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HomeMy WebLinkAbout222-003Nolan 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 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET 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' 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:Ryan Lemay Cc:Scott Warner; Donna Ambruz Subject:RE: Kalotsa 8 / Program Change / Perforation Interval Depths Update / PTD: 222-003 / Sundry 325-737 Date:Thursday, December 11, 2025 12:13:00 PM Ryan, Hilcorp has approval to make the requested changes to the perf table in the sundry. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Lemay <ryan.lemay@hilcorp.com> Sent: Wednesday, December 10, 2025 8:41 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Scott Warner <Scott.Warner@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com> Subject: Kalotsa 8 / Program Change / Perforation Interval Depths Update / PTD: 222-003 / Sundry 325-737 Good morning Bryan, Thank you for taking my call yesterday afternoon and discussing this. The approved Sundry attached for Kalotsa 8 has the incorrect perforation table / depths attached for this job. The planned series of sands to be proposed and shot are similar (Bel 60 – Bel 135) it’s just the individual perforation zones depths were off in original submission. Below is the corrected perf table with updated perforation depths for these sands. Attachments: Original approved Sundry Corrected Program Corrected Proposed Schematic Corrected Proposed Perforation Table: Well Name Zone Top MD Bottom MD Top TVD Bottom TVD Footage Kalotsa 8 BEL 60 3,666 3,676 2,430 2,437 10 Kalotsa 8 BEL 60 3,676 3,701 2,437 2,456 25 Kalotsa 8 BEL 65 3,722 3,730 2,472 2,478 8 Kalotsa 8 BEL 65 3,736 3,744 2,482 2,488 8 Kalotsa 8 BEL 65 3,752 3,756 2,494 2,498 4 Kalotsa 8 BEL 72 3,795 3,804 2,528 2,535 9 Kalotsa 8 BEL73 3,828 3,844 2,554 2,567 16 Kalotsa 8 BEL 74 3,853 3,866 2,574 2,584 13 Kalotsa 8 BEL 74 3,875 3,880 2,591 2,596 5 Kalotsa 8 BEL 74 3,882 3,886 2,597 2,600 4 Kalotsa 8 BEL 74 3,891 3,911 2,604 2,621 20 Kalotsa 8 BEL 78 3,950 3,957 2,652 2,658 7 Kalotsa 8 BEL 81 3,996 4,010 2,690 2,702 14 Kalotsa 8 BEL 82 4,013 4,018 2,705 2,709 5 Kalotsa 8 BEL 82 4,020 4,026 2,711 2,716 6 Kalotsa 8 BEL 82 4,033 4,042 2,722 2,729 9 Kalotsa 8 BEL 83 4,050 4,060 2,736 2,745 10 Kalotsa 8 BEL 88 4,076 4,082 2,758 2,763 6 Kalotsa 8 BEL 90 4,100 4,112 2,779 2,789 12 Kalotsa 8 BEL 90 4,138 4,158 2,812 2,829 20 Kalotsa 8 BEL 91 4,168 4,174 2,838 2,844 6 Kalotsa 8 BEL 91 4,188 4,212 2,856 2,877 24 Kalotsa 8 BEL 92 4,215 4,219 2,880 2,884 4 Kalotsa 8 BEL 92 4,238 4,244 2,901 2,906 6 Kalotsa 8 BEL 92 4,248 4,254 2,910 2,915 6 Kalotsa 8 BEL 92 4,271 4,281 2,930 2,939 10 Kalotsa 8 BEL 92 4,284 4,289 2,942 2,947 5 Kalotsa 8 BEL 93 4,328 4,337 2,983 2,991 9 Kalotsa 8 BEL 93 4,340 4,346 2,993 2,999 6 Kalotsa 8 BEL 94 4,352 4,357 3,004 3,009 5 Kalotsa 8 BEL 94 4,359 4,364 3,011 3,015 5 Kalotsa 8 BEL 94 4,371 4,377 3,022 3,028 6 Kalotsa 8 BEL 95 4,386 4,392 3,036 3,042 6 Kalotsa 8 BEL 95 4,408 4,413 3,056 3,061 5 Kalotsa 8 BEL 95 4,415 4,421 3,063 3,068 6 Kalotsa 8 BEL 97 4,469 4,474 3,114 3,118 5 Kalotsa 8 BEL 98 4,479 4,484 3,123 3,128 5 Kalotsa 8 BEL 98 4,498 4,503 3,141 3,146 5 Kalotsa 8 BEL 98 4,505 4,509 3,148 3,151 4 Kalotsa 8 BEL 99 4,522 4,528 3,164 3,169 6 Kalotsa 8 BEL 99 4,530 4,535 3,171 3,176 5 Kalotsa 8 BEL 99A 4,540 4,545 3,181 3,185 5 Kalotsa 8 BEL 99A 4,547 4,556 3,187 3,196 9 Kalotsa 8 BEL 100 4,582 4,592 3,221 3,230 10 Kalotsa 8 BEL 100 4,606 4,616 3,244 3,253 10 Kalotsa 8 BEL 100 4,622 4,632 3,259 3,269 10 Kalotsa 8 BEL 110 4,657 4,670 3,293 3,305 13 Kalotsa 8 BEL 110 4,693 4,699 3,327 3,333 6 Kalotsa 8 BEL 120 4,750 4,808 3,383 3,440 58 Kalotsa 8 BEL 132 4,834 4,839 3,465 3,470 5 Kalotsa 8 BEL 133 4,849 4,859 3,480 3,490 10 Kalotsa 8 BEL 134 4,871 4,881 3,501 3,511 10 Kalotsa 8 BEL 134 4,907 4,917 3,537 3,547 10 Kalotsa 8 BEL 135 4,933 4,937 3,562 3,566 4 Kalotsa 8 BEL 135 4,956 4,961 3,585 3,590 5 Kalotsa 8 BEL 135 4,993 4,998 3,621 3,626 5 Kalotsa 8 BEL 135 5,019 5,029 3,647 3,657 10 Kalotsa 8 BEL 135 5,029 5,061 3,657 3,688 32 Please let us know if you approve of the perforation interval changes and let me know if you need any additional information for this request. Have a great day, Ryan LeMay Operations Engineer Swanson River / Beaver Creek Cell: (661) 487-0871 E-mail: Ryan.lemay@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 intendedrecipient 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 anyattachments 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 considersappropriate. _____________________________________________________________________________________ RPL 12-10-2025 PROPOSED SCHEMATIC Corrected Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ T12 Thru T18 T3 Thru T9A BEL 60- BEL 135 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875”Surf 2,287’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”2,031’7,566’ Tubing Details 4-1/2"Tieback 12.6 L-80 DWC/C HT 3.958”Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 -11.000 Cactus EN-2CCL 11" Hgr w/4-1/2" EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’1,558’4.875”6.540”Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’1,564’4.790”6.340”Seal Assy. Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status BEL 60 3,666 3,676 2,430 2,437 10 TBD Proposed BEL 60 3,676 3,701 2,437 2,456 25 TBD Proposed BEL 65 3,722 3,730 2,472 2,478 8 TBD Proposed BEL 65 3,736 3,744 2,482 2,488 8 TBD Proposed BEL 65 3,752 3,756 2,494 2,498 4 TBD Proposed BEL 72 3,795 3,804 2,528 2,535 9 TBD Proposed BEL 73 3,828 3,844 2,554 2,567 16 TBD Proposed BEL 74 3,853 3,866 2,574 2,584 13 TBD Proposed BEL 74 3,875 3,880 2,591 2,596 5 TBD Proposed BEL 74 3,882 3,886 2,597 2,600 4 TBD Proposed BEL 74 3,891 3,911 2,604 2,621 20 TBD Proposed BEL 78 3,950 3,957 2,652 2,658 7 TBD Proposed BEL 81 3,996 4,010 2,690 2,702 14 TBD Proposed BEL 82 4,013 4,018 2,705 2,709 5 TBD Proposed BEL 82 4,020 4,026 2,711 2,716 6 TBD Proposed BEL 82 4,033 4,042 2,722 2,729 9 TBD Proposed BEL 83 4,050 4,060 2,736 2,745 10 TBD Proposed BEL 88 4,076 4,082 2,758 2,763 6 TBD Proposed BEL 90 4,100 4,112 2,779 2,789 12 TBD Proposed BEL 90 4,138 4,158 2,812 2,829 20 TBD Proposed BEL 91 4,168 4,174 2,838 2,844 6 TBD Proposed BEL 91 4,188 4,212 2,856 2,877 24 TBD Proposed BEL 92 4,215 4,219 2,880 2,884 4 TBD Proposed BEL 92 4,238 4,244 2,901 2,906 6 TBD Proposed BEL 92 4,248 4,254 2,910 2,915 6 TBD Proposed BEL 92 4,271 4,281 2,930 2,939 10 TBD Proposed BEL 92 4,284 4,289 2,942 2,947 5 TBD Proposed BEL 93 4,328 4,337 2,983 2,991 9 TBD Proposed BEL 93 4,340 4,346 2,993 2,999 6 TBD Proposed BEL 94 4,352 4,357 3,004 3,009 5 TBD Proposed BEL 94 4,359 4,364 3,011 3,015 5 TBD Proposed BEL 94 4,371 4,377 3,022 3,028 6 TBD Proposed BEL 95 4,386 4,392 3,036 3,042 6 TBD Proposed BEL 95 4,408 4,413 3,056 3,061 5 TBD Proposed OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2”TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’6,166’Stuck BHA (372’ in length) –Contains radioactive sources (2/22/22) _____________________________________________________________________________________ RPL 12-10-2025 PROPOSED SCHEMATIC Corrected Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status BEL 95 4,415 4,421 3,063 3,068 6 TBD Proposed BEL 97 4,469 4,474 3,114 3,118 5 TBD Proposed BEL 98 4,479 4,484 3,123 3,128 5 TBD Proposed BEL 98 4,498 4,503 3,141 3,146 5 TBD Proposed BEL 98 4,505 4,509 3,148 3,151 4 TBD Proposed BEL 99 4,522 4,528 3,164 3,169 6 TBD Proposed BEL 99 4,530 4,535 3,171 3,176 5 TBD Proposed BEL 99A 4,540 4,545 3,181 3,185 5 TBD Proposed BEL 99A 4,547 4,556 3,187 3,196 9 TBD Proposed BEL 100 4,582 4,592 3,221 3,230 10 TBD Proposed BEL 100 4,606 4,616 3,244 3,253 10 TBD Proposed BEL 100 4,622 4,632 3,259 3,269 10 TBD Proposed BEL 110 4,657 4,670 3,293 3,305 13 TBD Proposed BEL 110 4,693 4,699 3,327 3,333 6 TBD Proposed BEL 120 4,750 4,808 3,383 3,440 58 TBD Proposed BEL 132 4,834 4,839 3,465 3,470 5 TBD Proposed BEL 133 4,849 4,859 3,480 3,490 10 TBD Proposed BEL 134 4,871 4,881 3,501 3,511 10 TBD Proposed BEL 134 4,907 4,917 3,537 3,547 10 TBD Proposed BEL 135 4,933 4,937 3,562 3,566 4 TBD Proposed BEL 135 4,956 4,961 3,585 3,590 5 TBD Proposed BEL 135 4,993 4,998 3,621 3,626 5 TBD Proposed BEL 135 5,019 5,029 3,647 3,657 10 