, unable to restart, discuss w/ engineer continue drilling ahead;Drill ahead 6 3/4'' Hole section f/ 4302' t/ 4328' w/ reduced ROP of 40 FPH and flow rate of 190 gpm 960 psi 45 rpm 8.7k tq on bottom, Full returns, Distance to plan 2.06' 1.48' Low 1.42' Left;Dragon Boxes Loaded 160 bbls Total Dragon Boxes 1130 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 129 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 414 bbls Losses Downhole 390 bbls Total Losses Downhole 398 bbls 6/7/2022 Cont drilling the 6 3/4" hole from 4329' to 4516'. Rot wob 1-2K, 190 gpm-962 psi, 50 rpm-8718 ft/lbs on bott torque, 40 ft/hr ROP, MW 9.1/vis 52, ECD's at 9.9 ppg, BGG 7 units. Reduced pump rate to 30 spm-82 gpm on down stroke to reduce chance of surging.;At 4379' the return flow started dropping from 19% to 15%. At 4441' we had rot wob of 2-3K, 187 gpm-963 psi, 50 rpm-8800 ft/lbs on bott torque, 38 ft/hr ROP. At 4470' return flow dropped from 15% to 8%. We reduced pump rate to 165 gpm-772 psi, 50 rpm-9200 ft/lbs on bott torque, 37 ft/hr ROP.;Flow increased to 12% at 4473' and held there to 4516'. At this point we had lost +/- 282 bbls from 6am to 11:30am and have been unable to obtain surveys after connections (issues with DM collar and ALD collar, suspect battery problems).;At 4516' CBU at 170 gpm-751 psi, 50 rpm-9030 ft/lbs off bottom torque. Up wt 84K, dwn wt 62K with no rotary. Obtained SPR's then pumped 11 bbls of 50 ppb LCM pill and chased with 62 bbls of mud to clear pill from drill pipe at 121 gpm-558 psi.;Pulled up hole on elevators from 4516' to 4072' with no issues, slowly. Up wt 88K. Planned to cycle pumps and try to get Sperry tools working at this depth above top of loss zone, and possibly squeeze LCM pill with pump surges. MU topdrive.;Cycled pump as per Sperry MWD, at 220 gpm, seeing 23% flow with little to no losses and were getting good surveys, cycling pump at 40 second intervals. Notified Drilling Engineer, decision made to TIH and try to get missed surveys, then cont. drilling ahead. C/O choke house sensor on standpipe and;voltage regulator on office generator. Had issues getting comm's back up and running after gen set was re-started, but got back on line.;TIH slow from 4072' to 4330' with no issues. Stopped there, MU topdrive and attempted to survey with no luck. Cycled pump and tried 185, 220 and 260 gpm. No losses observed but no survey obtained. Notified Drilling Engineer, decision made to POOH for directional tools swap.;POOH on elevators F/4330'-T/738'. Calculated hole fill during the trip. P/U-80K S/O-48K;Racked back HWDP, jars, and NM flex DC's. Held PJSM on handling sources. Removed sources, down loaded data. L/D MWD tools, drained motor, inspected 6.75" bit. Bit grade 1-2-CT-S-X-I-NO-DTF;Performed rig service- Greased TD, blocks, IR, DWKS, crown, and wash pipe.;M/U BHA #3 as per Sperry. RR 6.75" bit and motor, DM, PCG, changed out ADR collar. RR ALD, CTN, PWD, and changed out TM HOC.;Crew change, held PTSM. Cont. M/U BHA #3, uploaded data, performed shallow pulse test GPM-185 SPP-533 psi (ok). Held PJSM on handling sources, installed sources. M/U remainder of BHA #3- Flex collars, HWDP, and jars. (installed new corrosion ring in top of flex collars).;Cont. RIH on elevators out of the derrick F/738' to current depth of 3955'. P/U-95K S/O-62K. Distance to well plan: 2.36' 2.24' Low .75' Left;Dragon Boxes Loaded 80 bbls Total Dragon Boxes 1210 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 129 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 414 bbls Losses Downhole 347 bbls Total Losses Downhole 745 bbls 6/8/2022 CBU at 3958', 170 gpm-668 psi, 20 rpm-6100 ft/lbs off bott torque, seeing no losses. Cont RIH to 4290'.;At 4290' MU topdrive, filled pipe, Mad Passed going in hole at 180 ft/hr, down to 4516', 162 gpm- 644 psi, 44 rpm-8395 ft/lbs off bott torque, no losses.;Eased into drilling ahead the 6 3/4" hole from 4516' to 4590', wob 1-2K,197 gpm-848 psi, 50 rpm-9265 ft/lbs on bott torque, 35 to 40 ft/hr ROP and seeing no losses.;Cont drilling from 4590' to 4907'. Rot wob 1-2K, 200 gpm- 965 psi, 55 rpm-9250 ft/lbs on bott torque, 40 ft/hr ROP, 18% flow, MW 9.2/vis 48, ECD's at 9.9 ppg, BGG 12 units, max gas 66 units. At 4643' = 210 gpm-50 ft/hr, at 4703' = 212 gpm-60 ft/hr, at 4772' = 212 gpm-70 ft/hr, at 4825 =80ft/hr.;Cont drilling from 4907' to 5150', 225 GPM, SPP- 1220 PSI, 60-70 RPM, 10.2K on BTM TQ, WOB 2-3K, 90 ft/hr ROP, 20% flow, Max gas 130 units with 7-13 units of BBG, MW 9.2 PPG/vis 49, ECD 's at 10.1 PPG. P/U= 120K, S/O= 70k, ROT= 90K.;Cont. drilling from 5150' to 5246' , 200 GPM, SPP -937 PSI, 50 RPM, 9.5K on BTM TQ, WOB 2K, 40 ft/hr ROP, 18% flow, Max gas 50 units with 7- 13 units of BBG, MW 9.2 PPG, ECD's at 10.3 PPG, P/U= 110K, S/O= 68K, ROT= 80K.;At 5246' MD/4859' TVD encountered losses with no returns, P/U slowed pumps to 100 GPM, 35 RPM's with no returns well staying full. Initial losses 20 BBLS, Rack back std to 5200'.;Pump 15 BBL/ 50 PPG LCM pill and spot out side bit, 70 GPM, SPP- 290 PSI while continuing to work pipe.;POOH from 5200" to 4819' allowing pill to soak, P/U= 120K, S/O= 65K, Disp. Cal= 1.8 BBLS, Disp. Act= 2.1 BBLS, Loss= .3 BBLS, monitor well on TT with 5.1 BPH static loss rate. Attempt to pump at pump idle with no returns observed.;Made decision to POOH to get above initial loss zone from 4819' to 4113', PU= 105K, SO= 62K.;Pumped and spotted 15 BBL LCM pill with 50 PPB LCM, GPM 72, SPP- 286 PSI, flow 0%.;POOH from 4113' to 3767', PU=100K, SO= 60K. Monitored well on TT while allowing 2nd pill the soak. Currently performing rig service at report time. Distance to well plan: 6.43' 5.67' Low 3.03' Left.;Dragon Boxes Loaded 0 bbls Total Dragon Boxes 1210 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 129 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 414 bbls Losses Downhole 0 bbls Total Losses Downhole 745 bbls 6/9/2022 Bit parked at 3767’, cont monitor well on trip tank with an initial 2.4 bph loss rate that reduced to .6 bph. Rolled mud pump up to 118 gpm with trace of returns. Back on trip tank and building a 60 ppb LCM pill and a 150 bbl batch of new mud at 25 ppb background LCM. Working pipe on occasion, up wt;95K, dwn wt 60K. Rolled rig pump again and pumped away 10 bbls with little to no returns.;Eased in hole from 3767' to 4261', did not see anything at 4261' where we previously set down 10K on LCM scab. At 4261' we MU topdrive, lined up and pumped 21 bbls of 60 ppb LCM pill at 70 gpm-278 psi, then chased with 6% KCL mud to spot outside of drill string. Lost 80 bbls spotting pill.;Pulled up hole slowly from 4261' and had a 10K overpull at 4168' (possible LCM scab), up wt 100K on elevators. Pulled to surface casing and parked with bit outside surface shoe at 2939' (shoe depth = 2897').;Allow pill to soak, replaced alternator on camp gen set and PM'd topdrive. Made arrangements for cementers to fly to Beluga, gave BLM 72 hour notice for upcoming weekly BOP test, prepped cementing BHA components. Well on TT with 7% flow, shut off pump and fluid dropped in well bore 3'. 18 bph losses;Rolled rig pump initially at 80 gpm-306 psi, 7% flow. At 132 gpm-491 psi, 10% flow. CBU with a max of 87 units gas at bottoms up, then shut down to monitor on trip tank. Lost 12 bbls during CBU. Seeing no losses after circ and on trip tank.;Rolled pump at 160 gpm-593 psi 17% flow, increased to 182 gpm-656 psi, 18% flow. MWD not getting detection. Cycled pump and increased to 223 gpm-901 psi, 21% flow and getting detection, ECD's at 9.8 ppg. CBU at this rate and lost another 1.5 bbls. Shut and flow check = static.;POOH from 2939', no issue pulling into surface casing at 2897'. At 738' racked back HWDP and jars.;Racked back NM Flex DC's, removed sources and perform download. L/D remaining BHA ( Bit Grade - 1-2-CT-S-X-NO-HP- 1/16 Under ).;Clear and clean rig floor, pick up and measure upcoming BHA .;Make up 6.75" Tri-cone bit, Bit sub ( Float ), Integral Blade stab, XO's , jars and HWDP, RIH to 750' , PU=31K, SO= 30K.;Cont. RIH on 4.5" DP from 750' to 4278' filling pipe at 2733', at 112 GPM, SSP- 46 PSI, 11% flow, from 4164' to 4243' observed multiple spots with 5-15K drag, PU= 88K, SO= 60K, Disp. Cal= 81.3 BBLS, Disp. Act= 70.7 BBLS, - 10.6 BBL loss.;Kelly up , CBU at 98 GPM, SPP = 179 PSI, 10% flow, Max gas= 49 units with an initial dynamic loss rate of 6 BPH tapering off to 1 BPH at BU.;Dragon Boxes Loaded 80 bbls Total Dragon Boxes 1290 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 129 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 414 bbls Losses Downhole 332.5 bbls Total Losses Downhole 1077.5 bbls 6/10/2022 Tr-Cone bit with no jets parked at 4278'. Halliburton loaded lines with 5 bbls water and checked for leaks. Halliburton pressure tested lines at 540 psi low and 3019 psi high, good tests. Halliburton pumped 20 bbls water at 3 bpm-500 psi followed with 20 bbls 15.8 ppg Class "G" LCM cement at 4 bpm-;705 psi, followed by 14 bbls water at 200 psi, then displaced with 35.4 bbls 9.2 ppg KCL mud at 4 bpm-170 to 455 psi, leaving 3 bbls cement in drill string. Lost 4 bbls throughout the job. CIP at 06:40 on 6-10-22. RD circ hose and cement head. Notified AOGCC of upcoming BOP test at 06:26.;Pulled up hole slowly, from 4278' to 3785' racking back 8 stands, up wt 90K, then pulled another 7 stands to 3319' faster. Initially first 3 stands were wet, then pulled dry.;MU topdrive and pumped 21 bbl low vis nutplug sweep around at 114 gpm increasing to 225 gpm-192 psi, increasing to 254 gpm-260 psi-21% flow, 20 rpm-6721 ft/lbs torque. With sweep to surface saw a PH of 10.8 dropping to 7.7, no sign of cement. Parked at 3338', shut down pump. Fluid dropped slightly.;Swapped from trip tank to rig pump at 15 min intervals. Lost .23 bbls on TT first 15 min. Ran mud pump at 251 gpm-244 psi, 23% flow with no indication of losses. Cont this for 5 hours to let cement firm up.;Eased in hole, dwn wt 52K, from 3338' to 3835' and string started taking some weight. Pulled back up to 3820' and MU topdrive, filled pipe.;Started washing/reaming down at 190 gpm-159 psi, 17% return flow, 50 rpm-8033 ft/lbs torque, 40 ft/hr ROP. At 3829' started seeing WOB up to 1.5K, had PH of 11.8 at shakers, 7473 ft/bs torque at 50 rpm and saw max of 2.5K wob. At 3853' wob dropping off so increased ROP to 60 ft/hr. At 3981';increased to to 80 ft/hr, 70 rpm- 8360 ft/lbs torque. At 4007' increased to 90 ft/hr ROP, 70 rpm-8094 ft/lbs and 2K wob to 4109'.;Cont drilling cement plug from 4109' to 4245' at 1-3K wob, 194 gpm- spp= 244 psi, 70 rpm, 8346-8580 ft/lbs tq, 19% flow. At 4245' wob drop and gas increased to 124 units, washed and reamed from 4245' to 4591', 194 gpm, ssp= 253 psi, max gas- 900 units, 70 rpms, 8100- 8875 ft/lbs tq, at 10-20 ft/min;CBU at 4591', 195 gpm, spp- 265 psi, 70 rpm, 8843- 9423 ft/lbs tq, 19% flow, max gas 688 units dropping to 38 units BGG at BU.;Flow check well, Haliburton filled lines with 5 bbls water, pt lines 500/3000 psi good test, opened up and pumped 20 bbls water 4 bpm- 480 psi- 19% flow, followed by 20 bbls 15.8 ppg class "G" LCM cement 4 bpm- icp 660 psi- fcp 285 psi- 18% flow, chased with 14 bbls water 4 bpm-112 psi-15% flow.;Displaced with 36 bbls of 9.4 ppg KCL mud at 4 bpm- icp 120 psi - fcp 320 psi, 16% flow leaving 5 bbls in the drill pipe, CIP at 23:32 on 6-10-22, no losses during cement job, rig down cement hose and head pin.;POOH from 4591' to 4468' at 15 ft/min, P/U= 90k, SO= 58k.;Cont. POOH from 4468' to 4094' at 15 ft/min, pull from 4094' to 3644' at 60 ft/min, pipe still pulling wet at 3644', P/U= 