TBD Proposed BEL 135 5,029 5,061 3,657 3,688 32 TBD Proposed T3 5,200' 5,212' 3,824' 3,836' 12' 11/30/2023 Open T5 5,320' 5,326' 3,943' 3,948' 6' 11/30/2023 Open TY5A 5,360' 5,366' 3,982' 3,988' 6' 02/20/2025 Open TY5B 5,398' 5,404' 4,019' 4,025' 6' 02/20/2025 Open TY5B 5,418' 5,432' 4,039' 4,052' 14' 02/20/2025 Open T6U 5,440' 5,466' 4,060' 4,086' 26' 11/30/2023 Open T6L 5,484' 5,510' 4,103' 4,128' 26' 11/29/2023 Open TY7 5,564' 5,572' 4,182' 4,190' 8' 02/20/2025 Open T7 5,575' 5,595' 4,192' 4,212' 20' 11/29/2023 Open TY7 5,628' 5,634' 4,244' 4,250' 6' 02/20/2025 Open T8 5,656' 5,680' 4,272' 4,295' 24' 11/29/2023 Open TY8 5,680' 5,700' 4,295' 4,315' 20' 02/19/2025 Open T9A 5,750' 5,766' 4,363' 4,379' 16' 11/29/2023 Open TY10A 5,814' 5,820' 4,426' 4,432' 6' 02/19/2025 Open TY10A 5,838' 5,844' 4,450' 4,456' 6' 02/19/2025 Open TY10B 5,873' 5,879' 4,484' 4,490' 6' 02/19/2025 Open TY11A 5,966' 5,972' 4,576' 4,581' 6' 02/19/2025 Open T-12U 6,099' 6,117' 4,707' 4,724' 18' 5/11/2022 Open T-12L 6,121' 6,127' 4,728' 4,734' 6' 5/11/2022 Open TY13 6,302' 6,308' 4,906' 4,912' 6' 02/19/2025 Open TY14 6,326' 6,332' 4,930' 4,936' 6' 02/19/2025 Open TY14 6,397' 6,403' 5,000' 5,006' 6' 02/19/2025 Open TY16 6,498' 6,507' 5,100' 5,108' 9' 02/19/2025 Open T-16 6,511' 6,525' 5,113' 5,126' 14' 5/11/2022 Open T-17 6,590' 6,638' 5,191' 5,238' 48' 5/10/2022 Open T-17A 6,677' 6,691' 5,276' 5,290' 14' 5/10/2022 Open T-18A 6,719' 6,732' 5,317' 5,330' 13' 5/10/2022 Open T-18B 6,734' 6,744' 5,332' 5,342' 10' 5/10/2022 Open TY18 6,749' 6,765' 5,347' 5,362' 16' 02/18/2025 Open T-18C 6,768' 6,782' 5,366' 5,380' 14' 5/10/2022 Open T 37 7,008’ 7,028’ 5,612’ 5,632’ 20’ 3/4/2022 Open T 37 7,028’ 7,038’ 5,632’ 5,642’ 10’ 3/4/2022 Open TY37 7,038' 7,052' 5,631' 5,645' 14' 02/18/2025 Open TY42 7,151' 7,159' 5,743' 5,750' 8' 02/18/2025 Open Well Prognosis Corrected Perforation Table Rev 1 Well Name: Kalotsa 8 API Number: 50-133-20705-00-00 Current Status: Producing Gas Well Permit to Drill Number: 222-003 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 1623 psi @ 3688’ TVD Based on 0.44 psi/ft at deepest proposed perf Existing perforations are depleted and not at original pressure Max. Potential Surface Pressure: 1254 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: .86 psi/ft using 16.6 ppg EMW FIT at the 7-5/8” surface casing shoe Shallowest Allowable Perf TVD: MPSP/(.86-0.1) = 1254 psi / .76 = 1650‘ TVD Top of Applicable Gas Pool: 1710’ MD/1422’ TVD (Beluga-Tyonek) Well Status: Online Gas producer – 935 mscfd, 0 bwpd, 61 psi FTP Recent SITP: 281 psi max SITP when perforating in February 2025 Brief Well Summary Kalotsa 8 was drilled and completed in February 2021, targeting the lower Tyonek sands. The well IP’d at ~2.0 MMCFD and production increased to 3.0 MMCFD before going on a steady decline. Additional Tyonek sands were perf’d in May 2022 and came online at 4 mmscfd. A capstring was installed in April 2023 which helped keep the well from loading up. That capstring was pulled in November 2023 prior to adding more perforations which increased rate from 825 mscfd to 2.7 mmscfd. Additional perforations were added in February 2025 which increased rate from 1.1 mmscfd to 1.8 mmscfd. Due to deviation and inability to get soap sticks downhole, a capstring was added in May 2025 to help unloading. The objective of this sundry is to add additional perforations to the lower Beluga sands to increase the rate. Notes Regarding Wellbore Condition x Inclination o Max inclination = 67.6° at 2091’ MD o Max DLS: 9.51° @ 2377’ MD x Min ID o 3.890” – (5.5” x 4.5” DWC/C-HT Box at 2027’ MD) x Recent Tags o 2/18/25: ƒ EL added perfs w/ 2-3/4” guns. Tagged at 7282’ and found fluid level with GPT at 6965’ MD. o 2/16/25: ƒ RIH w/ 3.75" GR and fall slow from 1500' to tag @ 2,118' RKB. RIH w/ 3.75" GR, roller bogie and roller stem to tag @ 5,198' RKB. RIH w/ 2 1/2" bailer and tag @ 7,283' RKB. RIH w/ 3.75" GR and tag @ 7,282' RKB. RIH w/ 2 7/8" x 20' dummy gun and tag @ 7,272' RKB. Well Prognosis Corrected Perforation Table Rev 1 Pre-Sundry Steps: 1. MIRU Cap string truck 2. Pull 3/8” cap string from 5100’ MD 3. RD cap string truck 4. RU slickline 5. PT lubricator to 250 psi low/ 2,500 psi high 6. D&T to TD w/ large OD drift in prep for perforations. Last EL tag was 7282’ MD in February 2025. Note if fluid level is seen. 7. RDMO slickline Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /2,500 psi high 3. RIH and perforate BEL 135 – BEL 60 sands from bottom up: Well Name Zone Top MD Bottom MD Top TVD Bottom TVD Footage Kalotsa 8 BEL 60 3,666 3,676 2,430 2,437 10 Kalotsa 8 BEL 60 3,676 3,701 2,437 2,456 25 Kalotsa 8 BEL 65 3,722 3,730 2,472 2,478 8 Kalotsa 8 BEL 65 3,736 3,744 2,482 2,488 8 Kalotsa 8 BEL 65 3,752 3,756 2,494 2,498 4 Kalotsa 8 BEL 72 3,795 3,804 2,528 2,535 9 Kalotsa 8 BEL73 3,828 3,844 2,554 2,567 16 Kalotsa 8 BEL 74 3,853 3,866 2,574 2,584 13 Kalotsa 8 BEL 74 3,875 3,880 2,591 2,596 5 Kalotsa 8 BEL 74 3,882 3,886 2,597 2,600 4 Kalotsa 8 BEL 74 3,891 3,911 2,604 2,621 20 Kalotsa 8 BEL 78 3,950 3,957 2,652 2,658 7 Kalotsa 8 BEL 81 3,996 4,010 2,690 2,702 14 Kalotsa 8 BEL 82 4,013 4,018 2,705 2,709 5 Kalotsa 8 BEL 82 4,020 4,026 2,711 2,716 6 Kalotsa 8 BEL 82 4,033 4,042 2,722 2,729 9 Kalotsa 8 BEL 83 4,050 4,060 2,736 2,745 10 Kalotsa 8 BEL 88 4,076 4,082 2,758 2,763 6 Kalotsa 8 BEL 90 4,100 4,112 2,779 2,789 12 Kalotsa 8 BEL 90 4,138 4,158 2,812 2,829 20 Kalotsa 8 BEL 91 4,168 4,174 2,838 2,844 6 Kalotsa 8 BEL 91 4,188 4,212 2,856 2,877 24 Kalotsa 8 BEL 92 4,215 4,219 2,880 2,884 4 Kalotsa 8 BEL 92 4,238 4,244 2,901 2,906 6 Kalotsa 8 BEL 92 4,248 4,254 2,910 2,915 6 Kalotsa 8 BEL 92 4,271 4,281 2,930 2,939 10 Kalotsa 8 BEL 92 4,284 4,289 2,942 2,947 5 Well Prognosis Corrected Perforation Table Rev 1 Kalotsa 8 BEL 93 4,328 4,337 2,983 2,991 9 Kalotsa 8 BEL 93 4,340 4,346 2,993 2,999 6 Kalotsa 8 BEL 94 4,352 4,357 3,004 3,009 5 Kalotsa 8 BEL 94 4,359 4,364 3,011 3,015 5 Kalotsa 8 BEL 94 4,371 4,377 3,022 3,028 6 Kalotsa 8 BEL 95 4,386 4,392 3,036 3,042 6 Kalotsa 8 BEL 95 4,408 4,413 3,056 3,061 5 Kalotsa 8 BEL 95 4,415 4,421 3,063 3,068 6 Kalotsa 8 BEL 97 4,469 4,474 3,114 3,118 5 Kalotsa 8 BEL 98 4,479 4,484 3,123 3,128 5 Kalotsa 8 BEL 98 4,498 4,503 3,141 3,146 5 Kalotsa 8 BEL 98 4,505 4,509 3,148 3,151 4 Kalotsa 8 BEL 99 4,522 4,528 3,164 3,169 6 Kalotsa 8 BEL 99 4,530 4,535 3,171 3,176 5 Kalotsa 8 BEL 99A 4,540 4,545 3,181 3,185 5 Kalotsa 8 BEL 99A 4,547 4,556 3,187 3,196 9 Kalotsa 8 BEL 100 4,582 4,592 3,221 3,230 10 Kalotsa 8 BEL 100 4,606 4,616 3,244 3,253 10 Kalotsa 8 BEL 100 4,622 4,632 3,259 3,269 10 Kalotsa 8 BEL 110 4,657 4,670 3,293 3,305 13 Kalotsa 8 BEL 110 4,693 4,699 3,327 3,333 6 Kalotsa 8 BEL 120 4,750 4,808 3,383 3,440 58 Kalotsa 8 BEL 132 4,834 4,839 3,465 3,470 5 Kalotsa 8 BEL 133 4,849 4,859 3,480 3,490 10 Kalotsa 8 BEL 134 4,871 4,881 3,501 3,511 10 Kalotsa 8 BEL 134 4,907 4,917 3,537 3,547 10 Kalotsa 8 BEL 135 4,933 4,937 3,562 3,566 4 Kalotsa 8 BEL 135 4,956 4,961 3,585 3,590 5 Kalotsa 8 BEL 135 4,993 4,998 3,621 3,626 5 Kalotsa 8 BEL 135 5,019 5,029 3,647 3,657 10 Kalotsa 8 BEL 135 5,029 5,061 3,657 3,688 32 a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. Pending well production, select intervals may be re-perforated as needed g. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations Well Prognosis Corrected Perforation Table Rev 1 i. Patch will most likely be used to avoid shutting off current production h. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO a. If necessary, re-run cap string to aid with water production if encountered post perforating. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations 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: Capstring, N2 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): 8,603 7590 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 scott.warner@hilcorp.com 907-564-4506 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 Scott Warner, 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 ADL0038437 / FEE-Private 222-003 50-133-20705-00-00 Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 2,041 8,430psi 1,663 Size 120 2,287 MD See Attached Schematic 2,980psi 6,880psi 120120 2,287 December 12, 2025 4-1/2" 7,566 Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Kalotsa 8CO 701 C Same 6,1524-1/2" 1246 psi 5,535 N/A Length Liner Top Pkr & N/A 2,031 (MD) 1,558 (TVD) & N/A 7,178 7,355 5,943 Ninilchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic m n P s tc N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.12.02 16:35:19 - 09'00' Noel Nocas (4361) 325-737 By Grace Christianson at 7:49 am, Dec 04, 2025 Obtain approval from AOGCC before setting any plugs as mentioned in step 3.g. 10-404 A.Dewhurst 04DEC25BJM 12/4/25 DSR-12/5/25 12/08/25 Well Prognosis Well Name:Kalotsa 8 API Number:50-133-20705-00-00 Current Status:Producing Gas Well Permit to Drill Number:222-003 Regulatory Contact:Donna Ambruz (907) 777-8305 First Call Engineer:Scott Warner (907) 564-4506 (O)(907) 830-8863 (C) Second Call Engineer:Chad Helgeson (907) 777-8405 (O)(907) 229-4824 (C) Maximum Expected BHP:1613 psi @ 3666’ TVD Based on 0.44 psi/ft at deepest proposed perf Existing perforations are depleted and not at original pressure Max. Potential Surface Pressure:1246 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient:.86 psi/ft using 16.6 ppg EMW FIT at the 7-5/8” surface casing shoe Shallowest Allowable Perf TVD:MPSP/(.86-0.1) = 1246 psi / .76 = 1639‘ TVD Top of Applicable Gas Pool:1710’ MD/1422’ TVD (Beluga-Tyonek) Well Status:Online Gas producer – 935 mscfd, 0 bwpd, 61 psi FTP Recent SITP: 281 psi max SITP when perforating in February 2025 Brief Well Summary Kalotsa 8 was drilled and completed in February 2021, targeting the lower Tyonek sands. The well IP’d at ~2.0 MMCFD and production increased to 3.0 MMCFD before going on a steady decline. Additional Tyonek sands were perf’d in May 2022 and came online at 4 mmscfd. A capstring was installed in April 2023 which helped keep the well from loading up. That capstring was pulled in November 2023 prior to adding more perforations which increased rate from 825 mscfd to 2.7 mmscfd. Additional perforations were added in February 2025 which increased rate from 1.1 mmscfd to 1.8 mmscfd. Due to deviation and inability to get soap sticks downhole, a capstring was added in May 2025 to help unloading. The objective of this sundry is to add additional perforations to the lower Beluga sands to increase the rate. Notes Regarding Wellbore Condition Inclination o Max inclination = 67.6° at 2091’ MD o Max DLS: 9.51° @ 2377’ MD Min ID o 3.890” – (5.5” x 4.5” DWC/C-HT Box at 2027’ MD) Recent Tags o 2/18/25: EL added perfs w/ 2-3/4” guns. Tagged at 7282’ and found fluid level with GPT at 6965’ MD. o 2/16/25: RIH w/ 3.75" GR and fall slow from 1500' to tag @ 2,118' RKB. RIH w/ 3.75" GR, roller bogie and roller stem to tag @ 5,198' RKB. RIH w/ 2 1/2" bailer and tag @ 7,283' RKB. RIH w/ 3.75" GR and tag @ 7,282' RKB. RIH w/ 2 7/8" x 20' dummy gun and tag @ 7,272' RKB. Pre-Sundry Steps: 1. MIRU Cap string truck 2. Pull 3/8” cap string from 5100’ MD 3. RD cap string truck Well Prognosis 4. RU slickline 5. PT lubricator to 250 psi low/ 2,500 psi high 6. D&T to TD w/ large OD drift in prep for perforations. Last EL tag was 7282’ MD in February 2025. Note if fluid level is seen. 7. RDMO slickline Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /2,500 psi high 3. RIH and perforate BEL 135 – BEL 60 sands from bottom up: Zone Top MD Btm MD Top TVD Btm TVD Footage BEL 60 3,065'3,070'2,435'2,439'5' BEL 60 3,074'3,084'2,442'2,449'10' BEL 60 3,084'3,099'2,449'2,459'15' BEL 65 3,106'3,111'2,464'2,467'5' BEL 65 3,146'3,152'2,492'2,496'6' BEL 65 3,155'3,160'2,498'2,501'5' BEL 70 3,168'3,172'2,507'2,509'4' BEL 70 3,176'3,198'2,512'2,527'22' BEL 72 3,211'3,216'2,536'2,540'5' BEL 72 3,218'3,223'2,541'2,544'5' BEL 72 3,230' 3,238' 2,549' 2,555' 8' BEL 73 3,250' 3,258' 2,563' 2,568' 8' BEL73 3,264' 3,268' 2,572' 2,575' 4' BEL 74 3,277' 3,289' 2,581' 2,589' 12' BEL 74 3,308' 3,312' 2,602' 2,605' 4' BEL 74 3,327' 3,331' 2,615' 2,618' 4' BEL 75 3,355' 3,361' 2,635' 2,639' 6' BEL 75 3,373' 3,377' 2,647' 2,650' 4' BEL 78 3,389' 3,393' 2,659' 2,661' 4' BEL 80 3,410' 3,425' 2,673' 2,684' 15' BEL 80 3,427' 3,433' 2,685' 2,690' 6' BEL 81 3,450' 3,454' 2,701' 2,704' 4' BEL 82 3,470' 3,476' 2,715' 2,720' 6' BEL 82 3,488' 3,492' 2,728' 2,731' 4' BEL 88 3,535' 3,540' 2,761' 2,764' 5' BEL 90 3,565' 3,571' 2,782' 2,786' 6' BEL 90 3,572' 3,578' 2,786' 2,790' 6' BEL 90 3,587' 3,592' 2,797' 2,800' 5' BEL 90 3,596' 3,614' 2,803' 2,815' 18' BEL 90 3,636' 3,640' 2,830' 2,833' 4' BEL 91 3,655' 3,659' 2,843' 2,846' 4' BEL 91 3,669'3,675'2,853'2,857'6' Well Prognosis BEL 91 3,683'3,687'2,862'2,865'4' BEL 91 3,694'3,698'2,870'2,873'4' BEL 91 3,700'3,704'2,874'2,877'4' BEL 91 3,706'3,712'2,878'2,882'6' BEL 92 3,747'3,751'2,906'2,909'4' BEL 92 3,758'3,762'2,914'2,917'4' BEL 92 3,765'3,770'2,919'2,923'5' BEL 92 3,780'3,785'2,930'2,933'5' BEL 92 3,788'3,793'2,935'2,939'5' BEL 92 3,795'3,801'2,940'2,944'6' BEL 92 3,806'3,814'2,948'2,953'8' BEL 92 3,824'3,832'2,960'2,966'8' BEL 93 3,854'3,859'2,982'2,985'5' BEL 93 3,864'3,869'2,989'2,992'5' BEL 93 3,878'3,882'2,999'3,002'4' BEL 94 3,893'3,899'3,010'3,014'6' BEL 94 3,902'3,908'3,016'3,021'6' BEL 94 3,917'3,922'3,027'3,031'5' BEL 95 3,945'3,950'3,048'3,051'5' BEL 95 3,955'3,960'3,055'3,059'5' BEL 95 3,971'3,981'3,067'3,075'10' BEL 97 4,025' 4,029' 3,108' 3,111' 4' BEL 98 4,053'4,057'3,129'3,132'4' BEL 99B 4,157' 4,162' 3,209' 3,213' 5' BEL 100 4,225' 4,237' 3,263' 3,272' 12' BEL 110 4,305' 4,315' 3,327' 3,336' 10' BEL 115 4,322' 4,326' 3,341' 3,345' 4' BEL 120 4,382' 4,439' 3,391' 3,439' 57' BEL 131 4,450'4,455'3,448'3,453'5' BEL 131 4,460' 4,466' 3,457' 3,462' 6' BEL 134 4,549' 4,555' 3,533' 3,538' 6' BEL 135 4,670' 4,680' 3,637' 3,646' 10' BEL 135 4,682' 4,701' 3,647' 3,664' 19' BEL 135 4,703' 4,735' 3,666' 3,694' 32' a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. Pending well production, select intervals may be re-perforated as needed Well Prognosis g. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations i. Patch will most likely be used to avoid shutting off current production h. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO a. If necessary, re-run cap string to aid with water production if encountered post perforating. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations Obtain AOGCC approval before setting plugs. -bjm _____________________________________________________________________________________ Updated by DMA 07-11-25 SCHEMATIC Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ T12 Thru T18 T3 Thru T9A RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875”Surf 2,287’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”2,031’7,566’ Tubing Details 4-1/2"Tieback 12.6 L-80 DWC/C HT 3.958”Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 - 11.000 Cactus EN-2CCL 11" Hgr w/4-1/2" EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’ 1,558’ 4.875” 6.540” Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’1,564’4.790”6.340”Seal Assy. Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status T3 5,200'5,212'3,824'3,836'12'11/30/2023 Open T5 5,320'5,326'3,943'3,948'6'11/30/2023 Open TY5A 5,360'5,366'3,982'3,988'6'02/20/2025 Open TY5B 5,398'5,404'4,019'4,025'6'02/20/2025 Open TY5B 5,418'5,432'4,039'4,052'14'02/20/2025 Open T6U 5,440'5,466'4,060'4,086'26'11/30/2023 Open T6L 5,484'5,510'4,103'4,128'26'11/29/2023 Open TY7 5,564'5,572'4,182'4,190'8'02/20/2025 Open T7 5,575'5,595'4,192'4,212'20'11/29/2023 Open TY7 5,628' 5,634' 4,244' 4,250' 6' 02/20/2025 Open T8 5,656' 5,680' 4,272' 4,295' 24' 11/29/2023 Open TY8 5,680' 5,700' 4,295' 4,315' 20' 02/19/2025 Open T9A 5,750' 5,766' 4,363' 4,379' 16' 11/29/2023 Open TY10A 5,814' 5,820' 4,426' 4,432' 6' 02/19/2025 Open TY10A 5,838' 5,844' 4,450' 4,456' 6' 02/19/2025 Open TY10B 5,873' 5,879' 4,484' 4,490' 6' 02/19/2025 Open TY11A 5,966' 5,972' 4,576' 4,581' 6' 02/19/2025 Open T-12U 6,099' 6,117' 4,707' 4,724' 18' 5/11/2022 Open T-12L 6,121' 6,127' 4,728' 4,734' 6' 5/11/2022 Open TY13 6,302' 6,308' 4,906' 4,912' 6' 02/19/2025 Open TY14 6,326' 6,332' 4,930' 4,936' 6' 02/19/2025 Open TY14 6,397' 6,403' 5,000' 5,006' 6' 02/19/2025 Open TY16 6,498' 6,507' 5,100' 5,108' 9' 02/19/2025 Open T-16 6,511' 6,525' 5,113' 5,126' 14' 5/11/2022 Open T-17 6,590' 6,638' 5,191' 5,238' 48' 5/10/2022 Open T-17A 6,677' 6,691' 5,276' 5,290' 14' 5/10/2022 Open T-18A 6,719' 6,732' 5,317' 5,330' 13' 5/10/2022 Open T-18B 6,734' 6,744' 5,332' 5,342' 10' 5/10/2022 Open TY18 6,749' 6,765' 5,347' 5,362' 16' 02/18/2025 Open T-18C 6,768' 6,782' 5,366' 5,380' 14' 5/10/2022 Open T 37 7,008’ 7,028’ 5,612’ 5,632’ 20’3/4/2022 Open T 37 7,028’ 7,038’ 5,632’ 5,642’ 10’3/4/2022 Open TY37 7,038' 7,052' 5,631' 5,645' 14' 02/18/2025 Open TY42 7,151' 7,159' 5,743' 5,750' 8' 02/18/2025 Open OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2” TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’ 6,166’ Stuck BHA (372’ in length) –Contains radioactive sources (2/22/22) Capillary String (3/8”): 05/28/25 Top Btm MD 0 5100’ TVD 0 3727’ _____________________________________________________________________________________ SRW 11-25-25 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ T12 Thru T18 T3 Thru T9A BEL 60- BEL 135 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875”Surf 2,287’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”2,031’7,566’ Tubing Details 4-1/2"Tieback 12.6 L-80 DWC/C HT 3.958”Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 - 11.000 Cactus EN-2CCL 11" Hgr w/4-1/2" EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’ 1,558’ 4.875” 6.540” Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’1,564’4.790”6.340”Seal Assy. Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status BEL 60 3,065'3,070'2,435'2,439'5'TBD Proposed BEL 60 3,074'3,084'2,442'2,449'10'TBD Proposed BEL 60 3,084'3,099'2,449'2,459'15'TBD Proposed BEL 65 3,106'3,111'2,464'2,467'5'TBD Proposed BEL 65 3,146'3,152'2,492'2,496'6'TBD Proposed BEL 65 3,155'3,160'2,498'2,501'5'TBD Proposed BEL 70 3,168'3,172'2,507'2,509'4'TBD Proposed BEL 70 3,176'3,198'2,512'2,527'22'TBD Proposed BEL 72 3,211'3,216'2,536'2,540'5'TBD Proposed BEL 72 3,218' 3,223' 2,541' 2,544' 5' TBD Proposed BEL 72 3,230' 3,238' 2,549' 2,555' 8' TBD Proposed BEL 73 3,250' 3,258' 2,563' 2,568' 8' TBD Proposed BEL73 3,264' 3,268' 2,572' 2,575' 4' TBD Proposed BEL 74 3,277' 3,289' 2,581' 2,589' 12' TBD Proposed BEL 74 3,308' 3,312' 2,602' 2,605' 4' TBD Proposed BEL 74 3,327' 3,331' 2,615' 2,618' 4' TBD Proposed BEL 75 3,355' 3,361' 2,635' 2,639' 6' TBD Proposed BEL 75 3,373' 3,377' 2,647' 2,650' 4' TBD Proposed BEL 78 3,389' 3,393' 2,659' 2,661' 4' TBD Proposed BEL 80 3,410' 3,425' 2,673' 2,684' 15' TBD Proposed BEL 80 3,427' 3,433' 2,685' 2,690' 6' TBD Proposed BEL 81 3,450' 3,454' 2,701' 2,704' 4' TBD Proposed BEL 82 3,470' 3,476' 2,715' 2,720' 6' TBD Proposed BEL 82 3,488' 3,492' 2,728' 2,731' 4' TBD Proposed BEL 88 3,535' 3,540' 2,761' 2,764' 5' TBD Proposed BEL 90 3,565' 3,571' 2,782' 2,786' 6' TBD Proposed BEL 90 3,572' 3,578' 2,786' 2,790' 6' TBD Proposed BEL 90 3,587' 3,592' 2,797' 2,800' 5' TBD Proposed BEL 90 3,596' 3,614' 2,803' 2,815' 18' TBD Proposed BEL 90 3,636' 3,640' 2,830' 2,833' 4' TBD Proposed BEL 91 3,655' 3,659' 2,843' 2,846' 4' TBD Proposed BEL 91 3,669' 3,675' 2,853' 2,857' 6' TBD Proposed BEL 91 3,683' 3,687' 2,862' 2,865' 4' TBD Proposed BEL 91 3,694' 3,698' 2,870' 2,873' 4' TBD Proposed OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2” TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’ 6,166’ Stuck BHA (372’ in length) –Contains radioactive sources (2/22/22) _____________________________________________________________________________________ SRW 11-25-25 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status BEL 91 3,700' 3,704' 2,874' 2,877' 4' TBD Proposed BEL 91 3,706' 3,712' 2,878' 2,882' 6' TBD Proposed BEL 92 3,747' 3,751' 2,906' 2,909' 4' TBD Proposed BEL 92 3,758' 3,762' 2,914' 2,917' 4' TBD Proposed BEL 92 3,765' 3,770' 2,919' 2,923' 5' TBD Proposed BEL 92 3,780' 3,785' 2,930' 2,933' 5' TBD Proposed BEL 92 3,788' 3,793' 2,935' 2,939' 5' TBD Proposed BEL 92 3,795' 3,801' 2,940' 2,944' 6' TBD Proposed BEL 92 3,806' 3,814' 2,948' 2,953' 8' TBD Proposed BEL 92 3,824' 3,832' 2,960' 2,966' 8' TBD Proposed BEL 93 3,854' 3,859' 2,982' 2,985' 5' TBD Proposed BEL 93 3,864' 3,869' 2,989' 2,992' 5' TBD Proposed BEL 93 3,878' 3,882' 2,999' 3,002' 4' TBD Proposed BEL 94 3,893' 3,899' 3,010' 3,014' 6' TBD Proposed BEL 94 3,902' 3,908' 3,016' 3,021' 6' TBD Proposed BEL 94 3,917' 3,922' 3,027' 3,031' 5' TBD Proposed BEL 95 3,945' 3,950' 3,048' 3,051' 5' TBD Proposed BEL 95 3,955' 3,960' 3,055' 3,059' 5' TBD Proposed BEL 95 3,971' 3,981' 3,067' 3,075' 10' TBD Proposed BEL 97 4,025' 4,029' 3,108' 3,111' 4' TBD Proposed BEL 98 4,053' 4,057' 3,129' 3,132' 4' TBD Proposed BEL 99B 4,157' 4,162' 3,209' 3,213' 5' TBD Proposed BEL 100 4,225' 4,237' 3,263' 3,272' 12' TBD Proposed BEL 110 4,305' 4,315' 3,327' 3,336' 10' TBD Proposed BEL 115 4,322' 4,326' 3,341' 3,345' 4' TBD Proposed BEL 120 4,382' 4,439' 3,391' 3,439' 57' TBD Proposed BEL 131 4,450' 4,455' 3,448' 3,453' 5' TBD Proposed BEL 131 4,460' 4,466' 3,457' 3,462' 6' TBD Proposed BEL 134 4,549' 4,555' 3,533' 3,538' 6' TBD Proposed BEL 135 4,670' 4,680' 3,637' 3,646' 10' TBD Proposed BEL 135 4,682' 4,701' 3,647' 3,664' 19' TBD Proposed BEL 135 4,703' 4,735' 3,666' 3,694' 32' TBD Proposed T3 5,200' 5,212' 3,824' 3,836' 12' 11/30/2023 Open T5 5,320' 5,326' 3,943' 3,948' 6' 11/30/2023 Open TY5A 5,360' 5,366' 3,982' 3,988' 6' 02/20/2025 Open TY5B 5,398' 5,404' 4,019' 4,025' 6' 02/20/2025 Open TY5B 5,418' 5,432' 4,039' 4,052' 14' 02/20/2025 Open T6U 5,440' 5,466' 4,060' 4,086' 26' 11/30/2023 Open T6L 5,484' 5,510' 4,103' 4,128' 26' 11/29/2023 Open TY7 5,564' 5,572' 4,182' 4,190' 8' 02/20/2025 Open T7 5,575' 5,595' 4,192' 4,212' 20' 11/29/2023 Open TY7 5,628' 5,634' 4,244' 4,250' 6' 02/20/2025 Open T8 5,656' 5,680' 4,272' 4,295' 24' 11/29/2023 Open TY8 5,680' 5,700' 4,295' 4,315' 20' 02/19/2025 Open T9A 5,750' 5,766' 4,363' 4,379' 16' 11/29/2023 Open TY10A 5,814' 5,820' 4,426' 4,432' 6' 02/19/2025 Open TY10A 5,838' 5,844' 4,450' 4,456' 6' 02/19/2025 Open TY10B 5,873' 5,879' 4,484' 4,490' 6' 02/19/2025 Open TY11A 5,966' 5,972' 4,576' 4,581' 6' 02/19/2025 Open T-12U 6,099' 6,117' 4,707' 4,724' 18' 5/11/2022 Open T-12L 6,121' 6,127' 4,728' 4,734' 6' 5/11/2022 Open TY13 6,302' 6,308' 4,906' 4,912' 6' 02/19/2025 Open TY14 6,326' 6,332' 4,930' 4,936' 6' 02/19/2025 Open TY14 6,397' 6,403' 5,000' 5,006' 6' 02/19/2025 Open TY16 6,498' 6,507' 5,100' 5,108' 9' 02/19/2025 Open T-16 6,511' 6,525' 5,113' 5,126' 14' 5/11/2022 Open T-17 6,590' 6,638' 5,191' 5,238' 48' 5/10/2022 Open T-17A 6,677' 6,691' 5,276' 5,290' 14' 5/10/2022 Open T-18A 6,719' 6,732' 5,317' 5,330' 13' 5/10/2022 Open T-18B 6,734' 6,744' 5,332' 5,342' 10' 5/10/2022 Open TY18 6,749' 6,765' 5,347' 5,362' 16' 02/18/2025 Open T-18C 6,768' 6,782' 5,366' 5,380' 14' 5/10/2022 Open T 37 7,008’ 7,028’ 5,612’ 5,632’ 20’3/4/2022 Open T 37 7,028’ 7,038’ 5,632’ 5,642’ 10’3/4/2022 Open TY37 7,038' 7,052' 5,631' 5,645' 14' 02/18/2025 Open TY42 7,151' 7,159' 5,743' 5,750' 8' 02/18/2025 Open STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 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: Re-run Cap String 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 8,603 feet N/A feet true vertical 7,178 feet 7,590 feet Effective Depth measured 7,355 feet 2,031 feet true vertical 5,943 feet 1,558 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Cap String 3/8" 5,100'MD 3,727' TVD Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 2,041 MD 1,564 TVD 2,031 MD Packers and SSSV (type, measured and true vertical depth)Flex-Lock V 1,558 TVD SSSV - 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: Scott Warner, Operations Engineer N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 1253 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 scott.warner@hilcorp.com 907-564-4506 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 7 Size 120' 0 71239 0 500 50 Production Liner 5,535' measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-003 50-133-20705-00-00 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: ADL0038437 / FEE-Private Ninilchik / Beluga-Tyonek Gas Pool Ninilchik Unit Kalotsa 8 Plugs Junk measured LengthCasing Structural 6,152'7,566' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 2,287' 7,500psi 2,980psi 6,880psi 8,430psi 2,287' 1,663' Burst Collapse 1,410psi 4,790psi p k ft t Fra O s 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 8:08 am, Aug 21, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.08.20 17:07:15 - 08'00' Noel Nocas (4361) BJM 10/3/25 Page 1/1 Well Name: NINU Kalotsa 08 Report Printed: 8/8/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-133-20705-00-00 Field Name:Ninilchik State/Province:ALASKA Permit to Drill (PTD) #:222-003 Sundry #: Rig Name/No: Jobs Actual Start Date:4/3/2023 End Date: Report Number 2 Report Start Date 6/30/2025 Report End Date 7/1/2025 Last 24hr Summary PTW, JSA. MIRU HAK cap string truck. PU on cap string set at 5145'. Up weight 1700 lbs. POOH to surface. All 5145' of 3/8" SS cap tubing and semi adjustable foot valve recovered. Test and rebuild foot valve. Shut down for the day. Report Number 3 Report Start Date 7/2/2025 Report End Date 7/3/2025 Last 24hr Summary PTW, JSA. Make up foot valve with set pressure 1500 lbs. PT pack off and wellhead connection 250/3500 psi. RIH and set cap string 5100' Slack 5000 lbs tension 1650 lbs. Set static and manual lockdowns. Install hanger alves. RDMO Report Number 4 Report Start Date 8/7/2025 Report End Date 8/8/2025 Last 24hr Summary We received clarity on documentation required for capstrings from email sent to AOGCC on 7/16. 