72K, SO= 50K, Disp. Cal= 6.9 bbls, Disp. Act= 6.7 bbla, diff= .2 bbls.;Kelly up and circulate 15 bbl low vis nut plug sweep around at 253 gpm, spp- 275 psi, 20 rpm, 10.6K tq, max gas 65 units.;Every 1/2 hr break circulation at 185 gpm, spp- 143 psi, 20 rpm, 10.6K tq, 16% flow, racking back a stand from 3644' to 3531', PU= 72k, SO=50K, ROT= 58K.;Break circulation every 15 min moving pipe while WOC, 254 gpm, spp- 245 psi, 20% flow with no losses.;Ease in the hole from 3529' to 4160 observing bit taking weight, Picked up to 4153' kelly up and fill pipe.;Started washing/reaming down from 4153' to 4465' at 186 gpm-270 psi, 18% flow, 50 rpm-8129-8843 ft/lbs torque, 5-15 ft/min, wob of 1-4k wob, max gas= 231 units, 90% cement returns @ 4220', PU= 84K, SO= 56K, ROT= 66K.;Dragon Boxes Loaded 0 bbls Total Dragon Boxes 1290 bbls Cuttings Totes Loaded 126 bbls Total Cuttings Totes 309 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 414 bbls Losses Downhole 22 bbls Total Losses Downhole 1099.5 bbls 6/11/2022 Cont to wash and ream drilling out cement plug from 4423' to 4590' with 3-7K wob, 188 gpm-295 psi, 17% flow, 50 rpm-8701 ft/lbs torque, MW 9.3+ in/9.4 out, Mud Loggers seeing 90% to 100% cement on shakers. At 4590' made connection and no more than got circulating and lost all returns. Right at a +/-;15' coal seam. Pulled 2 stands up hole to 4522' and put well on trip tank. Seeing 5% return flow (normal 8% on TT), switched to rig pump at idle and seeing 6%. Decision made to pull up hole and attempt CBU to clean up and unload wellbore of cement.;Pulled up hole on elevators from 4522' to 2894', up wt 92K. Calculated hole fill 13.1 bbls, actual hole fill 12.1 bbls. Had to pull quite slow to keep from swabbing.;Brought on rig pump at 30 spm-80 gpm-30 psi, 8% flow, 25 rpm-5725 ft/lbs torque. MW in 9.5/out 9.6. Started centrifuge and 10 bph water to reduce MW in active (pits 2 and 6). Had a max of 129 units at bottoms up. Quadco Rep on location and tested audio/visual gas alarms at 09:30 (weekly BOP test).;Eased in hole from 2894' to 3221', dwn wt 48K. MU topdrive and CBU at 36 spm-95 gpm- 27 psi, 8% flow, 24 rpm-6324 ft/lbs torque. Centrifuge discharging 8.9 ppg. MW in 9.1=/9.5 out. Incresed to 41 spm-107 gpm-59 psi, 11% flow, no indication of losses. HES loaded 348 sx lead cement in silo for liner.;Eased in hole from 3221' to 3527', dwn wt 53K. MU topdrive and CBU at 41 spm-108 gpm-48 psi, 12% flow, 24 rpm-6849 ft/lbs torque.;Eased in hole from 3527' to 3839', MU topdrive and CBU at 48 spm-128 gpm-90 psi, 12% flow, 21 rpm-7452 ft/lbs torque. Increased to 56 spm-147 gpm-117 psi, 14% flow with no losses.;Eased in hole from 3839' to 4150', dwn wt 58K, MU topdrive and CBU 50 spm-131 gpm-118 psi, 21 rpm-7700 ft/lbs torque, 14% flow. MW in 9.1+/9.2+ out. Increased to 61 spm-160 gpm-147 psi, 17% flow. No losses.;Eased in hole from 4150' to 4460', dwn wt 60K. MU topdrive and CBU at 60 spm-157 gpm-169 psi, 14% flow, 20 rpm-8315 ft/lbs torque.;Eased in hole from 4460' to 4591' and set down 10K, dwn wt 60K. PU and MU topdrive, broke circ at 46 spm-121 gpm-152 psi, 50 rpm-8373 ft/lbs torque. Started wash/ream down and saw wob at 4591'. Drilled cement from 4591' to 4604' at 51 spm-135 gpm-146 psi, 50 rpm-8600 ft/lbs torque. At 4604' lost wob;cont wash and ream down slowly from 4604' to 4774', next planned LCM cement plug depth. No losses.;CBU at 51 spm-134 gpm-96 psi, 14% flow, 20 rpm-8300 ft/lbs torque. Called out cementers.;Cement equipment still staged at rig, shut down rig pump, broke off topdrive, MU cement head and circ hose. Halliburton flood lines with 5 bbls of water, pressure test 500 low/3000 high. Line up and pump 20 bbls of water at 4 bpm-440 psi, 16% flow;followed by 20 bbls of 15.8 class "G" LCM cement at 4 bpm- icp=265 psi- fcp=128 psi, 14% flow, chased with 14 bbls water at 4 bpm-75 psi, 13% flow. Displace with 30 bbls of 9.1 ppg KCL at 4 bpm-100 psi, 11-13% flow, observed flow drop to 8% with 4 bbls of cement on the back side.;dropped rate and pumped remaining 10 bbls at 2.8 bpm-285 psi, 11% flow. CIP at 1902 hrs with 1 bbl loss for the job. Rig down cement line and cement head.;POOH from 4779' to 3843', first 8 stands at 15 ft/min, last 7 stands at 60 ft/min. PU= 80K, SO= 56K.;Circulate 14 bbl low vis nut plug sweep around staging pump to 251 gpm-293 psi, 20 rpms, 6.5-7.4 ft/lbs tq, 21% returns, no losses, max gas =102 units.;Monitor well with trip tank cycling pumps every 15 min at 250 gpm, 275 psi, 20 rpm, 6.5 ft/lbs tq.;Ease in the hole from 3838' to 4279', wash and ream from 4279' to 4344', 200 gpm, 243 psi, 48 rpm, 7.7 ft/lbs tq, 16% flow, PU= 90K, SO=70K, ROT= 70K.;Drill up cement plug from 4344' to 4590' at 300 fph, 200 gpm- 250 psi, 48 rpm, 8.2-8.8 ft/lbs tq, 17% flow, WOB=2-4k, max gas=200 units, Performed clean up cycle @ 4590', 90 % returns of cmt @ 4404'. Cont. drilling plug from 4590' to 4725' at 200 gpm-230 psi, 48 rpm, 8.6-9.1 ft/lbs tq. 17% flow.;At 4596' rop slowed down to 60 fph with 4k wob, 100% cmt at returns @ 4620'.;Dragon Boxes Loaded 80 bbls Total Dragon Boxes 1370 bbls Cuttings Totes Loaded 81 bbls Total Cuttings Totes 390 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 414 bbls Losses Downhole 119 bbls 6/12/2022 Cont drilling LCM cement from 4725' to 4785', rot wob 4K, 78 spm-207 gpm-246 psi, 18% flow, 66 rpm-9700 ft/lbs torque, MW 9.1+ in/out, BGG 7 units, running centrifuge. At 4785' wob dropped off to 0.;Began washing/reaming down for bottom at 207 gpm, 66 rpm, seeing some occasional wob. At 4940' gas increased to 479 units, return flow rate increased from 18% to 26%. MW down to 9.0 ppg in/out. Shut down centrifuge and water.;CBU at 78 spm-207 gpm-228 psi, 45 rpm- 9100 ft/lbs torque, had max of 793 units at bottoms up, MW up to 9.1+ in/out. Gas down to 25 units.;Cont washing/reaming down to 5246' at 78 spm-205 gpm- 300 psi, 18% flow, 50 rpm-9000 ft/lbs torque, 100 ft/hr ROP, seeing 1 to 3K wob. Had another max of 778 units gas after reaming past a coal seam at 4965', no increase in flow. Have been watching topdrive gear box sight glass, has gained some oil.;CBU at 74 spm-195 gpm-251 psi, 17% flow, 45 rpm-9632 ft/lbs torque, MW 9.2 ppg in/out, BGG 40 units down to 11 units. Did 15 min flow check-static.;LD single joint DP, POOH on elevators with no issues from 5246', on alternate breaks, pipe pulling dry, up wt 110K coming off bottom. Calculated hole fill = 41.9 bbls, Actual hole fill = 43.8 bbls. Bit graded a 1-1-WT-A-E-I-No-BHA.;Inspect and troubleshoot topdrive rineer motor. Installed gauge and flow meter on case drain line. Discussed with rig Super on transporting rineer motor from rig 169 to Beluga. Looking at getting two more motors to peninsula from north slope.;Drained BOP stack, pulled wear ring, set test plug, flooded surface lines and purged air, RU chart recorder.;Tested BOPE at 250 psi low, 3500 psi high, 5 min low, 10 min high. Had 1 F/P , lower pipe rams on test #6, low psi test, functioned and retested (Pass). Rig down test equipment, blow down choke and kill lines, pull test plug and install wear ring.;Witness of BOP test was waived by BLM Rep Allie Schoessler on 6/10/2022 @ 15:33 hrs. and AOGCC Jim Regg on 6/10/2022 @ 16:40 hrs.;Make up BHA with 6.75" Tricone bit ( no nozzles ) bit sub ( plunger style float ), integral blade, XO, hyd. jars and HWDP RIH to 564', PU= 36K, SO= 34K.;RIH on stands of DP to the shoe from 564' to 2885', PU 64K, SO= 48K, Disp. Cal= 53.5 bbls, Disp. Act= 51.9 bbls, Diff=1.4 bbls, Running speed 40-60 ft/min.;Dragon Boxes Loaded 80 bbls Total Dragon Boxes 1450 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 390 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 414 bbls Losses Downhole 0 bbls Total Losses Downhole 1218.5 bbls 6/13/2022 CBU at 2888'. Staged up to 202 gpm-147 psi, 20% return flow, 20 rpm-5300 ft/lbs torque.;Cont TIH from 2888' to 3899'. CBU stepping up to 206 gpm-219 psi, 17% return flow, 20 rpm-7500 ft/lbs torque.;Cont TIH from 3899' to 5082'. CBU stepping up to 202 gpm-305 psi, 17% return flow, 20 rpm-9551 ft/lbs torque, up wt 100K, dwn wt 64K. Called out cementers.;Held PJSM with rig team and cementers, shut down and broke off topdrive, MU cement head and circ hose. Halliburton pumped 5 bbls water to flush and fill lines then tested at 655 psi low and 3540 psi high. Good tests. Halliburton pumped 20 bbls water at 4 bpm-501 psi followed with 19 bbls;(99sx) of 15.8 ppg class "G" cement with 5 ppb Bridgemaker LCM at 4 bpm-599 psi to 260 psi, followed with 14 bbls water at 4 bpm- 444 psi. Halliburton displaced with 45 bbls 9.2 ppg 6% KCL mud at 4 bpm-85 psi to 567 psi FCP. CIP at 10:46 on 6-13-22. Broke off circ hose and cement head.;Pulled up hole 8 stands slowly, up wt 100K, then 7 more stands faster from 5085' to 4157'. Washed up, RD and released cementers. Top of cement estimated at 4634'.;Pumped a 20 bbl lo-vis nutplug sweep around at 96 spm-253 gpm-329 psi, 20 rpm-7569 ft/lbs torque, shut down and put well on trip tank.;Alternate between trip tank and rig pump every 15 minutes.;Eased in hole from 4154' to 4641' and started seeing some string weight drop off. PU and break circ stepping up to 73 spm-194 gpm-193 psi, 17% flow, 50 rpm-8962 ft/lbs torque and begin reaming down. Seeing 1-2K wob at 4656'. At 4773' seeing 90% cement-10% coal. At 4815' 40% cement-60% formation.;Increased rpm's to 70-9052 ft/lbs torque, 1.5 to 4K wob, 3 ft/min ROP. At 4883' mud loggers seeing 80% cement and 20% formation. Drilled cement to 4901' (planned CBU).;CBU at 74 spm-196 gpm-237 psi, 20 rpm-8100 ft/lbs torque.;Resumed drilling cement from 4901' to 5085' - 75 spm- 198 gpm- 275 psi, 17% flow, 55 rpm, 9.2-9.8 ft/lbs torque, 2-4K wob, 1.5-3 ft/min ROP, At 5000' observed wob drop from 3K to 0. At bottoms up gas increase to 498 units.;Mud loggers seeing 95% cement and 5% formation at 4910' and seeing 100% cement at 5050'.;Wash & ream from 5085' to 5244', 195 gpm-280 psi, 40-60 rpms, 9.1-9.5 ft/lbs torque, 1-2K wob,17% flow, max gas=30 units, Mud loggers seeing cement returns tapering off to 90% formation 10% cement by 5210', picked up working single to reach bottom.;Circulate a STS and condition mud - 200 gpm-265 psi, 20 rpms, 8.4-9.1 ft/lbs torque, 17% flow, 6-10 units of gas, shut down and monitor well for 15 min.;L/D working single, POOH on elevators from 5210' to 2857' just inside the CSG. shoe, PU= 60K, SO= 45K, Disp. Cal= 16.1 bbls, Disp. Act= 15.9 bbls, Diff= .2 bbls.;CBU at 75 spm-200 gpm- 125 psi, 17% flow.;Monitor well for 10 min, install TIW valve, hang blocks, cut and slip drill line, ( total length= 92' - 19 wraps ) Acc. TM= 694.;Perform rig service, grease crown, blocks, draw works and motor components.;Monitor well on trip tank with TIW valve installed. Rig mechanic RU gauge and tested Rineer motor seals as per Tesco. Motor seals not holding any pressure, seals have failed. Prep to remove Rineer motor.;Dragon Boxes Loaded 160 bbls Total Dragon Boxes 1610 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 390 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 414 bbls Losses Downhole 0 bbls Total Losses Downhole 1218.5 bbls 6/14/2022 Drill string parked at 2851', TIW installed, well on trip tank monitoring hole, static loss rate= .4 bph. Pressure tested Rineer motor w/ HYD's dead headed to motor. Observed pressure loss, determined seals failed. Change out Rineer motor and replaced w/ same. Functioned test TD motor (ok).;Pumped 15 bbl dry job 2 lbs over mud weight, POOH F/2851'-T/BHA #5, L/D BHA, bit graded engage 1-1-WT-A-E-I-NO-BHA. P/U-50K S/O-40K.;Cleared & cleaned rig floor, staged BHA #6 on catwalk. Inspected TD for leaks (ok).;Held PJSM on P/U BHA. M/U 6.75" directional BHA #6 as per Sperry. 