404 documentation needed for capstring maintenance. _____________________________________________________________________________________ Updated by DMA 07-11-25 SCHEMATIC Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ T12 Thru T18 T3 Thru T9A RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875”Surf 2,287’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”2,031’7,566’ Tubing Details 4-1/2"Tieback 12.6 L-80 DWC/C HT 3.958”Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 - 11.000 Cactus EN-2CCL 11" Hgr w/4-1/2" EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’ 1,558’ 4.875” 6.540” Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’1,564’4.790”6.340”Seal Assy. Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status T3 5,200'5,212'3,824'3,836'12'11/30/2023 Open T5 5,320'5,326'3,943'3,948'6'11/30/2023 Open TY5A 5,360'5,366'3,982'3,988'6'02/20/2025 Open TY5B 5,398'5,404'4,019'4,025'6'02/20/2025 Open TY5B 5,418'5,432'4,039'4,052'14'02/20/2025 Open T6U 5,440'5,466'4,060'4,086'26'11/30/2023 Open T6L 5,484'5,510'4,103'4,128'26'11/29/2023 Open TY7 5,564'5,572'4,182'4,190'8'02/20/2025 Open T7 5,575'5,595'4,192'4,212'20'11/29/2023 Open TY7 5,628' 5,634' 4,244' 4,250' 6' 02/20/2025 Open T8 5,656' 5,680' 4,272' 4,295' 24' 11/29/2023 Open TY8 5,680' 5,700' 4,295' 4,315' 20' 02/19/2025 Open T9A 5,750' 5,766' 4,363' 4,379' 16' 11/29/2023 Open TY10A 5,814' 5,820' 4,426' 4,432' 6' 02/19/2025 Open TY10A 5,838' 5,844' 4,450' 4,456' 6' 02/19/2025 Open TY10B 5,873' 5,879' 4,484' 4,490' 6' 02/19/2025 Open TY11A 5,966' 5,972' 4,576' 4,581' 6' 02/19/2025 Open T-12U 6,099' 6,117' 4,707' 4,724' 18' 5/11/2022 Open T-12L 6,121' 6,127' 4,728' 4,734' 6' 5/11/2022 Open TY13 6,302' 6,308' 4,906' 4,912' 6' 02/19/2025 Open TY14 6,326' 6,332' 4,930' 4,936' 6' 02/19/2025 Open TY14 6,397' 6,403' 5,000' 5,006' 6' 02/19/2025 Open TY16 6,498' 6,507' 5,100' 5,108' 9' 02/19/2025 Open T-16 6,511' 6,525' 5,113' 5,126' 14' 5/11/2022 Open T-17 6,590' 6,638' 5,191' 5,238' 48' 5/10/2022 Open T-17A 6,677' 6,691' 5,276' 5,290' 14' 5/10/2022 Open T-18A 6,719' 6,732' 5,317' 5,330' 13' 5/10/2022 Open T-18B 6,734' 6,744' 5,332' 5,342' 10' 5/10/2022 Open TY18 6,749' 6,765' 5,347' 5,362' 16' 02/18/2025 Open T-18C 6,768' 6,782' 5,366' 5,380' 14' 5/10/2022 Open T 37 7,008’ 7,028’ 5,612’ 5,632’ 20’3/4/2022 Open T 37 7,028’ 7,038’ 5,632’ 5,642’ 10’3/4/2022 Open TY37 7,038' 7,052' 5,631' 5,645' 14' 02/18/2025 Open TY42 7,151' 7,159' 5,743' 5,750' 8' 02/18/2025 Open OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2” TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’ 6,166’ Stuck BHA (372’ in length) –Contains radioactive sources (2/22/22) Capillary String (3/8”): 05/28/25 Top Btm MD 0 5100’ TVD 0 3727’ 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: Install Cap String 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 8,603 feet N/A feet true vertical 7,178 feet 7,590 feet Effective Depth measured 7,355 feet 2,031 feet true vertical 5,943 feet 1,558 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Cap String 3/8" 5,127'MD 3,753' TVD Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 2,041 MD 1,564 TVD 2,031 MD Packers and SSSV (type, measured and true vertical depth)Flex-Lock V 1,558 TVD SSSV - 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: Scott Warner, Operations Engineer 325-329 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 1312 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 scott.warner@hilcorp.com 907-564-4506 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 7 Size 120' 0 71270 0 450 49 Production Liner 5,535' measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-003 50-133-20705-00-00 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: ADL0038437 / FEE-Private Ninilchik / Beluga-Tyonek Gas Pool Ninilchik Unit Kalotsa 8 Plugs Junk measured LengthCasing Structural 6,152'7,566' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 2,287' 7,500psi 2,980psi 6,880psi 8,430psi 2,287'1,663' Burst Collapse 1,410psi 4,790psi p k ft t Fra O s 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 4:26 pm, Jun 16, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.06.16 14:56:13 - 08'00' Noel Nocas (4361) RBDMS JSB 061825 DSR-6/18/25BJM 9/23/25 Page 1/1 Well Name: NINU Kalotsa 08 Report Printed: 6/11/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-133-20705-00-00 Field Name:Ninilchik State/Province:ALASKA Permit to Drill (PTD) #:222-003 Sundry #: Rig Name/No: Jobs Actual Start Date:11/10/2023 End Date: Report Number 3 Report Start Date 5/28/2025 Report End Date 5/29/2025 Last 24hr Summary MIRU HAK capillary tubing unit. Load New spool of 3/8" SS tubing 7000'. Pressure test pack off assembly to 250/3500 psi. Foot valve opening pressure 1800 psi. RIH with cap string to 5127'. Pick up in tension 1450 lbs. RIH wt 600 lbs. Hang cap string at 5127'. Install hanger and lock down static and dynamic packoffs. RDMO _____________________________________________________________________________________ Updated by DMA 06-11-25 SCHEMATIC Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ T12 Thru T18 T3 Thru T9A RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875”Surf 2,287’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”2,031’7,566’ Tubing Details 4-1/2"Tieback 12.6 L-80 DWC/C HT 3.958”Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 -11.000 Cactus EN-2CCL 11" Hgr w/4-1/2" EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’1,558’4.875”6.540”Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’1,564’4.790”6.340”Seal Assy. Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status T3 5,200'5,212'3,824'3,836'12'11/30/2023 Open T5 5,320'5,326'3,943'3,948'6'11/30/2023 Open TY5A 5,360'5,366'3,982'3,988'6'02/20/2025 Open TY5B 5,398'5,404'4,019'4,025'6'02/20/2025 Open TY5B 5,418'5,432'4,039'4,052'14'02/20/2025 Open T6U 5,440'5,466'4,060'4,086'26'11/30/2023 Open T6L 5,484'5,510'4,103'4,128'26'11/29/2023 Open TY7 5,564'5,572'4,182'4,190'8'02/20/2025 Open T7 5,575'5,595'4,192'4,212'20'11/29/2023 Open TY7 5,628'5,634'4,244'4,250'6'02/20/2025 Open T8 5,656'5,680'4,272'4,295'24'11/29/2023 Open TY8 5,680'5,700'4,295'4,315'20'02/19/2025 Open T9A 5,750'5,766'4,363'4,379'16'11/29/2023 Open TY10A 5,814'5,820'4,426'4,432'6'02/19/2025 Open TY10A 5,838'5,844'4,450'4,456'6'02/19/2025 Open TY10B 5,873'5,879'4,484'4,490'6'02/19/2025 Open TY11A 5,966'5,972'4,576'4,581'6'02/19/2025 Open T-12U 6,099'6,117'4,707'4,724'18'5/11/2022 Open T-12L 6,121'6,127'4,728'4,734'6'5/11/2022 Open TY13 6,302'6,308'4,906'4,912'6'02/19/2025 Open TY14 6,326'6,332'4,930'4,936'6'02/19/2025 Open TY14 6,397'6,403'5,000'5,006'6'02/19/2025 Open TY16 6,498'6,507'5,100'5,108'9'02/19/2025 Open T-16 6,511'6,525'5,113'5,126'14'5/11/2022 Open T-17 6,590'6,638'5,191'5,238'48'5/10/2022 Open T-17A 6,677'6,691'5,276'5,290'14'5/10/2022 Open T-18A 6,719'6,732'5,317'5,330'13'5/10/2022 Open T-18B 6,734'6,744'5,332'5,342'10'5/10/2022 Open TY18 6,749'6,765'5,347'5,362'16'02/18/2025 Open T-18C 6,768'6,782'5,366'5,380'14'5/10/2022 Open T 37 7,008’7,028’5,612’5,632’20’3/4/2022 Open T 37 7,028’7,038’5,632’5,642’10’3/4/2022 Open TY37 7,038'7,052'5,631'5,645'14'02/18/2025 Open TY42 7,151'7,159'5,743'5,750'8'02/18/2025 Open OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2”TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’6,166’Stuck BHA (372’ in length) –Contains