5 bladed 6.75"PDC bit, 1.5° motor, MWD tools, measured off set =307°. Plugged in and uploaded data to MWD tools. Performed shallow pulse test (ok).;Prep and clear rig floor and load sources into BHA, P/U and M/U 2 NM Flex collars, 17 JTS of HWDP and Hyd. Jars and RIH to 738'.;Cont. RIH on elevators from 738' to 2845', PU= 70K, SO= 52K.;CBU at CSG. shoe 200 gpm- 854 psi, 20 RPM, ROT= 70K, Torque 5.8 FT/LBS, 19% flow, while moving pipe slowly in the up stroke.;Cont. RIH from 2847' to 3850' at 30 FT/MIN in open hole, PU=88K, SO= 61K.;CBU staging pumps up while moving pipe slowly to 200 GPM- 880 PSI, 20 RPM, 6.6-7.1 FT/LBS torque, 19% flow, max gas= 9 units.;Cont. RIH from 3897' to 5244' at 30 FT/MIN, fill pipe, PU= 116K, SO= 75K, Disp. Cal= 90.3 BBLS, Disp. Act= 85 BBLS, Diff=5.3 BBLS.;Pumped 20 BBLS of spacer followed by new 9.2 PPG- 6% KCL STS at 75 SPM- 200 GPM- 940 PSI, 20 RPM, 9.8-10.1 FT/LBS torque, 19% flow, ECD's dropping to 9.7- max gas= 4 units, shut down and clean out ditches and shaker beds, sim-ops adjusts kelly hose after top drive repairs.;Drill production hole from 5246' to 5322', 75 SPM-200 GPM- 990 PSI, 17% flow, 55 RPM, on BTM TQ 10.1-10.5 FT/LBS, off BTM TQ 9.7-9.9 FT/LBS, 3-5K WOB, ECD's= 9.8, max gas= 64 units, PU=118K, SO=72K, ROT=85K.;Dragon Boxes Loaded 80 bbls Total Dragon Boxes 1690 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 390 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 414 bbls Losses Downhole 68.5 bbls Total Losses Downhole 1287 bbls pp p Witness of BOP test was waived by BLM Rep Allie()g qp p pg Schoessler on 6/10/2022 @ 15:33 hrs. and AOGCC Jim Regg on 6/10/2022 @ 16:40 hrs.; 6/15/2022 Cont. drilling ahead w/ 6.75" directional BHA #6 F/5330'-T/5572'. P/U-120K S/O-72K ROT-90K GPM-200 SPP-1010 psi Flow-16% TQ-11.9K WOB-3K ROP-60 Diff-100 psi ECD-9.9 ppg MW-9.2 ppg Max gas-282 units. Had Hilcorp and ADFG representatives;traveled to Beluga and take a tour of rig 147.;Crew change, held PTSM. Cont. drilling ahead F/5572'-T/5764'. P/U-127K S/O-71K ROT-91K GPM-207 SPP-1025 psi Flow-17% TQ-11.4K WOB-4K ROP-100 Diff-190 psi ECD-10.0 ppg MW-9.25 ppg Max gas-326 unit;Cont. drilling ahead w/ 6.75" directional BHA #6 F/5764'-T/6037'. P/U-135K S/O-72K ROT-95K GPM-200 SPP- 1230 psi Flow-16% TQ-11.4-12.1K, WOB-3K ROP-80-100, Diff-180 psi, ECD-10.1 ppg MW-9.25 ppg Max gas-486 units.;Crew change, held PTSM. Cont. drilling ahead w/ 6.75" directional BHA #6 F/6037'-T/6253'. P/U-138K S/O-74K ROT-96K GPM-200 SPP-1268 psi Flow-19% TQ-12-12.3K, WOB-5K ROP-80- 100, Diff-255 psi, ECD-10.2 ppg MW-9.3 ppg Max gas-128 units. Distance to well 2.4'- 2.21' Low- .93' left;CBU at 77 SPM-200 GPM- 1050 PSI, 40 RPM, TQ 12.2K, max gas= 46 units, Obtain SPR's, Monitor well for 15 min= static;POOH on elevators from 6253' to 5945', PU= 128K, SO=72K;Dragon Boxes Loaded 160 bbls Total Dragon Boxes 1850 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 390 bbls ISO Tanks Loaded 416 bbls ISO Tanks Total 830 bbls Losses Downhole 0 bbls Total Losses Downhole 1287 bbls 6/16/2022 Cont. POOH on elevators for wiper trip F/5945' -T/5232' w/ no issues. Had calculated hole fill. P/U-120K S/O-62K;Service rig- Greased crown, blocks, DWKS, IR, TDS, brake linkage, and drive shaft. Service MP #1's 3" valve. Monitored well on TT. Static loss rate=1.2 bph.;RIH on elevators at 30 fpm F/5232'-T/6193' w/ no issues. P/U-124K S/O-74K;M/U TDS, broke circ. staged up MP and washed to bottom. GPM-205 SPP-1355 psi RPM-70 TQ-13.5K ECD-10.2 ppg MW- 9.25 ppg Max gas- 1400 units.;Resumed directional drilling ahead F/6253'-T/6316'. P/U-138K S/O-75K ROT-96K GPM-200 SPP-1350 psi Diff-120 psi RPM-70 TQ-12.7K ROP-120 fph WOB-5-7K Flow-19% Max gas-130 units. ECD-10.2 ppg MW-9.2 ppg;Crew change, held PTSM. Cont. directional drilling ahead F/6316'- T/6624'. Add 1 drum of Baralube gold seal to help w/ slides. P/U-146K S/O-80K ROT-103K GPM-200 SPP-1560 psi Diff-280 psi RPM-70 TQ-12.9K ROP-120 fph WOB-5K Flow-18% Max gas-310 units. ECD-10.3 ppg MW-9.25 ppg;Cont. directional drilling ahead F/6624'-T/6935,. 75 SPM- 200 GPM- SPP-1480 psi Diff- 200 psi, 50 RPM, TQ-13.1K ROP-90-120 fph WOB-4K Flow-18% Max gas-76 units. ECD-10.4 ppg MW-9.30 ppg, P/U-150K S/O-79K ROT-100K;Moved 50 BBLS to pre-mix and increased water to 20 BPH. Cut mud from centrifuge 9.05 ppg.;Crew change, held PTSM. Cont. directional drilling ahead F/6935'-T/7240'. 75 SPM- 200 GPM- SPP-1510 psi Diff-290psi RPM-70, TQ-14K ROP-75 fph WOB-4K Flow-18% Max gas-888 units. ECD-10.45 ppg MW-9.3 ppg, P/U-160K S/O-80K ROT-105K, Distance to plan- 14.67'- .76' Low- 14.65' Right;Dragon Boxes Loaded 160 bbls Total Dragon Boxes 2010 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 390 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 830 bbls Losses Downhole 32 bbls Total Losses Downhole 1319 bbls 6/17/2022 Cont. directional drilling 6.75" production hole F/7242' to called TD at 7303'. P/U-162K S/O-78K ROT-106K GPM-200 SPP-1575 psi Diff-275 psi RPM-75 TQ- 14K ROP-75 fph WOB-4K Flow-18% Max gas-330 units. ECD-10.5 ppg MW-9.3 ppg;CBU while working pipe 10/15 ft per/min. GPM-200 SPP-1250 psi RPM-70 TQ-14K Max gas 59 units.;Flow checked well for 10 min (static). POOH on elevators F/7303'-T/6109' w/ no issues. Had calculated hole fill.;Rig service- Greased crown, blocks, TDS, IR, DWKS, brake linkage, drive shaft, and rig floor equip.;RIH F/6109'-T/6849', had 20K set down (slide), attempted to work through on elevators w/ no luck, M/U TD, broke circ. staged up pump, washed/reamed F/6849'-T/6867', hole cleaned up. GPM-200 SPP-1430 psi TQ-14K RPM-30.;CBU while working pipe 10/15 ft per/min. GPM-200 SPP-1430 psi RPM-30 TQ-14K Max gas 932 units.;Crew change, held PTSM. Cont. CBU. GPM-200 SPP-1215 psi RPM-40 TQ-13.2K;Cont. RIH F/6867''-T/7307', had another set down at 6903', were able to work through on elevators. M/U TDS, broke circ. staged up MP, washed last std to bottom w/ no fill. Had calculated pipe displacement. P/U-162K S/O-80K;CBU while working pipe 10/15 ft per/min. Pumped 20 bbl Hi-Vis sweep w/ walnut, sweep came back on time w/ 0% increase in cuttings. Made call to drilling engineer regarding gas, decision was made to dust up to 9.4 ppg, pull 5 stds, RIH to bottom, CBU to determine whether to further weight is needed.;GPM-200 SPP-1250 psi RPM-70 TQ-15K Max gas 933 units.;POOH F/7303'- T/6936' and turned right around and RIH back to bottom w/ no issues. P/U-170K S/O-82K;CBU while working pipe 10/15 ft per/min. GPM-200 SPP-1250 psi RPM-70 TQ-14.8K ECD-10.4 Max gas 477 units. Decision was made to bring MW to 9.55 ppg. Started dusting up MW.;Finished dusting MW to 9.55 ppg. GPM- 200 SPP-1270 psi RPM-70 TQ-14.8K ECD-10.5 Max gas 7 units;POOH F/7303'-T/6929' and turned right around and RIH back to bottom w/ no issues. P/U- 160K S/O-82K;CBU while working pipe 10/15 ft per/min. GPM-205 SPP-1320 psi RPM-80 TQ-14.7K ECD-10.5 Max gas 32 units at BU;Monitor well, POOH F/7303'-T/6620', pump dry job. Cont. POOH F/6620' T/5865', from 6128' to 6123' observing 15-20k over pull able to work through, F/6006' T/5865' observed 20- 30k over pull and was unable to work through tight spot at 5865'. PU= 165K, SO=84K, Kelly up;CBU while reaming through F/5880' T/5821' at 185 GPM, 1200 PSI, 40 RPM, 11.8k TQ, 17% flow, ECD's= 10.7, Max gas=14 units;Cont. POOH F/5880' T/5200', at 5720 observed 30K overpull worked through no issues, PU- 130K, SO=74K;RIH F/5200' T/7240', taking 20K to work through one spot at 6985', Kelly up-fill pipe and wash down 115 GPM, 915 PSI, no rotation F/ 7240' T/7260' showing signs of packing off, Picked up increased pumps to 150 GPM, 1200 PSI, 40 RPM, 13.5K TQ, ECD's= 10.8,;start reaming down with no issues to 7280', F/7280' T/7303' observed WOB increasing from 1-2K up to 3-6K, with TQ swings 12.9-14.4K,;CBU while working pipe 10/15 ft per/min. GPM-200 SPP- 1260 psi RPM-60, TQ-14.4K ECD-10.4, Max gas 764 units at BU, MW in 9.7 PPG, MW out 10.0 PPG, Cont. circulating to drop MW to 9.6+- 9.6+ IN/OUT, while running water at 15 BPH, Centrifuge Cut Weight 9.3 PPG.;Dragon Boxes Loaded 80 bbls Total Dragon Boxes 2090 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 390 bbls ISO Tanks Loaded 208 bbls ISO Tanks Total 1038 bbls Losses Downhole 30 bbls Total Losses Downhole 1349 bbls gp Resumed directional drilling ahead F/6253'-T/6316 Cont. directional drilling 6.75" production hole F/7242' to called TD at 7303'. Cont. drilling ahead w/ 6.75" directional BHA 6/18/2022 Cont. circ. & conditioning MW at 7303'. Initial MW 9.7 ppg In and 10 ppg out. Final MW 9.65 ppg In & 9.65 ppg out. GPM-200 SPP-1500 psi TQ-12.7K RPM-70 ECD-10.4 ppg Max gas-764 units P/U-160K S/O-80K ROT-110K. Obtained new SPR's.;Flow checked well (static). POOH on elevators racking back in the derrick F/7303'-T/5325' (32 stds) seen occasional 20K over pull and falling right off. P/U-165K S/O-84K. Pumped 20 dry job 2 lbs over MW w/ corrosion inhibitor. Off line unloaded Lash 200 barge.;POOH L/D 4.5" DP singles F/5325'-T/2970' (76 jts) using good pipe handling practices, vacuuming wiper balls through pipe, re-doping threads, and screwing thread protectors on tight. P/U-75K S/O-52K;Dropped metal drift on wire (2.4" OD). Cont. POOH on elevators racking back in the derrick F/2970'-T/BHA #6 (36 stds). L/D jars, 1 jt of HWDP, racked back remaining 8 stds of HWDP in derrick;L/D BHA #6-L/D jars, 1 jt of HWDP, L/D flex collars. Removed sources, plugged in and down loaded data. Pulled & L/D pulser. B/O and L/D MWD tools, milked mud motor, B/O 6.75" bit. Bit grade- 1-2-CT-S-I -X-NO-TD in gauge.;Clean rig floor, remove small pieces of BHA from rig floor.;Grease crown, blocks, top drive, wash pipe, drawworks, drive line and brake linkage. Install dump valve on crawn saver reset. Change out fuel filter on floor motor and install an isolation valve on fuel/water separator;Pick up cement head and break off 5' pup from the top and install XO from 4.5" IF pin X 4.5" CDS box and 5' pup, Rig up weatherford hyd. tongs, 75 ton YC elevators and pipe handling equipment. Load liner on load arms.;Pick up and baker lock shoe track as per tally to 148'. Check floats= good, observed leak on power tongs, O-rings in valve manifold bad change out power tongs;Complete power tong swap, Cont. RIH with 4.5" liner 30-40 FPM from 128' to 2892', filling pipe on the fly topping off every 10th jt. TQ connections to 6100 FT/LBS with Best-O-Life 2000 pipe dope, Run free floating centralizers as per tally. PU= 49k, SO=48K, Cal Disp.=11.4 BBLS, Act Disp.= 8.4 BBLS;Dragon Boxes Loaded 80 bbls Total Dragon Boxes 2170 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 390 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 1038 bbls Losses Downhole 24 bbls Total Losses Downhole 1373 bbls 6/19/2022 CBU at shoe -2890', staging pump up to 5 bpm SPP-155 psi MW-9.65 ppg Max gas-4 units. Obtained rotary parameters. 10-RPM's =3.2K 20 RPM's = 3.6K 30 RPM's = 3.8K P/U-49K S/O-48K;Cont. RIH w/ 4.5" liner F/2890'-T/4573', running speed 30 ft per/min. Pushed away 3 bbls during the trip. P/U-70K S/O-55K;P/U Baker liner hanger-HDR-E ZXP liner packer/Flex Lock V liner hanger. Mixed and poured Xanplex in liner top. Attempted to obtain rotary parameters w/ no luck. M/U 1 std of HWDP to top of hanger and RIH. P/U-70K S/O-55K;CBU while working pipe 15-30 ft per/min, staging pump up to 5 bpm SPP-300 psi MW-9.65 ppg Max gas-15 units.;Cont. running liner on HWDP/DP at 15 ft per/min F/4580'-T/6100'. P/U-105K S/O-68K;CBU X2 while working pipe 15-30 ft per/min, staging pump up to 5 bpm SPP-420 psi MW-9.65 ppg Max gas-1219 units.;Cont. running liner on 4.5" DP at 15 ft per/min F/6100'-T/7303', washed last stand to bottom w/ no fill or issues during the trip. P/U-140K S/O-78K Cal Disp-45.1 bbls Act Disp-40.2 bbls Diff- -4.9 bbls;CBU X2 while working pipe 15-30 ft, staging pump up to 5 bpm SPP-520 psi, 20% flow MW-9.7 ppg Max gas-3030 units;Rig up cement head and circulate through cement line at 5 BPM- 660 PSI. While conducting PJSM with all hands involved;Halliburton pumped 3 bbls water to flush lines, then 5 bbls to fill lines. Shut in at Baker cement head and PT lines at 592 psi low 4665 psi high. Lined up Baker cement head to Halliburton, pumped 30 bbls 10.5 ppg spacer at 5 bpm-608 psi, followed with 148 bbls (348 sx) 12 ppg Type I II Lead cement;5 bpm, 550 to 275 psi, followed with 20 bbls (94 sx) 15.3 ppg Type I II Tail cement at 4 bpm-285 psi. Added 2 pps LCM to lead cement. Baker released dart, Halliburton then displaced with 9.65 ppg 6% KCL mud at 5 bpm-195 ICP. 8 bbls into displacement caught pressure chasing cement.;32 bbls into displacement saw dart latch wiper plug. With 12 bbls to go, reduced rate to 3 bpm-1120 psi and bumped plug/landing collar 100.1 bbls into displacement (calculated at 102.3 bbls). FCP 1315 psi. Halliburton increased to and held 1550 psi (235 over fcp) for 2 minute;Slacked off on blocks from 120K to 20K, giving us a good indication hanger was set. Bled back 1.5 bbls to truck and floats held. CIP at 22:15 on 6-19-22. Lost 16 bbls throughout the job. Applied 4560 psi and held 5 minute to shift HRD-E and release run tool PU 7’ to clear dogs;from hanger top, S/O and set down to 20K (30K applied). Top of liner hanger at 2687’, top of landing collar at 7213’.Closed upper rams, rig lined up on kill line and pressured up on annulus to 1050 psi and held for 5 minutes. Pressure holding, good indication HRDE ZXP liner top packer is set;Bled off annulus pressure to 0 psi and opened rams. LD Halliburton hardline, LD Baker cement head, MU topdrive. Pressured up to 580 psi on drill string and PU 10-20’ slowly. Once psi started dropping, rig started pumping and did one full circ at 425 gpm-765 psi.;Shut down pump, racked back one stand, installed wiper ball in drill string, MU topdrive and pumped second circulation at 425 gpm-588 psi.;POOH racking back drill pipe F/2620' T/ surface, L/D liner hanger running tool, Cal Disp.= 22.2 bbls, Act Disp.=23 bbls, Diff= .8 bbbls,;Remove both XO's and 5 ft pup from cement head, flush and drain stack;M/U Tieback polish mill assy and XO, RIH to 1315' on DP, PU=48K, SO=44K;Dragon Boxes Loaded 0 bbls Total Dragon Boxes 2170 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 390 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 1038 bbls Losses Downhole 16 bbls Total Losses Downhole 1389 bbls 6/20/2022 Cont. RIH w/ Baker polish mills F/1240'-T/2876'. P/U-68K S/O-50K;Polished PBR as per Baker Rep. GPM-84 SPP-100 psi RPM-10-60 TQ-5.6-7.5K working 10'. Tagged NoGo, set down 6K, TOL-2692' MD. Cont. hauling off mud and cleaning pits.;CBU, GPM-300 SPP-335 psi. Displaced top section of well over to 6% KCL 8.56 ppg brine w/ corrosion inhibited, GPM-455 SPP-460 psi RPM-60 TQ-6.5K while working pipe 35'. Flow checked well (static).;POOH L/D 4.5" DP singles F/2687'-T/61', vacuuming wiper balls through pipe, cleaning re-doping threads, and installing thread protectors on tight. P/U-48K S/O-44K @ 1400';Finished L/D 4.5" DP singles from down hole, L/D Baker polishing mill (ok).;M/U mule shoe, RIH w/ 4.5" DP out of derrick F/surface -T/2168' . P/U-50K S/O-45K;L/D 4.5" DP singles F/2168'-T/surface. L/D mule shoe. P/U-49K S/O-45K;Pulled wear ring, built test jt and set, M/U TIW and pump in sub to TDS.;Serviced rig- Greased crown, blocks, DWKS, IR, TD, wash pipe, drive shaft and brake linkage.;Rig up testing equipment, Flood lines and purge air from system. Perform shell test;Tested BOPE at 250 psi low, 3500 psi high, 5 min low, 10 min high. Had 1 F/P , lower pipe rams on test #6, low psi test, functioned and retested (Pass). Rig down test equipment, blow down choke and kill lines, pull test plug.;Witness of BOP test was waived by BLM Rep Allie Schoessler and AOGCC Jim Regg;Rig down test equipment, pull test plug and lay down test jt.;Pressure test 7 5/8 x 4.5" CSG to 3000 PSI holding for 30 min. Test good, bleed off pressure and blow down all lines. Pumped 2.7 BBLS with 2.7 BBLS bled back.;Rig up Weatherfords pipe handling equipment and power tongs, load up skate racks with bullet seal assy. and 4.5" DWC TBG.;Dragon Boxes Loaded 160 bbls Total Dragon Boxes 2330 bbls Cuttings Totes Loaded 90 bbls Total Cuttings Totes 480 bbls ISO Tanks Loaded 312 bbls ISO Tanks Total 1350 bbls Losses Downhole 0 bbls Total Losses Downhole 1389 bbls ppg g g p g Halliburton pumped 3 bbls water to flush lines,then 5 bbls to fill lines. Shut in at Baker cement head and PT lines atgpp 592 psi low 4665 psi high. Lined up Baker cement head to Halliburton, pumped 30 bbls 10.5 ppg spacer at 5 bpm-608 psi, followed with 148 bbls (348 sx) 12 ppgp pp ppg p p p ppg Type I II Lead cement;5 bpm, 550 to 275 psi, followed with 20 bbls (94 sx) 15.3 ppg Type I II Tail cement at 4 bpm-285 psi pg g Cont. running liner on HWDP/DP at 15 ft per/min F/4580'-T/6100' Lost 16 bbls throughout the job pp Baker released dart,Halliburton then displaced with 9.65 ppg 6% KCL mud at 5 bpm-195 ICP. 8 bbls into displacement caught pressure chasing pp ()ppgyp pp pppg p p gp g cement.;32 bbls into displacement saw dart latch wiper plug. With 12 bbls to go, reduced rate to 3 bpm-1120 psi and bumped plug/landing collar 100.1 bbls into pppggppppgg displacement (calculated at 102.3 bbls). FCP 1315 psi. Halliburton increased to and held 1550 psi (235 over fcp) for 2 minute;Slacked off on blocks from 120K top()p 20K, giving us a good indication hanger was set. Bled back 1.5 bbls to truck and floats held 6/21/2022 P/U liner hanger & LJ, attempted to test run hanger, unable to pass bag w/ hanger. Pulled hanger/LJ and L/D. P/U 4.5" tubing jts, functioned annular multiple times, pulled flow riser, cleaned out back side of bag w/ water hose, installed flow riser, functioned bag, L/D 4.5" tubing jt.;P/U hanger/LJ, attempted to test run hanger again, hanger went through, marked LJ w/ tape, Pulled hanger/LJ and L/D.;Held PJSM on running tie back assy. P/U & M/U tie back seals to first jt. of 4.5" 12.6# L-80 Vam DWC/C HT tubing . Cont. RIH w/ tie back seal F/surface-T/+/- 2040' (50 jnts) and called out Pollard Rep. At this point it was noticed the joint count did not match with joint numbers on run tally.;counted pipe in yard, came up with 11 extra joints for current depth. Decision made to POOH checking numbers and lengths. At joint #120 we found and LD 11 joints that had no strap or joint number, then found jnt #119 (jnt 8 in hole). Cont to POOH to seal assembly, checked seals (OK), removed the 11;joints from location, recounted all pipe on location, resumed PU single in hole from 61' to 2171', PU chem injection mandrel with pups, RU Pollard control line, cont PU single in hole total 64 joints to 2678', PU extra single with XO and MU topdrive. Rolled pump at idle as we S/O until we saw;pressure increase as seals entered SBR, down pump, opened bleeder.;With 0 psi on tubing, S/O and landed on no-go. PU to string weight, pressured up on tubing to 500 psi as per Baker Rep and held solid couple minutes to test seals. Good test, bled off, backed out and LD single. P/U landing jt and hanger, terminate control line and run through hanger.;Ran a total of 29 SS bands on control line, 1 at every connection and mid joint.;Drained stack , RIH and land hanger, - 3.42' off NO-GO, 24K on hanger. RILDS, sim-ops rig up for MIT. Lay down Weatherford handling equipment.;Fill lines and purge air from system, MIT 4.5" TBG to 3000 PSI for 30 charted min. Test Good, MIT-IA the 7 5/8 x 4 1/2" Annulus to 2500 PSI for 30 charted min. Test Good;Install TWC, Line up and flush through top drive, choke and kill lines with surfactant/solvent soap water, blow down all surface lines and suck out stack.;Pull mouse hole, remove choke and kill lines, pull flow riser and remove trip nipple, pull flow line from flow box, bled off koomey and removed koomey lines, sim-ops flush and clean pits;Dragon Boxes Loaded 80 bbls Total Dragon Boxes 2410 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 480 bbls ISO Tanks Loaded 104 bbls ISO Tanks Total 1350 bbls Losses Downhole 0 bbls Total Losses Downhole 1389 bbls 6/22/2022 Cont ND BOP stack, stage stack at cellar entrance on bridge cranes. Cont pit cleaning. Staged dry hole tree at cellar entrance.;RU and set dry hole tree on well, NU same. Wellhead Rep tested void at 2500 psi low for 5 minutes, 5000 psi high for 15 minutes, then tested tree at 1500 psi low for 5 minutes, 5000 psi high for 15 minutes. Good tests, pulled 2 way check from hanger and closed master valve.;Cont pit cleaning, installed shipping beams in cellar, RD discharge line and shock hose from poorboy degasser, pressure washed floor equipment for RD. Found poorboy degasser vessel and J tube full of grease and scale. Start cleaning out grease, suspected to be from choke manifold valves.;Brand new crew to rig, discussed recent injury on north slope, working on BLM/refuge land and associated rules and regs, oriented new hands to rig, also requested them to do a hazard hunt as they are fresh eyes on the rig. Cont working on poorboy degasser, RD bails and hand tongs, brought in crane;and BOP cradle. laid over beaver slide, spotted crane and cradle, transferred BOP stack from bridge cranes to cradle, released crane, folded slide back over, loaded and sent BOP stack to J pad. RD hand tongs and bails. Removed subs and XO's from floor. Cont pit cleaning.;Complete inspection of fluid end on MP's, Break down stand pipe manifold on rig floor, removed saver sub from top drive, Pined iron rough neck and removed hoses, removed kelly hose and service loop from top drive, set top drive in transfer carriage, remove blocks and L/D top drive on catwalk;oriented new crew on BLM/refuge land and associated rules and regs.;PJSM with crew, discussed recent injury on north slope. Bridle up and scope down derrick, removed lower portion of torque tube and L/D on catwalk, finish cleaning pits and remove suction lines between pit mods. Rig down steam lines, pinned monkey board in storage position. 