radioactive sources (2/22/22) Capillary String (3/8”): 05/28/25 Top Btm MD 0 5127’ TVD 0 3753’ 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 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): 8,603 7590 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 Other: Install Capstring Liner Top Pkr & N/A 2,031 (MD) 1,558 (TVD) & N/A 7,178 7,355 5,943 Ninilchik Beluga-Tyonek Gas 16" 7-5/8" 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Kalotsa 8CO 701 C Same 6,1524-1/2" 1953 5,535 N/A April 30, 2025 4-1/2" 7,566 Perforation Depth MD (ft): 5,200 - 7,159 3,824 - 5,750 2,980psi 6,880psi 120120 2,287 Size 120 2,287 MDLength Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 2,041 8,430psi 1,663 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 ADL0038437 / FEE-Private 222-003 50-133-20705-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: scott.warner@hilcorp.com 907-564-4506 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: No 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 12:35 pm, Apr 17, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.04.17 09:50:29 - 08'00' Noel Nocas (4361) 325-239 DSR-4/17/25SFD 4/18/2025BJM 4/21/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.21 13:46:18 -08'00'04/21/25 RBDMS JSB 042225 Well Prognosis Well Name: Kalotsa 8 API Number: 50-133-20705-00-00 Current Status: Producing Gas Well Permit to Drill Number: 222-003 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 2527 psi @ 5743’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure:1953 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: .86 psi/ft using 16.6 ppg EMW FIT at the 7-5/8” surface casing shoe Shallowest Allowable Perf TVD: MPSP/(.86-0.1) = 1953 psi / .76= 2569‘ TVD Top of Applicable Gas Pool: 1710’ MD/1422’ TVD (Beluga-Tyonek) Well Status: Online Gas producer – 1400 mscfd, 0 bwpd, 48 psi FTP Brief Well Summary Kalotsa 8 was drilled and completed in February 2021, targeting the lower Tyonek sands. The well IP’d at ~2.0 MMCFD and production increased to 3.0 MMCFD before going on a steady decline. Additional Tyonek sands were perf’d in May 2022 and came online at 4 mmscfd. A capstring was installed in April 2023 which helped keep the well from loading up. That capstring was pulled in November 2023 prior to adding more perforations which increased rate from 825 mscfd to 2.7 mmscfd. Additional perforations were added in February 2025 which increased rate from 1.1 mmscfd to 1.8 mmscfd. Rate has slowly declined since those perforations were added and we believe the well is loading up. The objective of this sundry is to add a capstring for soap injection due to the deviation in this well and being unable to get soap sticks to fall down the wellbore. Notes Regarding Wellbore Condition x Inclination o Max inclination = 67.6° at 2091’ MD o Max DLS: 9.51° @ 2377’ MD x Min ID o 3.890” – (5.5” x 4.5” DWC/C-HT Box at 2027’ MD) x Recent Tags o 2/15/25: ƒSL RIH w/ 3.75” GR- fell slow and came to stop at 2118’ KB. RIH w/ 3.75” GR, roller bogie and roller stem, tag at 5198’ KB. RIH w/ 3.75” GR, work tools through multiple sptos and tagged at 7282’ KB. Bailer run during this operation had mud/water o 2/18/25 – 2/20/25: ƒPerforated multiple zones with 2-3/4” guns. Guns were noted to be sandy throughout a lot of the 3 day operation Procedure: 1. RU Cap String Truck 2. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components. Install pack-off and pressure test against swab valve to 2500 psi 3. RIH with 3/8” capillary string to ±5100’ MD a. Set cap string as deep as practical in fluid Well Prognosis 4. Install slips and connect tubing to chemical injection pump 5. Set spool of remaining line near well 6. RD cap string Unit, and turn well over to production Attachments: 1. Current Schematic 2. Proposed Schematic _____________________________________________________________________________________ Updated by DMA 02-26-25 SCHEMATIC Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ T12 Thru T18 T3 Thru T9A RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875”Surf 2,287’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”2,031’7,566’ Tubing Details 4-1/2"Tieback 12.6 L-80 DWC/C HT 3.958”Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 -11.000 Cactus EN-2CCL 11" Hgr w/4-1/2" EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’1,558’4.875”6.540”Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’1,564’4.790”6.340”Seal Assy. Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status T3 5,200'5,212'3,824'3,836'12'11/30/2023 Open T5 5,320'5,326'3,943'3,948'6'11/30/2023 Open TY5A 5,360'5,366'3,982'3,988'6'02/20/2025 Open TY5B 5,398'5,404'4,019'4,025'6'02/20/2025 Open TY5B 5,418'5,432'4,039'4,052'14'02/20/2025 Open T6U 5,440'5,466'4,060'4,086'26'11/30/2023 Open T6L 5,484'5,510'4,103'4,128'26'11/29/2023 Open TY7 5,564'5,572'4,182'4,190'8'02/20/2025 Open T7 5,575'5,595'4,192'4,212'20'11/29/2023 Open TY7 5,628'5,634'4,244'4,250'6'02/20/2025 Open T8 5,656'5,680'4,272'4,295'24'11/29/2023 Open TY8 5,680'5,700'4,295'4,315'20'02/19/2025 Open T9A 5,750'5,766'4,363'4,379'16'11/29/2023 Open TY10A 5,814'5,820'4,426'4,432'6'02/19/2025 Open TY10A 5,838'5,844'4,450'4,456'6'02/19/2025 Open TY10B 5,873'5,879'4,484'4,490'6'02/19/2025 Open TY11A 5,966'5,972'4,576'4,581'6'02/19/2025 Open T-12U 6,099'6,117'4,707'4,724'18'5/11/2022 Open T-12L 6,121'6,127'4,728'4,734'6'5/11/2022 Open TY13 6,302'6,308'4,906'4,912'6'02/19/2025 Open TY14 6,326'6,332'4,930'4,936'6'02/19/2025 Open TY14 6,397'6,403'5,000'5,006'6'02/19/2025 Open TY16 6,498'6,507'5,100'5,108'9'02/19/2025 Open T-16 6,511'6,525'5,113'5,126'14'5/11/2022 Open T-17 6,590'6,638'5,191'5,238'48'5/10/2022 Open T-17A 6,677'6,691'5,276'5,290'14'5/10/2022 Open T-18A 6,719'6,732'5,317'5,330'13'5/10/2022 Open T-18B 6,734'6,744'5,332'5,342'10'5/10/2022 Open TY18 6,749'6,765'5,347'5,362'16'02/18/2025 Open T-18C 6,768'6,782'5,366'5,380'14'5/10/2022 Open T 37 7,008’7,028’5,612’5,632’20’3/4/2022 Open T 37 7,028’7,038’5,632’5,642’10’3/4/2022 Open TY37 7,038'7,052'5,631'5,645'14'02/18/2025 Open TY42 7,151'7,159'5,743'5,750'8'02/18/2025 Open OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2”TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’6,166’Stuck BHA (372’ in length) –Contains radioactive sources (2/22/22) _____________________________________________________________________________________ Updated by SRW 4/15/25 PROPOSED Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ T12 Thru T18 T3 Thru T9A RKB to GL =18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875” Surf 2,287’ 4-1/2" Prod Lnr 12.6 L-80 DWC/C HT 3.958” 2,031’ 7,566’ Tubing Details 4-1/2" Tieback 12.6 L-80 DWC/C HT 3.958” Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 - 11.000 Cactus EN-2CCL 11" Hgr w/4-1/2" EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’ 1,558’ 4.875” 6.540” Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’ 1,564’ 4.790” 6.340” Seal Assy. Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status T3 5,200' 5,212' 3,824' 3,836' 12' 11/30/2023 Open T5 5,320' 5,326' 3,943' 3,948' 6' 11/30/2023 Open TY5A 5,360' 5,366' 3,982' 3,988' 6' 02/20/2025 Open TY5B 5,398' 5,404' 4,019' 4,025' 6' 02/20/2025 Open TY5B 5,418' 5,432' 4,039' 4,052' 14' 02/20/2025 Open T6U 5,440' 5,466' 4,060' 4,086' 26' 11/30/2023 Open T6L 5,484' 5,510' 4,103' 4,128' 26' 11/29/2023 Open TY7 5,564' 5,572' 4,182' 4,190' 8' 02/20/2025 Open T7 5,575' 5,595' 4,192' 4,212' 20' 11/29/2023 Open TY7 5,628' 5,634' 4,244' 4,250' 6' 02/20/2025 Open T8 5,656' 5,680' 4,272' 4,295' 24' 11/29/2023 Open TY8 5,680' 5,700' 4,295' 4,315' 20' 02/19/2025 Open T9A 5,750' 5,766' 4,363' 4,379' 16' 11/29/2023 Open TY10A 5,814' 5,820' 4,426' 4,432' 6' 02/19/2025 Open TY10A 5,838' 5,844' 4,450' 4,456' 6' 02/19/2025 Open TY10B 5,873' 5,879' 4,484' 4,490' 6' 02/19/2025 Open TY11A 5,966' 5,972' 4,576' 4,581' 6' 02/19/2025 Open T-12U 6,099' 6,117' 4,707' 4,724' 18' 5/11/2022 Open T-12L 6,121' 6,127' 4,728' 4,734' 6' 5/11/2022 Open TY13 6,302' 6,308' 4,906' 4,912' 6' 02/19/2025 Open TY14 6,326' 6,332' 4,930' 4,936' 6' 02/19/2025 Open TY14 6,397' 6,403' 5,000' 5,006' 6' 02/19/2025 Open TY16 6,498' 6,507' 5,100' 5,108' 9' 02/19/2025 Open T-16 6,511' 6,525' 5,113' 5,126' 14' 5/11/2022 Open T-17 6,590' 6,638' 5,191' 5,238' 48' 5/10/2022 Open T-17A 6,677' 6,691' 5,276' 5,290' 14' 5/10/2022 Open T-18A 6,719' 6,732' 5,317' 5,330' 13' 5/10/2022 Open T-18B 6,734' 6,744' 5,332' 5,342' 10' 5/10/2022 Open TY18 6,749' 6,765' 5,347' 5,362' 16' 02/18/2025 Open T-18C 6,768' 6,782' 5,366' 5,380' 14' 5/10/2022 Open T 37 7,008’ 7,028’ 5,612’ 5,632’ 20’ 3/4/2022 Open T 37 7,028’ 7,038’ 5,632’ 5,642’ 10’ 3/4/2022 Open TY37 7,038' 7,052' 5,631' 5,645' 14' 02/18/2025 Open TY42 7,151' 7,159' 5,743' 5,750' 8' 02/18/2025 Open OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2” TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’ 6,166’ Stuck BHA (372’ in length)–Contains radioactive sources (2/22/22) Capillary String (3/8”): planned Top Bottom MD 0 5100’ TVD 0 3726’ 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 8,603 feet N/A feet true vertical 7,178 feet 7,590 feet Effective Depth measured 7,355 feet 2,031 feet true vertical 5,943 feet 1,558 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 2,041 MD 1,564 TVD 2,031 MD Packers and SSSV (type, measured and true vertical depth)Flex-Lock V 1,558 TVD SSSV - 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 2,287'1,663' Burst Collapse 1,410psi 4,790psi Casing Structural 6,152'7,566' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 2,287' measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-003 50-133-20705-00-00 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: ADL0038437 / FEE-Private Ninilchik / Beluga-Tyonek Gas Pool Ninilchik Unit Kalotsa 8 Plugs Junk measured Length Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 6 Size 120' 0 61938 0 410 66 Production Liner 5,535' Scott Warner, Operations Engineer 325-073 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 1175 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 scott.warner@hilcorp.com 907-564-4506 measured true vertical Packer Representative Daily Average Production or Injection Data p k ft t Fra O s 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 10:08 am, Mar 17, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.03.14 17:07:09 - 08'00' Noel Nocas (4361) BJM 5/28/25 RBDMS JSB 032625 DSR-3/25/25 Page 1/1 Well Name: NINU Kalotsa 08 Report Printed: 2/26/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:2/6/2025 End Date: Report Number 1 Report Start Date 2/15/2025 Report End Date 2/15/2025 Last 24hr Summary Attempt to D&T w/ 3.75'' g-ring - fell slow from 1500' came to stop @ 2118'kb PTW/PJSM. FTP 35 psi. RU Pollard Slickline. PT lubricator 250 psi low / 2500 psi high - good test. RIH w/ 3.75" GR and fall slow from 1500' to tag @ 2,118' RKB. Secure well, SDFN. Report Number 2 Report Start Date 2/16/2025 Report End Date 2/16/2025 Last 24hr Summary Clean perf debri (tight spots) w/ 3.75'' g-ring. Drift w/ 2 7/8'' dummy guns to 7272'kb no obstruction POOH heavy to 4500' PTW/PJSM. FTP 35 psi. RU Pollard Slickline. RIH w/ 3.75" GR, roller bogie and roller stem to tag @ 5,198' RKB. RIH w/ 2 1/2" bailer and tag @ 7,283' RKB. RIH w/ 3.75" GR and tag @ 7,282' RKB. RIH w/ 2 7/8" x 20' dummy gun and tag @ 7,272' RKB. Secure well, RD Pollard. Report Number 3 Report Start Date 2/18/2025 Report End Date 2/18/2025 Last 24hr Summary PTW/PJSM. 270 psi SITP. MIRU YJ E-line. PT lubricator to 250 psi low / 2500 psi high - good test. RIH w/ GPT and tag @ 7,282' and find fluid level ~ 6,965'. RIH w/ 8' x 2 3/4" 6 SPF 60 DEG guns and perf TY_42 (7,151’ – 7,159’). RIH w/ 14' x 2 3/4" 6 SPF 60 DEG guns and perf TY_37 (7,038’ – 7,052’). RIH w/ 16' x 2 3/4" 6 SPF 60 DEG guns and perf TY_18 (6,749’ – 6,765’). Secure well, SDFN, and flow well. Report Number 4 Report Start Date 2/19/2025 Report End Date 2/19/2025 Last 24hr Summary PTW/PJSM. 210 psi SITP. RU YJ E-line. RIH w/ 9'x6' 2 3/4" 6 SPF 60 DEG guns on switch and perf TY_16 (6,498’ – 6,507’) and TY_14 Lower (6,397’ – 6,403’). RIH w/ 6'x6'x6' 2 3/4" 6 SPF 60 DEG guns on switch and perf TY_14 Upper (6,326’ – 6,332’), TY_13 (6,302’ – 6,308’), and TY_11A (5,966’ – 5,972’). RIH w/ 6'x6'x6' 2 3/4" 6 SPF 60 DEG guns on switch and perf TY_10B (5,873’ – 5,879’), TY_10A Lower (5,838’ – 5,844’), and TY_10A Upper (5,814’ – 5,820’). RIH w/ 20' 2 3/4" 6 SPF 60 DEG guns and perf TY_8 (5,680’ – 5,700’). Secure well, SDFN, and flow well. Report Number 5 Report Start Date 2/20/2025 Report End Date 2/20/2025 Last 24hr Summary PTW/PJSM. 250 psi SITP. RU YJ E-line. RIH w/ 6'x8' 2 3/4" 6 SPF 60 DEG guns on switch and perf TY_7 Lower (5,628’ – 5,634’) and TY_7 Upper (5,564’ – 5,572’). RIH w/ 14' 2 3/4" 6 SPF 60 DEG guns and perf TY_5B Lower (5,418’ – 5,432’). RIH w/ 6'x6' 2 3/4" 6 SPF 60 DEG guns on switch and perf TY_5B Upper (5,398’ – 5,404’) and TY_5A (5,360’ – 5,366’). Secure well, RDMO YJ E-line, and flow well. Field: Ninilchik Sundry #: 325-073 State: Alaska Rig/Service:Permit to Drill (PTD) #:222-003Permit to Drill (PTD) #:222-003 Wellbore API/UWI:50-133-20705-00-00 _____________________________________________________________________________________ Updated by DMA 02-26-25 SCHEMATIC Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ T12 Thru T18 T3 Thru T9A RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875”Surf 2,287’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”2,031’7,566’ Tubing Details 4-1/2"Tieback 12.6 L-80 DWC/C HT 3.958”Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 -11.000 Cactus EN-2CCL 11" Hgr w/4-1/2" EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’1,558’4.875”6.540”Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’1,564’4.790”6.340”Seal Assy. Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status T3 5,200'5,212'3,824'3,836'12'11/30/2023 Open T5 5,320'5,326'3,943'3,948'6'11/30/2023 Open TY5A 5,360'5,366'3,982'3,988'6'02/20/2025 Open TY5B 5,398'5,404'4,019'4,025'6'02/20/2025 Open TY5B 5,418'5,432'4,039'4,052'14'02/20/2025 Open T6U 5,440'5,466'4,060'4,086'26'11/30/2023 Open T6L 5,484'5,510'4,103'4,128'26'11/29/2023 Open TY7 5,564'5,572'4,182'4,190'8'02/20/2025 Open T7 5,575'5,595'4,192'4,212'20'11/29/2023 Open TY7 5,628'5,634'4,244'4,250'6'02/20/2025 Open T8 5,656'5,680'4,272'4,295'24'11/29/2023 Open TY8 5,680'5,700'4,295'4,315'20'02/19/2025 Open T9A 5,750'5,766'4,363'4,379'16'11/29/2023 Open TY10A 5,814'5,820'4,426'4,432'6'02/19/2025 Open TY10A 5,838'5,844'4,450'4,456'6'02/19/2025 Open TY10B 5,873'5,879'4,484'4,490'6'02/19/2025 Open TY11A 5,966'5,972'4,576'4,581'6'02/19/2025 Open T-12U 6,099'6,117'4,707'4,724'18'5/11/2022 Open T-12L 6,121'6,127'4,728'4,734'6'5/11/2022 Open TY13 6,302'6,308'4,906'4,912'6'02/19/2025 Open TY14 6,326'6,332'4,930'4,936'6'02/19/2025 Open TY14 6,397'6,403'5,000'5,006'6'02/19/2025 Open TY16 6,498'6,507'5,100'5,108'9'02/19/2025 Open T-16 6,511'6,525'5,113'5,126'14'5/11/2022 Open T-17 6,590'6,638'5,191'5,238'48'5/10/2022 Open T-17A 6,677'6,691'5,276'5,290'14'5/10/2022 Open T-18A 6,719'6,732'5,317'5,330'13'5/10/2022 Open T-18B 6,734'6,744'5,332'5,342'10'5/10/2022 Open TY18 6,749'6,765'5,347'5,362'16'02/18/2025 Open T-18C 6,768'6,782'5,366'5,380'14'5/10/2022 Open T 37 7,008’7,028’5,612’5,632’20’3/4/2022 Open T 37 7,028’7,038’5,632’5,642’10’3/4/2022 Open TY37 7,038'7,052'5,631'5,645'14'02/18/2025 Open TY42 7,151'7,159'5,743'5,750'8'02/18/2025 Open OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2”TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’6,166’Stuck BHA (372’ in length) –Contains radioactive sources (2/22/22) 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: N2 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): 8,603 7590 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 Liner Top Pkr & N/A 2,031 (MD) 1,558 (TVD) & N/A 7,178 7,355 5,943 Ninilchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Kalotsa 8CO 701 C Same 6,1524-1/2" 1953 psi 5,535 N/A Length February 14, 2025 4-1/2" 7,566 Perforation Depth MD (ft): See Attached Schematic 2,980psi 6,880psi 120120 2,287 Size 120 2,287 MD Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 2,041 8,430psi 1,663 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 ADL0038437 / FEE-Private 222-003 50-133-20705-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: scott.warner@hilcorp.com 907-564-4506 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 t N 66 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 3:24 pm, Jan 31, 2025 325-055 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.01.31 15:15:24 - 09'00' Noel Nocas (4361) BJM 2/7/25 DSR-1/31/25 