6/23/2022 RD Pason sensor from upright water tank, drained Bara Klean solution from poorboy degasser and re-loaded to soak some more. MU wire rope snake from new spool drill line to existing drill line tail, held PJSM, string derrick and blocks with new drill line, coiled up old line for disposal.;Removed lights from pit roof tops, transport items to barge landing for shipping to east side.;Gathered up gas detection sensors for rig move, checking shaker screen and absorb inventory, prep to clean mud pump engine radiators, work on crown saver actuator, transported upright water tank to staging pad, remove JB Weld from hopper discharge line for welding repair, spool up drill line on drum;removed same from drum, coiled up and secured in derrick.;Secure all derrick lines/cables and prep derrick to be laid over. Disconnected 3rd party connex, Disconnected brake linkage from Draw works. Disconnected non-essential electrical cables from mods. Cont. to cleaned and buffed hopper #1 discharge for welding project.;Cleaned up and secured misc. tools and performed hazard hunt.;Remove 3rd party shacks from location, pressure wash and clean sub structure, clean and organize tool boxes and parts conex, repair various fluid lines/vlaves in pits, clean motor filters, remove air lines to drillers console and secure electrical cables to pits. 6/24/2022 Cont pressure washing throughout the rig, clean and organize rig mods and j pad, cont checking valves for replacement in pits, cont securing cords for rig move, start removing hardware on pump motors for upcoming injector change.;Wellhead rep checking equipment for Ivan River well and excess equipment to ship to east side, prep and manifest loads for tomorrow morning’s barge, load available rig mats on trailer for transport to Ivan on the 1st, rolled the 500 bbl frac tank holding 6% KCL mud and added some caustic;Perform EAM on hopper 2 and 3, buff and/or grind item's in need of welding, check pins and service catwalk robotics.;Pressure wash rig floor mats and free up rotary table lock pin, Cont. and complete EAM's on hopper 2 and 3. Adjust cable on catwalk buggy, Prep and remove not needed well head equipment to be barged out. Removed guards on both mud pumps for fuel pump change. Cont. organizing rig mods.;Grease all Lo-torque and choke manifold valves, Performed hazard hunt on overhead equipment, organized and inventoried pump room tools and equipment, Cont. pressure washing and cleaning rig. Installed isolation valves for air and water lines to pits. Stick pick and remove misc. items off location. 6/25/2022 Inspect and grease crown sheaves, RD and prep centrifuge for removal from pit mod 3, replaced 2” valve on poorboy degasser, inspected all SRL’s and replaced one on crown, cleaned cellar box.;Loaded last of trash fluid in ISO for shipping to G&I, brought in crane and LD poorboy, then removed centrifuge from pit mod 3, cont prep pump motors for injector changes, cont cleaning throughout the rig.;Replaced driller side catwalk loading arm cylinders, Installed pre-filter on gens 1&2, Cleaning up BOP bolts, Pressure wash drawworks skid.;Cont. cleaning off BOP bolts with wire wheel, Wrap all connections and fitting on mods, Remove air intakes on MP's, Fixing stems on gun line valves in pits so handle fits on them correctly. 6/26/2022 Replaced dog run cables on pit roof tops (anti fall), cut out very thin/washed out section of discharge line on hopper one, inspected cabling for doghouse hoist system, inspected cabling for vacuum degasser hoist system, cont cleaning BOP bolts and organize 40 connex.;Fabricate and weld in new discharge line for hopper one, cont trouble shooting crown saver actuating ram reset, CCI rolled 6% KCL mud in frac tank. Tourpusher woke up early feeling ill, sent in to town on helicopter, to be checked out at emergency room.;Change out 4" valve in trip tank, replace gaskets on inspection hatches of gas buster, install T manifold on hydraulic supply to bop cranes and catwalk. Received shipment/organized and put away. Prep MP #2 liner wash tank and paint;Finish painting liner wash tank on MP #2, Complete the installation of dog runs on pit roofs, prep liner wash tank for paint MP#1, Clean out hopper #1 room and paint new metal from repairs. Sort through hose basket and remove any bad hose, 6/27/2022 Cont prepping some items for paint, weld up cracks top of beaver slide trough and bottom of beaver slide trough, weld safety chains to various pins on shipping beams. Relocate trailers from barge landing to in field, label electric cords.;Perform EAM on pump motor #2, assist Pac Power Rep with injector changes on pump motor #1, cont sorting and stowing hoses of all sizes, paint liner wash tank on pump #1, cleaning and organizing throughout the rig.;Fire watch on welding job, Inventory hoses and connection types. Discard bad hoses. Sort through and segregate trash/oily waste.;Clean and organize driller dog house. Repair hydraulic lines for doghouse lowering system. Secure spare hoses on 40' conex. jg gg RIH and land hanger, - 3.42' off NO-GO, 24K on hanger. RILDS 6/28/2022 Test ran pump #2 engine with no issues, started working on injector changes on pump #1, held PJSM and L/D mast, folded over beaver slide, RU to lower roof tops on pits 2 and 3.;Lowered roof tops on pits 2-3, chased down Ivan River well sign, rig electrician checked out starter and wire for water well on Ivan pad (needs replaced along with pump), obtained 1.5 horse water pump from production, Finished assembly of pump motor #1 and test ran, released Pac Power Rep.;Spooled up com wire from service shacks to DSM office, secured torque tube section to catwalk for rig move, troubleshoot wireless comm's to mud lab, organized used bits to ship out. Lift walkways, R/D down diesel, water and air lines in prep for rig move.;Cut out tale lock access in rotary floor mat. Put trash cans and tool barrels in connexes. Prep to lower doghouse.;Dragon Boxes Loaded 0 bbls Total Dragon Boxes 2960 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 480 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 1350 bbls Losses Downhole 0 bbls Total Losses Downhole 1389 bbls 6/29/2022 CCI worked the am barge while rig crew RD lights camera and gas alarm from doghouse, then lowered doghouse. RD Handy Berm around entire rig then CCI tore out catwalk, cuttings box, pit mods, back yard mods, doghouse and gen skid. Staged trailers and start loading;rig mats when exposed. Cleaned up liner for re-use, set any rig mats aside for metal strap re-welding. CCI welder making repairs to pit 3 mod roof legs. Loaded jig and poorboy degasser. Ran some measurements with Drilling Engineer on C pad to determine brush/tree removal in order to fit rig,;palletized oil drums and assorted bits etc for rig move.;Clean and organize both change houses. Engrave sizes on new shaker screens. Orient New crew to jsa's and safety processes. CCI spotted crane. CCI welder on location at 05:30 to finish welding projects.;Dragon Boxes Loaded 0 bbls Total Dragon Boxes 2960 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 480 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 1350 bbls Losses Downhole 0 bbls Total Losses Downhole 1389 bbls 6/30/2022 CCI worked barge then brought in 2nd crane, spotted and picked iron roughneck off rig floor, spotted 2nd crane and picked derrick off carrier, picked carrier off sub, picked sub off pony walls. Staged derrick and carrier on J pad. Loaded rig mats, loaded pony walls, felt and liner for Ivan. Lost;camp gen (water pump froze up), wired in aux gen and put on line. Disposed of felt and liner on F pad, welder repaired steam heater mount bracket on sub base, trimmed grating to fit on 244- 27, shortened racking finger on derrick board, loaded sub on bed truck for transport to Ivan.;Tool Push traveled to Ivan Pad and ran string line/marked with paint for lay out of felt and liner.;Install legs on Pit mod 3 roof. Finish clean up on location. Rig released at 23:59 on 06/30/2022 Activity Date Ops Summary 9/11/2022 Fly Kenai to Beluga,Mobilize coil equipment and crane from Ivan River to Beluga.,Open PTW & PJSM. Begin spot in and rig up of coil equipment.,BOP test 250/3000 psi per sundry. Passed. Witness waived by AOGCC.,Move BOPS's to tree and continue rig up hardline to well.,Spot fluid tanks on location. LDFN. 9/12/2022 Open PTW and PJSM, continue rig up & pick up lubricator,,Notified by ops to install Herculite liner below coil tubing equipment. Stand back unit and pump truck to install liner.,Pick up lubricator & make up BHA #1 w/ CTC, DFCV's, weight bar & 2.5" nozzle. Prepare for PT. SLB coil pump will not start up, troubleshoot with Kenai mechanics shop to a bad starter. Rig down and secure well for the night. SLB mechanic w/ replacement starter on the 6 pm Otter. Will then install and verify pump is working for circ out run. 9/13/2022 PTW & PJSM. Make up lubricator and BHA #1 (1.9" roll on CTC, 1.75" DFCV's, 1.75" stinger, xo, 2.5" nozzle). PT lubricator & hardline w/ returns line to 250/3000 psi per sundry.,RIH w/ BHA #1. Come online w/ pumps @ 1.5 bpm @ 6800'. Tag PBTD @ 7210' CTM. POOH and paint flag @ 7180'. POOH @ 100 fpm pumping at 1.5 bpm. 1:1 returns. Total freshwater pumped 182 bbls. Bump up and lay down nozzle.,MU Halliburton Radial CBL tool (24.7' x 1.69"). RIH w/ CBL. Stop at flag (7180'). Wait for tool to turn on @ 13:30. Log up from TD to 2600' @ 40 fpm. POOH to surface.,Close in swab and pop off with lubricator. Laydown logging toolstring and stack down lubricator. Set down injector. Install night cap on well. Verify good CBL data. SDFN. 9/14/2022 SLB Coil hold TBT and approve PTW. Pick up injector, lubricator and MU BHA.,RIH with 1.75" coil and 2.75" big hole nozzle. Cool down N2 pump and start pumping N2 down coil at 1000 scfm at 5000'. Tag at 7214' ctmd and PU 10'. Increase N2 rate to 1200 scfm. Stay on bottom pumping until recovered enough water at surface to ensure N2 is around the nozzle. Start to POOH at 60 fpm.,POOH until returns are all N2, then close in choke. Recover 145 bbls of water to surface, which is the total tubing volume plus coil volume. Pressure up tubing to 1700 psi, then shut in swab.,Pop off well. Laydown coil BHA, lubricator and set down injector. Install tree cap. RDMO coil equipment and spot equipment on BRU 222-34. Wait on Yellow Jacket tools to arrive on Otter. SDFN. 11/13/2022 MIRU on well. Pickup 1-11/16" GPT tools. WHP is 1730 psi. RIH and find fluid level at 6814' and tagged PBTD at 7210'. POOH, Secure tree. RDMO. 11/22/2022 Spot up AK Eline on 244-27, pick up lubricator and 20' perf gun assembly. Stab on well. PT lubricator to 250/3000 pass.,WHP = 1665. RIH w/ 5' x 3 1/8" GR/CCL, 2.5' x 2 3/4" shock sub, 20' x 2 7/8" Geo Razor perf guns. 10' CCL to top shot. Pull correlation pass from 6000'-5600'. Send to Geo, shift down 3'. Shoot the Beluga H10 sand, 5870'-5890'. CCL stop depth = 5860'. Initial pressure = 1667, 5 min = 1756, 10 min = 1824, 15 min = 1881. POOH, all shots fired. Bull plug dry. SITP at surface = 2004 psi.,Lay down perf guns & lubricator. Secure well for the night. 11/23/2022 AK Eline on location. Open PTW & PJSM. Make up GPT tool and pick up lubricator. Stab onto well. Open up to WHP = 2032 psi.,SITP = 2032 psi. RIH w/ 12' x 1 11/16" WB, 8' x 1 11/16" GPT tool w/ CCL 4' x 1 1/2" WB. Find FL w/ RIH @ 6818'. Pick up to 5800' w/ Eline and begin to bleed N2. Bleed WHP down to 1870 psi when LELs detected at the flowback tank. Shut in choke skid. Final FL @ 6805'. POOH. Lay down tools and lubricator. Rig down equipment. Secure tree. Leave AK EL unit and crane spotted at 244-27. AK EL crew on the 5pm flight to Kenai. 12/21/2022 PTW and PJSM. MIRU on BRU 244-27. MU 20' 2-7/8" HSC gun. Stab on well and pressure test to 250 psi / 3000 psi. Swap out needle valve on pump-in-sub. Retest to 250 psi / 3000 psi, good test.,RIH and correlate, send to town, on depth. Perforate the H-12 from 5930'-5950'. POOH. Pressure and flow data: well was flowing at ~675 mcf and 249 psi prior to perforating, well showed no flowing pressure response and the flow rate come up 20-30 mcf after 15 min. Lay down gun, all shots fired. Gun had some fluid in the bull plug. Install night cap and SDFN. 12/22/2022 PTW and PJSM. Warmup equipment and pickup lubricator. Wait on tools from Kenai.,MU GPT logging tools. Well is flowing at 249 psi and ~575 mcf. RIH and find fluid level at 5890' (right near open H-10 perfs from 5870'-5890'). POOH. Lay down tools.,MU 3.70" CIBP. Shut in well. RIH and correlate, send to town, on depth. Set plug at 5905'. Tag plug to confirm set. POOH.,MU 20' 2-7/8" gun. RIH, pull correlation log, send to town, on depth. Well currently shut-in. Perforate the H7 from 5730'-5750'. POOH. Lay down gun, all shots fired. Gun was wet. Pressure data: Initial - 554 psi 5 min - 551 psi 10 min - 549 psi 15 min - 549 psi,MU 13' 2-3/4" gun. RIH, pull correlation log, send to town, on depth. Well currently shut-in. Perforate the H2 from 5535'-5548'. POOH. Lay down gun, all shots fired. Gun was wet. Pressure data: 543 psi with no change after 15 min.,MU 13' 2-3/4" gun. RIH, pull correlation log, send to town, on depth. Well currently shut-in. Perforate the G5 from 5215'-5228'. POOH. Lay down gun, all shots fired. Gun was wet. 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'8*)!" /C,0,0  AD  A  A         Benjamin Hand Digitally signed by Benjamin Hand Date: 2022.06.17 11:57:52 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2022.06.20 08:41:41 -08'00' TD Shoe Depth: PBTD: Jts. 2 72 Yes X No X Yes No Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes X No Liner hanger test pressure:Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) 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: X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns? Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Type I II Class A 488 2.44 Type I II Class A 160 1.16 4 21.32 Hanger 16 CDC Cactus 2.12 21.32 19.20 2,819.06 22.69 Pup Joint 7 5/8 29.7 L-80 CDC 1.37 22.69 1.32 2,820.38 2,819.06 Casing 7 5/8 29.7 L-80 CDC 2,796.37 Float Collar 8 5/8 BTC Innovex Every other joint up to 300 ft. Casing 7 5/8 29.7 L-80 CDC 75.50 2,895.88 2,820.38 www.wellez.net WellEz Information Management LLC ver_04818br 4 Type of Shoe:Innovex Bullnose Casing Crew:Weatherford 12 195 2,897.902,905.00 2,819.06 CEMENTING REPORT Csg Wt. On Slips: Spud Mud 11:51 6/3/2022 3 15.8 33.5 Bump press Returns to Surface Bump Plug? 125/129 1541 95 Cementers FI R S T S T A G E 10.5Tuned 58 9.1 4 99.9 722 Csg Wt. On Hook:60,000 Type Float Collar:Innovex No. Hrs to Run:6 BTC Innovex 2.02 2,897.90 2,895.88 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.BRU 244-27 Date Run 2-Jun-22 CASING RECORD County State Alaska Supv.R Pederson / J Riley 2,819.06 Floats Held Spud Mud Rotate Csg Recip Csg Ft. Min. PPG9.1 Shoe @ 2897.9 FC @ Top of Liner Casing (Or Liner) Detail Shoe 8 5/8 TD Shoe Depth: PBTD: Jts. 1 2 109 Yes X No X Yes No 15 Fluid Description: Liner hanger Info (Make/Model):Liner top Packer?:X Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) 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: X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Casing (Or Liner) Detail Shoe 5 Rotate Csg Recip Csg Ft. Min. PPG9.65 Shoe @ 7301 FC @ Top of Liner 26877,256.00 Floats Held3000 PHPA CASING RECORD County State Alaska Supv.J Richardson / C Yearout Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.BRU 244-27 Date Run 19-Jun-22 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top BTC Innovex 1.71 7,303.00 7,301.29 Csg Wt. On Hook:90,000 Type Float Collar:Innovex No. Hrs to Run:19.5 9.65 5 20 1315 FI R S T S T A G E 10.5Tuned Spacer 30 100.1/102.2 235 288 Haliburton 15.3 20 Bump press CBL Bump Plug? 22:15 6/19/2022 2,680 7,303.007,303.00 7,215.93 CEMENTING REPORT Csg Wt. On Slips:75,000 6% KCL PHPA 12 148 Type of Shoe:Innovex Casing Crew:WOTCO HRD-E ZXP liner top packer www.wellez.net WellEz Information Management LLC ver_04818br 4 Ran 53 Hydro form centralizers Liner 4 1/2 12.6 L-80 DWC/C HT VAM 41.61 7,301.29 7,259.68 Float collar 5 BTC Innovex 1.32 7,259.68 7,258.36 Liner 4 1/2 12.6 L-80 DWC/C HT VAM 41.28 7,258.36 7,217.08 Landing collar 5 BTC Baker 1.15 7,217.08 7,215.93 Liner 4 1/2 12.6 L-80 DWC/C HT VAM 4,481.66 7,215.93 2,734.27 Pup jt 4 1/2 12.6 L-80 DWC/C HT VAM 7.78 2,734.27 2,726.49 Baker Hanger 6 5/8 DWC/C HT HRD-E ZXP 32.98 2,726.49 2,693.51 1/2 348 2.39 1/2 90 1.24 5 1 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Thursday, December 29, 2022 9:31 AM To:bbauer@hilcorp.com Cc:Stjohn, Kam P (OGC) Subject:Beluga SVS Testing Inspector that witnessed SVS tests at Beluga River Unit (BRU) this past week made me aware of 2 online wells that were  not tested – BRU 222‐34 (PTD 2220390) and BRU 244‐27 (PTD 2220380).  AOGCC regulation 20 AAC 25.265(h)(6)  requires all wells online at the time of a pad test to be performance tested.  AOGCC Industry Guidance Bulletin 10‐004,  Section titled “Test Cycle” clarifies with the following:  “All wells that require a functional SVS must be tested at the time  of a pad test, including any wells that have been brought on line since the previous pad test.”    I am aware that SVS tests on both were witnessed 12/6 after being placed in production.  AOGCC will accept those SVS  tests as satisfying the well’s pad test requirement.  For similar situations in the future, the decision to forego testing  wells that have been placed on production or injection since the previous pad test must be coordinated with AOGCC  when making notice for opportunity to witness.      Jim Regg  Supervisor, Inspections  AOGCC    333 W. 7th Ave, Suite 100  Anchorage, AK 99501  907‐793‐1236    From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:SVS Testing - Beluga River Unit Date:Thursday, December 29, 2022 9:38:09 AM Attachments:SVS BRU 222-24 clarification 12-29-2022.pdf SVS BRU 244-27 clarification 12-29-2022.pdf BRU 222-24 (PTD 2220390) BRU 244-27 (PTD 2220380) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221228 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 11/27/2022 AK E-LINE GPT Fluid Sample BRU 214-13 50283201870000 222117 11/9/2022 AK E-LINE Perf GPT BRU 214-13 50283201870000 222117 12/2/2022 AK E-LINE Perf BRU 222-34 50283201860000 222039 11/13/2022 AK E-LINE GPT BRU 233-23 50283201360100 222050 11/10/2022 AK E-LINE GPT Plug Perf BRU 244-27 50283201850000 222038 11/13/2022 AK E-LINE GPT Please include current contact information if different from above. By Meredith Guhl at 9:22 am, Dec 29, 2022 T37401 T37402 T37402 T37403 T37404 T37405BRU 244-27 50283201850000 222038 11/13/2022 AK E-LINE GPT Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.29 09:31:43 -09'00' Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/02/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221202 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 222-34 50283201860000 222039 11/22/2022 AK E-Line Perf BRU 233-23 50283201360100 222050 11/3/2022 AK E-Line GPT BRU 244-27 50283201850000 222038 11/23/2022 AK E-Line Perf GPT CLU 05RD2 50133204740200 222092 11/17/2022 AK E-Line Perf MPU K-34 50029227120000 196169 11/10/2022 AK E-Line Punch CLU 13 50133206460000 214171 11/12/2022 Halliburton SBHP END 3-25B 50029221250200 203021 11/24/2022 Halliburton PPROF PBU S-15 50029211130000 184071 11/24/2022 Halliburton RBT PBU Z-221 50029237040000 221095 11/17/2022 Halliburton IPROF PBU Z-221 50029237040000 221095 11/19/2022 Halliburton IPROF Please include current contact information if different from above. T37345 T37346 T37347 T37348 T37349 T37350 T37351 T37352 T37353 T37353 By Meredith Guhl at 12:25 pm, Dec 02, 2022 BRU 244-27 50283201850000 222038 11/23/2022 AK E-Line Perf GPT Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.02 12:24:17 -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:McLellan, Bryan J (OGC) To:Jacob Flora Subject:RE: BRU 244-27 request to add H-7 perf interval (Sundry 322-378) (PTD 222-038) Date:Friday, November 18, 2022 11:35:00 AM Jake, Approval granted to add the below perf interval which is between two proposed perf intervals already authorized under Sundry 322-378. 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: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Tuesday, November 15, 2022 11:10 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: BRU 244-27 request to add H-7 perf interval (Sundry 322-378) (PTD 222-038) Hello Bryan, A completion review with our geologist revealed the need to add one sand to the approved perforation table: Beluga H-7 5730 – 5750’ MD Please let me know if you need anything additional in this request, Thanks, Jake The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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:Jacob Flora Subject:RE: BRU 244-27 CBL (Sundry 322-378) (PTD 222-038) Date:Thursday, November 10, 2022 10:47:00 AM Hilcorp has approval to perf per Sundry 322-378. Looks like good cement all the way to the liner top. 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: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Thursday, November 10, 2022 9:58 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: BRU 244-27 CBL (Sundry 322-378) (PTD 222-038) Hello Bryan, Please see attached CBL for perf approval. Thanks, Jake From: Donna Ambruz <dambruz@hilcorp.com> Sent: Wednesday, September 7, 2022 3:26 PM To: Jacob Flora <Jake.Flora@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Vanessa Hughes <vhughes@hilcorp.com> Subject: 10-403 BRU 244-27 322-378 PTD 222-038 Approved 09-07-22 FYI – Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/3/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221003 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 501332053001 214070 8/10/2022 Halliburton CH PPROF BRU 222-34 502832018600 222039 9/15/2022 Halliburton CH RBT BRU 244-27 502832018500 222038 9/13/2022 Halliburton CH RBT END 1-45 500292199100 189124 8/11/2022 Halliburton CH PERF KBU 22-06Y 501332065000 215044 8/22/2022 Halliburton CH PPROF KBU 43-07Y 501332062500 214019 9/7/2022 Halliburton CH PPROF MPU C-24A 500292302001 209134 8/3/2022 Halliburton CH COILFLAG MPU L-46 500292355100 215118 9/10/2022 Halliburton CH MFC24 MPU S-34 500292317100 203130 9/3/2022 Halliburton CH MFC24 NS-10 500292298500 200182 8/18/2022 Halliburton CH WFL- TMD3D NS-32 500292317900 203158 8/17/2022 Halliburton CH WFL- TMD3D PBU 04-30 500292134500 185089 9/17/2022 Halliburton CH RMT3D PBU 05-24A 500292220401 204218 9/12/2022 Halliburton CH CAST PBU 11-16 500292158100 186078 9/10/2022 Halliburton CH PPROF PBU 11-27A 500292163801 222036 8/20/2022 Halliburton CH RBT PBU C-24B 500292081602 212063 8/16/2022 Halliburton CH PPROF PBU E-100A 500292281901 218157 9/20/2022 Halliburton CH LDL PBU S-106 500292299900 201012 9/12/2022 Halliburton CH RBT Please include current contact information if different from above. T37103 T37104 T37105 T37106 T37107 T37108 T37109 T37110 T37111 T37112 T37113 T37114 T37115 T37116 T37117 T37118 T37119 T37120 BRU 244-27 502832018500 222038 9/13/2022 Halliburton CH RBT Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.05 11:39:32 -08'00'  5HJJ-DPHV% 2*& )URP%URRNV3KRHEH/ 2*& 6HQW7XHVGD\6HSWHPEHU30 7R5\DQ7KRPSVRQ &F5HJJ-DPHV% 2*& 6XEMHFW5(%23(7HVW5HSRUW%58 $WWDFKPHQWV6FKOXPEHUJHU[OV[ ZLJĂŶ͕ ƚƚĂĐŚĞĚŝƐĂƌĞǀŝƐĞĚƌĞƉŽƌƚĐŽƌƌĞĐƚŝŶŐƚŚĞĨŽƌŵĂƚƚŝŶŐ;ŵŽǀŝŶŐƚŚĞŽƚƚůĞƉƌĞĐŚĂƌŐĞϭϯϱϬƚŽƚŚĞƌĞŵĂƌŬƐƐŝŶĐĞƚŚŝƐŝƐũƵƐƚ ĂWͬ&ĨŝĞůĚĂŶĚĂĚĚŝŶŐϬƚŽƚŚĞĐŽŶƚƌŽůƐLJƐƚĞŵƌĞƐƉŽŶƐĞƚŝŵĞĨŝĞůĚƐͿ͘WůĞĂƐĞƵƉĚĂƚĞLJŽƵƌĐŽƉLJ͘ dŚĂŶŬLJŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůLJƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗ZLJĂŶdŚŽŵƉƐŽŶфZLJĂŶ͘dŚŽŵƉƐŽŶΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗tĞĚŶĞƐĚĂLJ͕^ĞƉƚĞŵďĞƌϭϰ͕ϮϬϮϮϵ͗ϰϬD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂLJфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂLJΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗KWdĞƐƚZĞƉŽƌƚZhϮϰϰͲϮϳ WůĞĂƐĞĨŝŶĚƚŚĞKWƚĞƐƚƌĞƉŽƌƚĨŽƌZhϮϰϰͲϮϳ͘ dŚĂŶŬƐ͕ ZLJĂŶ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ƌĞǀŝƐĞĚƌĞƉŽƌƚĐ ;ŵŽǀŝŶŐƚŚĞŽƚƚůĞƉƌĞĐŚĂƌŐĞϭϯϱϬƚŽƚŚĞƌĞŵĂƌŬƐƐ ĂĚĚŝŶŐϬƚŽƚŚĞĐŽŶƚƌŽůƐLJƐƚĞŵƌĞƐƉŽŶƐĞƚŝŵĞĨŝĞůĚƐͿ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:13 DATE: 9/11/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2220380 Sundry #322-378 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3000 Annular: Valves:250/3000 MASP:2347 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 0NA Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0 NA NA Pit Level Indicators NA NA #1 Rams 1 1.75" B/S P Flow Indicator NA NA #2 Rams 1 1.75" B/S P Meth Gas Detector NA NA #3 Rams 1 1.75" Slip P H2S Gas Detector NA NA #4 Rams 1 1.75" Pipe P MS Misc 0NA #5 Rams 0 NA NA #6 Rams 0 NA NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 2"P Time/Pressure Test Result HCR Valves 0 NA NA System Pressure (psi)3000 P Kill Line Valves 0 NA NA Pressure After Closure (psi)1550 P Check Valve 0 NA NA 200 psi Attained (sec)10 P BOP Misc 0 NA NA Full Pressure Attained (sec)30 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 0 NA No. Valves 5P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 0 NA #1 Rams 15 P Coiled Tubing Only:#2 Rams 13 P Inside Reel valves 1P #3 Rams 4 P #4 Rams 4 P Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:2.5 Hours HCR Choke 0 NA Repair or replacement of equipment will be made within NA days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9/7/22 13:34 Waived By Test Start Date/Time:9/11/2022 15:00 (date) (time)Witness Test Finish Date/Time:9/11/2022 17:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Schlumberger 48 Hour Notice. Bottle precharge - 1350 psi. Sean Boyden Hilcorp Ryan Thompson BRU 244-27 Test Pressure (psi): sboyden@slb.com ryan.thompson@hilcorp.com Form 10-424 (Revised 08/2022) 2022-0911_BOP_Schlumberger13_BRU_244-27 9 +LOFRUS$ODVND//& 9 9 9 9 9 9 91$ 9 9 9 MEU -5HJJ Hilrarp All,Wkn, LI ; Date: 08/15/2022 David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 CenterPoint Drive, Suite 1400 Anchorage, AK 99503 l Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com To: Alaska Oil & Gas Conservation Commission Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL RECEIVED j 15 2022 BRU 244-27 AQGCC - PTD 222-038 - API 50-283-20185-00-00 Washed and Dried Well Samples (06/05/2022 to 06/17/2022) B Set (4 Boxes): WELL BOX SAMPLE INTERVAL (FEET / MD) BRU 244-27 BOX 1 OF 4 2930' - 4340' MD BRU 244-27 BOX 2 OF 4 4340' - 5690' MD BRU 244-27 BOX 3 OF 4 5690' — 6650' MD BRU 244-27 BOX 4 OF 4 6650' — 7303' MD (TD) Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal. 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ubmit to: OOPERATOR: FIEL D / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2220380 Type Inj N Tubing 0 3190 3178 3174 Type Test P Packer TVD 2415 BBL Pump 1.2 IA 0 110 110 110 Interval I Test psi 3000 BBL Return 1.2 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2220380 Type Inj N Tubing 0 40 40 40 Type Test P Packer TVD 2415 BBL Pump 0.9 IA 0 2795 2789 2787 Interval I Test psi 2500 BBL Return 0.8 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp Alaska, LLC Beluga River Field / Beluga River Unit / F Pad Rance Pederson / Chris Yearout 06/22/22 Notes:4 1/2" tieback string and liner. ZXP Liner Top Packer at 2415' tvd; AOGCC witness waived by J. Regg 928 am 6/20 Notes: Notes: Notes: BRU 244-27 BRU 244-27 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec hanical Integrity Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:7 5/8" x 4 1/2" annulus. ZXP Liner Top Packer at 2415' tvd; AOGCC witness waived by J. Regg 928 am 6/20 Notes: Notes: Form 10-426 (Revised 01/2017)2022-0622_MITP_BRU_244-27_2tests_revised 9 9 9 9 9 9 9 9 9 9 9 9 -5HJJ -5HJJ  5HJJ-DPHV% 2*& )URP-HVVH5LFKDUGVRQ & MHVULFKDUGVRQ#KLOFRUSFRP! 6HQW0RQGD\-XQH30 7R5HJJ-DPHV% 2*& '2$$2*&&3UXGKRH%D\%URRNV3KRHEH/ 2*& 6XEMHFW+LOFRUSULJ%23WHVWUHVXOWV $WWDFKPHQWV+LOFRUS[OV[ WůĞĂƐĞƐĞĞƚŚĞĂƚƚĂĐŚĞĚKWƚĞƐƚƌĞƐƵůƚƐ͘ :ĞƐƐZŝĐŚĂƌĚƐŽŶ ,ŝůĐŽƌƉZŝŐϭϰϳ^D ŽŶƚĂĐƚηϳϳϲͲϲϳϳϲ 7KHLQIRUPDWLRQFRQWDLQHGLQWKLVHPDLOPHVVDJHLVFRQILGHQWLDODQGPD\EHOHJDOO\SULYLOHJHGDQGLVLQWHQGHGRQO\IRUWKHXVHRIWKHLQGLYLGXDORUHQWLW\QDPHG DERYH,I\RXDUHQRWDQLQWHQGHGUHFLSLHQWRULI\RXKDYHUHFHLYHGWKLVPHVVDJHLQHUURU\RXDUHKHUHE\QRWLILHGWKDWDQ\GLVVHPLQDWLRQGLVWULEXWLRQRUFRS\RIWKLV HPDLOLVVWULFWO\SURKLELWHG,I\RXKDYHUHFHLYHGWKLVHPDLOLQHUURUSOHDVHLPPHGLDWHO\QRWLI\XVE\UHWXUQHPDLORUWHOHSKRQHLIWKHVHQGHU VSKRQHQXPEHULVOLVWHG DERYHWKHQSURPSWO\DQGSHUPDQHQWO\GHOHWHWKLVPHVVDJH :KLOHDOOUHDVRQDEOHFDUHKDVEHHQWDNHQWRDYRLGWKHWUDQVPLVVLRQRIYLUXVHVLWLVWKHUHVSRQVLELOLW\RIWKHUHFLSLHQWWRHQVXUHWKDWWKHRQZDUGWUDQVPLVVLRQ RSHQLQJRUXVHRIWKLVPHVVDJHDQGDQ\DWWDFKPHQWVZLOOQRWDGYHUVHO\DIIHFWLWVV\VWHPVRUGDWD1RUHVSRQVLELOLW\LVDFFHSWHGE\WKHFRPSDQ\LQWKLVUHJDUGDQG WKHUHFLSLHQWVKRXOGFDUU\RXWVXFKYLUXVDQGRWKHUFKHFNVDVLWFRQVLGHUVDSSURSULDWH 6RPHSHRSOHZKRUHFHLYHGWKLVPHVVDJHGRQ WRIWHQJHWHPDLOIURPMHVULFKDUGVRQ#KLOFRUSFRP/HDUQZK\WKLVLVLPSRUWDQW &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH %HOXJD5LYHU8QLW 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:147 DATE: 6/13/22 Rig Rep.: Rig Phone: 907-283-1386 Operator: Op. Phone:907-776-6776 Rep.: E-Mail Well Name: PTD #22220380 Sundry # Operation: Drilling: x Workover: Explor.: Test: Initial: Weekly: x Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2338 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 4.5"P Flow Indicator PP #2 Rams 1 Blind P Meth Gas Detector PP #3 Rams 1 4.5"FP H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8"P Inside Reel valves 0NA HCR Valves 2 2 1/16" & 3 1/8"P Kill Line Valves 1 2 1/16"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3050 P CHOKE MANIFOLD:Pressure After Closure (psi)1650 P Quantity Test Result 200 psi Attained (sec)21 P No. Valves 13 P Full Pressure Attained (sec)91 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4 @ 2525 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:5.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 6-10-22 16:40 Waived By Test Start Date/Time:6/12/2022 20:00 (date) (time)Witness Test Finish Date/Time:6/13/2022 1:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Tested with 4.5" test joint,at 250 psi Low 3500 psi High, held for 5 min Low & 10 min High. Had 1 FP on lower ram/low test. Funtioned rams and retested OK. Quadco was out on 6-11-22 at 09:30 hrs. and tested audio/visual gas alarms (due to flight availablity). Jon Van Evera Hilcorp Alaska, LLC J Richardson / C Yearout BRU 244-27 Test Pressure (psi): jesrichardson@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0613_BOP_Hilcorp147_BRU_244-27 9 9 9 9 9 9 9 9 9 9 9 MEU -5HJJ FP Had 1 FP on lower ram/low test. Funtioned rams and retested OK. David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/08/2022 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL BRU 244-27 - PTD 222-038 - API 50-283-20185-00-00 FINAL LWD FORMATION EVALUATION LOGS (05/31/2022 to 06/17/2022) PGC, AGR, EWR-M5, ADR, ALD, CTN, ROP (2” & 5” MD/TVD Color Logs) Final Definitive Directional Survey Folder Contents: Please include current contact information if different from above. PTD:222-038 T36745 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.08 15:16:54 -08'00' David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 07/08/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BRU 244-27 - PTD 222-038 - API 50-283-20185-00-00 MUDLOGS - EOW DRILLING REPORTS (05/31/2022 to 06/20/2022) 1. FINAL EOW REPORT 2. DAILY REPORTS 3. SHOW REPORTS 4. DIGITAL DATA (LAS) 5. MUDLOG PRINTS (2” and 5” MD and TVD COLOR PRINTS – TIFF AND PDF FORMATS) Formation Log LWD Combo Log Gas Ratio Log Drilling Dynamics Log SFTP Transfer - Data Folders: Please include current contact information if different from above. PTD:222-038 T36742 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.08 14:32:41 -08'00'  5HJJ-DPHV% 2*& )URP-HVVH5LFKDUGVRQ & MHVULFKDUGVRQ#KLOFRUSFRP! 6HQW7XHVGD\-XQH$0 7R5HJJ-DPHV% 2*& '2$$2*&&3UXGKRH%D\%URRNV3KRHEH/ 2*& 6XEMHFW+LOFRUSULJ%23WHVWUHVXOWV $WWDFKPHQWV&RS\RI+LOFRUS[OV[ WůĞĂƐĞƐĞĞƚŚĞĂƚƚĂĐŚĞĚKWƚĞƐƚƌĞƐƵůƚƐ͘ :ĞƐƐZŝĐŚĂƌĚƐŽŶ ,ŝůĐŽƌƉZŝŐϭϰϳ^D ŽŶƚĂĐƚηϳϳϲͲϲϳϳϲ 7KHLQIRUPDWLRQFRQWDLQHGLQWKLVHPDLOPHVVDJHLVFRQILGHQWLDODQGPD\EHOHJDOO\SULYLOHJHGDQGLVLQWHQGHGRQO\IRUWKHXVHRIWKHLQGLYLGXDORUHQWLW\QDPHG DERYH,I\RXDUHQRWDQLQWHQGHGUHFLSLHQWRULI\RXKDYHUHFHLYHGWKLVPHVVDJHLQHUURU\RXDUHKHUHE\QRWLILHGWKDWDQ\GLVVHPLQDWLRQGLVWULEXWLRQRUFRS\RIWKLV HPDLOLVVWULFWO\SURKLELWHG,I\RXKDYHUHFHLYHGWKLVHPDLOLQHUURUSOHDVHLPPHGLDWHO\QRWLI\XVE\UHWXUQHPDLORUWHOHSKRQHLIWKHVHQGHU VSKRQHQXPEHULVOLVWHG DERYHWKHQSURPSWO\DQGSHUPDQHQWO\GHOHWHWKLVPHVVDJH :KLOHDOOUHDVRQDEOHFDUHKDVEHHQWDNHQWRDYRLGWKHWUDQVPLVVLRQRIYLUXVHVLWLVWKHUHVSRQVLELOLW\RIWKHUHFLSLHQWWRHQVXUHWKDWWKHRQZDUGWUDQVPLVVLRQ RSHQLQJRUXVHRIWKLVPHVVDJHDQGDQ\DWWDFKPHQWVZLOOQRWDGYHUVHO\DIIHFWLWVV\VWHPVRUGDWD1RUHVSRQVLELOLW\LVDFFHSWHGE\WKHFRPSDQ\LQWKLVUHJDUGDQG WKHUHFLSLHQWVKRXOGFDUU\RXWVXFKYLUXVDQGRWKHUFKHFNVDVLWFRQVLGHUVDSSURSULDWH 6RPHSHRSOHZKRUHFHLYHGWKLVPHVVDJHGRQ WRIWHQJHWHPDLOIURPMHVULFKDUGVRQ#KLOFRUSFRP/HDUQZK\WKLVLVLPSRUWDQW &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH %HOXJD5LYHU8QLW 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:147 DATE: 6/21/22 Rig Rep.: Rig Phone: 907-283-1386 Operator: Op. Phone:907-776-6776 Rep.: E-Mail Well Name:PTD #22220380 Sundry # Operation: Drilling: x Workover: Explor.: Test: Initial: Weekly: x Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2338 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 4.5"P Flow Indicator PP #2 Rams 1 Blind P Meth Gas Detector PP #3 Rams 1 4.5"FP H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8"P Inside Reel valves 0NA HCR Valves 2 2 1/16" & 3 1/8"P Kill Line Valves 1 2 1/16"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3050 P CHOKE MANIFOLD:Pressure After Closure (psi)1800 P Quantity Test Result 200 psi Attained (sec)24 P No. Valves 13 P Full Pressure Attained (sec)87 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4 @ 2500 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:7.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 6-20-22 9:28 Waived By Test Start Date/Time:6/20/2022 20:00 (date) (time)Witness Test Finish Date/Time:6/21/2022 3:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Tested with 4.5" test joint,at 250 psi Low 3500 psi High, held for 5 min Low & 10 min High. Had 1 FP on lower ram/low test. Funtioned rams and retested OK. Quadco bump tested audio and visual gas alarms on 6-21-22. Kenneth Porterfield Hilcorp Alaska, LLC J Richardson / C Yearout BRU 244-27 Test Pressure (psi): jesrichardson@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0621_BOP_Hilcorp147_BRU_244-27 9 9 9 9 9 9 9 9 9 9 9 MEU FP FP on lower ram/low test. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________BELUGA RIV UNIT 244-27 JBR 06/22/2022 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:3 Upper Pipe and Blind Rams both leaking out shaft seal weep holes. Replace shaft seals on both. Choke line connection needed API ring gasket replaced. Annular close time: 14sec. Rams: 4.5sec. HCR: 1 sec Test Results TEST DATA Rig Rep:Jon Van EveraOperator:Hilcorp Alaska, LLC Operator Rep:R. Pederson/ J. Riley Contractor/Rig No.:Hilcorp 147 PTD#:2220380 DATE:6/5/2022 Type Operation:DRILL Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopAGE220613085813 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 15 MASP: 2338 Sundry No: Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P 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 1 FPCH Misc Stripper 0 NA Annular Preventer 1 11"P #1 Rams 1 4.5"FP #2 Rams 1 Blind FP #3 Rams 1 4.5"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 2 1/16 & 3 1/8 P Kill Line Valves 1 2 1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3100 Pressure After Closure P1750 200 PSI Attained P36 Full Pressure Attained P95 Blind Switch Covers:PAll Stations Nitgn. Bottles (avg):P4 @ 2550 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA 9 9 9 9 9 9 9 9 9 9 9 9 9 FP FP FP Upper Pipe and Blind Rams both leaking Choke line connection Annular close time: 14sec. Rams: 4.5sec. HCR: 1 sec P.I. SupvComm:Rig Coil Tubing Unit? NoRig Contractor Rig RepresentativeOperator Contractor RepresentativeWell Permit to Drill # 2220380 Sundry Approval #Operation Inspection LocationWorking Pressure, W/H Flange P Pit Fluid Measurement P Working Pressure PP Flow Rate Sensor P Operating Pressure PP Mud Gas Separator P Fluid Level/Condition PP Degasser P Pressure Gauges PP Separator Bypass P Sufficient Valves PP Gas Detectors P Regulator Bypass PP Alarms Separate/Distinct P Actuators (4-way valves) PP Choke/Kill Line Connections PBlind Ram Handle Cover PP Reserve Pits P Control Panel, Driller PP Trip Tank P Control Panel, Remote PPFirewallPP2 or More Pumps PP Kelly or TD Valves P Independent Power Supply PP Floor Safety Valves P N2 Backup PP Driller's Console P Condition of Equipment PP Flow Monitor PFlow Rate Indicator PPit Level Indicators P Valves PPPE P Gauges P Remote Hydraulic Choke PWell Control Trained P Gas Detection Monitor P FOV Upstream of Chokes PHousekeeping P Hydraulic Control Panel P Targeted Turns PWell Control Plan P Kill Sheet Current P Bypass Line PFAILURES:0CORRECT BY:COMMENTSAdam Earl6/5/2022Parker Drilling labor contract. Rig looked to be in good condition. Rig inspection items found in compliance. Witnessed initial BOPE test to 5k psi - refer to AOGCC Inspection Report bopAGE220613085813 (several performance test failures). INSPECT DATEAOGCC INSPECTOR147Hilcorp Alaska LLC.Hilcorp Alaska LLC.MISCELLANEOUSFlange/Hub ConnectionsDrilling Spool OutletsFlow NippleControl LinesRIG FLOORALASKA OIL AND GAS CONSERVATION COMMISSIONRIG INSPECTION REPORTHCR Valve(s)Manual ValvesAnnular PreventerWorking Pressure, BOP StackStack AnchoredChoke LineKill LineTargeted TurnsPipe RamsBlind RamsVan EveraPeterson/RileyLocking Devices, RamsBOP STACKCHOKE MANIFOLDBRUMUD SYSTEMBRU 244-27DrillingCLOSING UNIT2022-0605_Rig_Hilcorp147_BRU_244-27_ae rev. 5-8-1899999999-%5Witnessed initial BOPE ggggtest to 5k psi - refer to AOGCC Inspection Report bopAGE220613085813James B. ReggDigitally signed by James B. Regg Date: 2022.08.08 14:45:53 -08'00'  5HJJ-DPHV% 2*& )URP5DQFH3HGHUVRQ & USHGHUVRQ#KLOFRUSFRP! 6HQW7XHVGD\0D\30 7R5HJJ-DPHV% 2*& '2$$2*&&3UXGKRH%D\%URRNV3KRHEH/ 2*& &F)UDQN5RDFK-RQ9DQ(YHUD & 6XEMHFW5LJ'LYHUWHU7HVW5HSRUW &RPSOHWHG $WWDFKPHQWV'LYHUWHU+LOFRUS[OV[ WůĞĂƐĞƐĞĞƚŚĞĂƚƚĂĐŚĞĚ͕ĐŽŵƉůĞƚĞĚĚŝǀĞƌƚĞƌƚĞƐƚƌĞƉŽƌƚ͊ ZĂŶĐĞWĞĚĞƌƐŽŶ ƌŝůůŝŶŐ&ŽƌĞŵĂŶ ĞůƵŐĂZŝǀĞƌhŶŝƚ ϵϬϳͲϳϳϲͲϲϳϳϲ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ate: 5/31/2022 Development: X Exploratory: Drlg Contractor: Rig No. 147 AOGCC Rep: Operator:Oper. Rep: Field/Unit/Well No.:Rig Rep: PTD No.: 2220380 Rig Phone: Rig Email: MMISCEL L ANEOUS:DIVERTERR SYSTEM: Location Gen.: P Well Sign: P Designed to Avoid Freeze-up? P Housekeeping: P Drlg. Rig. P Remote Operated Diverter? P Warning Sign P Misc: NA No Threaded Connections? P 24 hr Notice: P Vent line Below Diverter? P AACCUMUL ATORR SYSTEM:Diverter Size: 21 1/4 in. Systems Pressure: 3000 psig P Hole Size: 9 7/8 in. Pressure After Closure: 1500 psig P Vent Line(s) Size: 16 in. P 200 psi Recharge Time: 29 Seconds P Vent Line(s) Length: 96.1 ft. P Full Recharge Time:110 Seconds P Closest Ignition Source: 78.6 ft. P Nitrogen Bottles (Number of): 4 Outlet from Rig Substructure: 93 ft. P Avg. Pressure: 2525 psig P Accumulator Misc: NA Vent Line(s) Anchored: P MMUDD SYSTEM:Visual Alarm Turns Targeted / Long Radius: NA Trip Tank: P P Divert Valve(s) Full Opening: P Mud Pits: P P Valve(s) Auto & Simultaneous: Flow Monitor: P P Annular Closed Time: 33 sec P Mud System Misc: 0 NA Knife Valve Open Time: 18 sec P Diverter Misc: NA GGASS DETECTORS:Visual Alarm Methane: P P Hydrogen Sulfide: P P Gas Detectors Misc: 0 NA Total Test Time: 1.5 hrs Non-Compliance Items: 0 Remarks: Submit to: SSTATEE OFF AL ASK A AAL ASK AA OILL ANDD GASS CONSERVATIONN COMMISSION DDi v er t err Sys t em ss In s p ec t i o nn Rep o r t GGENERALL INFORMATION WaivedHilcorp **Al ll Di v ert err r ep o r t ss ar ee d u ee t oo t h ee ag en c yy w i t h i nn 55 d ayss o ff t est i n g * rpederson@hilcorp.com TTESTT DATA Jon Van Evera phoebe.brooks@alaska.gov Hilcorp Alaska, LLC Function tested annular and knife valve with a joint of 4 1/2" DP in hole. Verified annular holding by slack off of blocks. Performed draw down test of koomey unit. Quadco Rep tested all gas alarms and lights on 5-31-22. Measured vent line and outlet from sub base. Function tested PVT and flow show audio and visual alarms. We have three "well on diverter" signs posted. One at pad entrance, one on each side of rig. We have barricades 75' from vent line outlet to block any traffic. 0 Rance Pederson 0 907-776-6776 TTESTT DETAIL S jim.regg@alaska.gov AOGCC.Inspectors@alaska.gov Beluga River Field, Beluga River Unit, Well BRU 244-27 Form 10-425 (Revised 05/2021)2022-0531_Diverter_Hilcorp147_BRU_244-27 9 9 9 9 - 5HJJ 9 9 BRU 244-27 9 9 9 9 -5HJJ Žƒ•ƒ‹Žƒ† ƒ• ‘•‡”˜ƒ–‹‘‘‹••‹‘ 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov   Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beluga River Field, Sterling-Beluga River Gas Pool, BRU 244-27 Hilcorp Alaska, LLC Permit to Drill Number: 222-038 Surface Location: 941' FNL, 1383' FEL, Sec 34, T13N, R10W, SM, AK Bottomhole Location: 977' FSL, 371' FWL, Sec 27, T13N, R1OW, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. Hilcorp Alaska, LLC as Operator assumes the liability of any protest to the spacing exception that may occur. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of May, 2022.  Jeremy Price Digitally signed by Jeremy Price Date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3DJH9HUVLRQ0DUFK  BRU 244-27 Drilling Procedure Rev 0 &KRNH0DQLIROG6FKHPDWLF     3DJH9HUVLRQ0DUFK  BRU 244-27 Drilling Procedure Rev 0 &DVLQJ'HVLJQ,QIRUPDWLRQ     3DJH9HUVLRQ0DUFK  BRU 244-27 Drilling Procedure Rev 0 ´+ROH6HFWLRQ0$63     3DJH9HUVLRQ0DUFK  BRU 244-27 Drilling Procedure Rev 0 6SLGHU3ORW *RYHUQPHQWDO6HFWLRQV      3DJH9HUVLRQ0DUFK  BRU 244-27 Drilling Procedure Rev 0 ¶5DGLXVIRU6669     3DJH9HUVLRQ0DUFK  BRU 244-27 Drilling Procedure Rev 0 6XUIDFH3ODW $V%XLOW1$' 1$'      3DJH9HUVLRQ0DUFK  BRU 244-27 Drilling Procedure Rev 0                !""#  $% &  '( )#*(     + , -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250True Vertical Depth (1500 usft/in)0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 Vertical Section at 27.94° (1500 usft/in) BRU 244-27 Tgt 4 1/2" Casing 5 0 0 1 0 0 0 15 0 0 2 0 0 0 2 5 0 0 3 0 0 0 3 5 0 0 4 0 0 0 4 5 0 0 5 0 0 0 5 5 0 0 6 0 0 0 6 5 0 0 7 0 0 0 7 3 0 8 BRU 244-27 WP10 Start Build 4.00 at 300 MD Start 1758.32 hold at 1088.36 MD Start DLS 3.00 TFO -178.70 at 2846.68 MD Start 2731.87 hold at 3498.23 MD Start 1077.55 hold at 6230.10 MD TD at 7307.65 at 7307.65 MD Hilcorp Alaska, LLC Calculation Method:Minimum Curvature Error System:ISCWSA Scan Method: Closest Approach 3D Error Surface: Ellipsoid Separation Warning Method: Error Ratio SURVEY PROGRAM Date: 2022-03-14T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 18.50 7307.65 BRU 244-27 WP10 (Wellbore #1) 3_MWD+AX+Sag FORMATION TOP DETAILS No formation data is available REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan BRU 244-27, True North Vertical (TVD) Reference:. @ 102.60usft Measured Depth Reference:. @ 102.60usft Calculation Method:Minimum Curvature Project:Beluga River Site:BRU F-Pad - NADCON Well:Plan BRU 244-27 Wellbore:Wellbore #1 Design:BRU 244-27 WP10 Beluga River BRU F-Pad - NADCON Plan BRU 244-27 Wellbore #1 BRU 244-27 WP10 CASING DETAILS 6875.54 7307.00 4 1/2" Casing 4-1/2 TVD TVDSS MD Size 6875.54 6772.94 7307.00 4-1/2 4 1/2" Casing SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 18.50 0.00 0.00 18.50 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 4.00 at 300 MD 3 1088.36 31.53 28.77 1049.15 185.41 101.81 4.00 28.77 211.50 Start 1758.32 hold at 1088.36 MD 4 2846.68 31.53 28.77 2547.82 991.50 544.43 0.00 0.00 1131.02 Start DLS 3.00 TFO -178.70 at 2846.68 MD 5 3498.23 12.00 26.68 3150.00 1203.43 657.96 3.00 -178.70 1371.44 Start 2731.87 hold at 3498.23 MD 6 6230.10 12.00 26.68 5822.17 1710.94 912.99 0.00 0.00 1939.29 BRU 244-27 Tgt Start 1077.55 hold at 6230.10 MD 7 7307.65 12.00 26.68 6876.17 1911.12 1013.58 0.00 0.00 2163.27 TD at 7307.65 at 7307.65 MD WELL DETAILS: Plan BRU 244-27 84.10 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2624242.83 316530.97 61° 10' 43.433 N 151° 2' 22.071 W -175 0 175 350 525 700 875 1050 1225 1400 1575 1750 1925 2100 2275 2450 2625 South(-)/North(+) (350 usft/in)-175 0 175 350 525 700 875 1050 1225 1400 1575 1750 1925 2100 2275 West(-)/East(+) (350 usft/in) BRU 244-27 Tgt BRU 241-34 BRU 241-34TB R U 2 2 2-3 4 w p 0 8 4 1/2" Casing 750 1250 1500 1750 2000 2250 2500 2750 3000 3500 4000 4500 5000 5500 6000 6500 6876 BRU 244-27 WP10 Start Build 4.00 at 300 MD Start DLS 3.00 TFO -178.70 at 2846.68 MD Start 2731.87 hold at 3498.23 MD Start 1077.55 hold at 6230.10 MD TD at 7307.65 at 7307.65 MD CASING DETAILS TVD TVDSS MD Size Name 6875.54 6772.94 7307.00 4-1/2 4 1/2" Casing Project: Beluga River Site: BRU F-Pad - NADCON Well: Plan BRU 244-27 Wellbore: Wellbore #1 Plan: BRU 244-27 WP10 WELL DETAILS: Plan BRU 244-27 84.10 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2624242.83 316530.97 61° 10' 43.433 N 151° 2' 22.071 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan BRU 244-27, True North Vertical (TVD) Reference: . @ 102.60usft Measured Depth Reference:. @ 102.60usft Calculation Method:Minimum 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FRPSRVLWHFXUYHVIRUZHOOORJVUXQPXVWEHVXEPLWWHGWRWKH$2*&& ZLWKLQGD\VDIWHUFRPSOHWLRQVXVSHQVLRQRUDEDQGRQPHQWRIWKLV ZHOO  %HOXJD5LYHU8QGHILQHG*DV +LOFRUS$ODVND//&  %HOXJD5LYHU %HOXJD5LYHU8QLW Sterling-Beluga Gas WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:BELUGA RIV UNIT 244-27Initial Class/TypeDEV / PENDGeoArea820Unit50220On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2220380BELUGA RIVER, STRLG-BELUGA GAS - 92500NA1 Permit fee attachedYesEntire Well lies within FEDA029657.2 Lease number appropriateYes3 Unique well name and numberYesBELUGA RIVER, Sterling-Beluga Gas Pool – 925004 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYesPool Rules in progress. Hearing set for April 12, 2022. Pool Rules issued 5/5/2022.11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYesliner tied in to surface casing.21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedYes27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes5000 psi BOPE, MPSP=2338 psi (BOP test to 5000 psi initial, 3500 psi subsequent)30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)YesNone expected35 Permit can be issued w/o hydrogen sulfide measuresYesMaximum expected reservoir pressure is 8.5 ppg EMW; however, many sands encountered are expected36 Data presented on potential overpressure zonesNAto be depleted to severely depleted. LCM materials will also be available onsite. Production interval will be37 Seismic analysis of shallow gas zonesNAdrilled using 9.0 to 10.0 ppg mud. Additional materials will be onsite to build38 Seabed condition survey (if off-shore)NAmud to 1 ppg more than the greatest anticipated mud weight.39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate5/11/2022ApprBJMDate5/10/2022ApprSFDDate4/4/2022AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:JLCDate:05-11-2022Public CommissionerJMPDate05-11-2022Pool Rules issued on May 5, 2022. A spacing exception is no longer needed for this well. SFD 5/6/2022