325-073 SFD 2/12/2025 Perforate *&: 2/12/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.12 10:28:32 -09'00' RBDMS JSB 021325 Well Prognosis Well Name: Kalotsa 8 API Number: 50-133-20705-00-00 Current Status: Producing Gas Well Permit to Drill Number: 222-003 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O)(907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O)(907) 229-4824 (C) Maximum Expected BHP: 2527 psi @ 5743’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure:1953 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: .86 psi/ft using 16.6 ppg EMW FIT at the 7-5/8” surface casing shoe Shallowest Allowable Perf TVD: MPSP/(.86-0.1) = 1953 psi / .76= 2569‘ TVD Top of Applicable Gas Pool:1710’ MD/1422’ TVD (Beluga-Tyonek) Well Status: Online Gas producer – 1081 mscfd, 0 bwpd, 37 psi FTP Brief Well Summary Kalotsa 8 was drilled and completed in February 2021, targeting the lower Tyonek sands. The well IP’d at ~2.0 MMCFD and production increased to 3.0 MMCFD before going on a steady decline. Additional Tyonek sands were perf’d in May 2022 and came online at 4 mmscfd. A capstring was installed in April 2023 which helped keep the well from loading up. That capstring was pulled in November 2023 prior to adding more perforations which increased rate from 825 mscfd to 2.7 mmscfd. The objective of this sundry is to add additional infill perforations to the Tyonek sands to increase the rate. Notes Regarding Wellbore Condition x Inclination o Max inclination = 67.6° at 2091’ MD o Max DLS: 9.51° @ 2377’ MD x Min ID o 3.890” – (5.5” x 4.5” DWC/C-HT Box at 2027’ MD) x Recent Tags o 11/22/23: ƒRIH w/ 2.5 DD bailer to 7325’ KB. Pre-Sundry Steps: 1. RU slickline 2. PT lubricator to 250 psi low/ 2,500 psi high 3. D&T to TD w/ large OD drift to find updated tag and ensure wellbore is clean of any sand bridges. Last SL tag was 7325’ KB in April 2023. Note if fluid level is seen. 4.RDMO slickline Procedure: 1. MIRU E-line and pressure control equipment 2.PT lubricator to 250 psi low /2,500 psi high 3. RIH and perforate TY 5A – TY 42 sands from bottom up with 2-7/8” 60 deg phased perf guns: 16.6 ppg EMW FIT Well Prognosis Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Zone Top MD Btm MD Top TVD Btm TVD Footage TY_5A ±5,360' ±5,366' ±3,982' ±3,988' ±6' TY_5B ±5,398' ±5,404' ±4,019' ±4,025' ±6' TY_5B ±5,418' ±5,432' ±4,039' ±4,052' ±14' TY_7 ±5,564' ±5,572' ±4,182' ±4,190' ±8' TY_7 ±5,628' ±5,634' ±4,244' ±4,250' ±6' TY_8 ±5,680' ±5,700' ±4,295' ±4,315' ±20' TY_10A ±5,814' ±5,820' ±4,426' ±4,432' ±6' TY_10A ±5,838' ±5,844' ±4,450' ±4,456' ±6' TY_10B ±5,873' ±5,879' ±4,484' ±4,490' ±6' TY_11A ±5,966' ±5,972' ±4,576' ±4,581' ±6' TY_13 ±6,302' ±6,308' ±4,906' ±4,912' ±6' TY_14 ±6,326' ±6,332' ±4,930' ±4,936' ±6' TY_14 ±6,397' ±6,403' ±5,000' ±5,006' ±6' TY_16 ±6,498' ±6,507' ±5,100' ±5,108' ±9' TY_18 ±6,749' ±6,765' ±5,347' ±5,362' ±16' TY_37 ±7,038' ±7,052' ±5,631' ±5,645' ±14' TY_42 ±7,151' ±7,159' ±5,743' ±5,750' ±8' a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations i. Note: A CIBP may be used instead of WRP if it is determined that no cement is needed for operational purposes. g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO a. If necessary, run cap string to aid with water production if encountered post perforating. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations _____________________________________________________________________________________ Updated by DMA 12-04-24 SCHEMATIC Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ T12 Thru T18 T3 Thru T9A RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875”Surf 2,287’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”2,031’7,566’ Tubing Details 4-1/2"Tieback 12.6 L-80 DWC/C HT 3.958”Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 -11.000 Cactus EN-2CCL 11" Hgr w/4-1/2" EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’1,558’4.875”6.540”Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’1,564’4.790”6.340”Seal Assy. PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Size Status T3 5,200'5,212'3,824'3,836'12'11/30/2023 Open T5 5,320'5,326'3,943'3,948'6'11/30/2023 Open T6U 5,440'5,466'4,060'4,086'26'11/30/2023 Open T6L 5,484'5,510'4,103'4,128'26'11/29/2023 Open T7 5,575'5,595'4,192'4,212'20'11/29/2023 Open T8 5,656'5,680'4,272'4,295'24'11/29/2023 Open T9A 5,750'5,766'4,363'4,379'16'11/29/2023 Open T-12U 6,099'6,117'4,707'4,724'18'5/11/2022 2-7/8” HC Open T-12L 6,121'6,127'4,728'4,734'6'5/11/2022 2-7/8” HC Open T-16 6,511'6,525'5,113'5,126'14'5/11/2022 2-7/8” HC Open T-17 6,590'6,638'5,191'5,238'48'5/10/2022 2-7/8” HC Open T-17A 6,677'6,691'5,276'5,290'14'5/10/2022 2-7/8” HC Open T-18A 6,719'6,732'5,317'5,330'13'5/10/2022 2-7/8” HC Open T-18B 6,734'6,744'5,332'5,342'10'5/10/2022 2-7/8” HC Open T-18C 6,768'6,782'5,366'5,380'14'5/10/2022 2-7/8” HC Open T 37 7,008’7,028’5,612’5,632’20’3/4/2022 2-7/8” 6SPF Open T 37 7,028’7,038’5,632’5,642’10’3/4/2022 2-7/8” 6SPF Open OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2”TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’6,166’Stuck BHA (372’ in length) –Contains radioactive sources (2/22/22) _____________________________________________________________________________________ Updated by SRW 1-31-25 PROPOSED SCHEMATIC Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ T12 Thru T18 T3 Thru T9A RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875”Surf 2,287’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”2,031’7,566’ Tubing Details 4-1/2"Tieback 12.6 L-80 DWC/C HT 3.958”Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 -11.000 Cactus EN-2CCL 11" Hgr w/4-1/2" EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’1,558’4.875”6.540”Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’1,564’4.790”6.340”Seal Assy. Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status T3 5,200'5,212'3,824'3,836'12'11/30/2023 Open T5 5,320'5,326'3,943'3,948'6'11/30/2023 Open TY5A ±5,360'±5,366'±3,982'±3,988'±6'TBD Proposed TY5B ±5,398'±5,404'±4,019'±4,025'±6'TBD Proposed TY5B ±5,418'±5,432'±4,039'±4,052'±14'TBD Proposed T6U 5,440'5,466'4,060'4,086'26'11/30/2023 Open T6L 5,484'5,510'4,103'4,128'26'11/29/2023 Open TY7 ±5,564'±5,572'±4,182'±4,190'±8'TBD Proposed T7 5,575'5,595'4,192'4,212'20'11/29/2023 Open TY7 ±5,628'±5,634'±4,244'±4,250'±6'TBD Proposed T8 5,656'5,680'4,272'4,295'24'11/29/2023 Open TY8 ±5,680'±5,700'±4,295'±4,315'±20'TBD Proposed T9A 5,750'5,766'4,363'4,379'16'11/29/2023 Open TY10A ±5,814'±5,820'±4,426'±4,432'±6'TBD Proposed TY10A ±5,838'±5,844'±4,450'±4,456'±6'TBD Proposed TY10B ±5,873'±5,879'±4,484'±4,490'±6'TBD Proposed TY11A ±5,966'±5,972'±4,576'±4,581'±6'TBD Proposed T-12U 6,099'6,117'4,707'4,724'18'5/11/2022 Open T-12L 6,121'6,127'4,728'4,734'6'5/11/2022 Open TY13 ±6,302'±6,308'±4,906'±4,912'±6'TBD Proposed TY14 ±6,326'±6,332'±4,930'±4,936'±6'TBD Proposed TY14 ±6,397'±6,403'±5,000'±5,006'±6'TBD Proposed TY16 ±6,498'±6,507'±5,100'±5,108'±9'TBD Proposed T-16 6,511'6,525'5,113'5,126'14'5/11/2022 Open T-17 6,590'6,638'5,191'5,238'48'5/10/2022 Open T-17A 6,677'6,691'5,276'5,290'14'5/10/2022 Open T-18A 6,719'6,732'5,317'5,330'13'5/10/2022 Open T-18B 6,734'6,744'5,332'5,342'10'5/10/2022 Open TY18 ±6,749'±6,765'±5,347'±5,362'±16'TBD Proposed T-18C 6,768'6,782'5,366'5,380'14'5/10/2022 Open T 37 7,008’7,028’5,612’5,632’20’3/4/2022 Open T 37 7,028’7,038’5,632’5,642’10’3/4/2022 Open TY37 ±7,038'±7,052'±5,631'±5,645'±14'TBD Proposed TY42 ±7,151'±7,159'±5,743'±5,750'±8'TBD Proposed OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2”TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’6,166’Stuck BHA (372’ in length) –Contains radioactive sources (2/22/22) STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 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: 1/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240112 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 221-35 50283201930000 223077 11/4/2023 AK E-LINE CBL END 1-27 50029216930000 187009 11/16/2023 YELLOWJACKET PERF KALOTSA 4 50133206650000 217063 9/28/2023 YELLOWJACKET PERF KALOTSA 8 50133207050000 222003 11/29/2023 YELLOWJACKET PERF KBU 13-8 50133203040000 177029 11/5/2023 YELLOWJACKET PERF KBU 22-06Y 50133206500000 215044 11/9/2023 YELLOWJACKET GPT KBU 22-06Y 50133206500000 215044 11/17/2023 YELLOWJACKET PLUG-PERF KBU 11-08Z 50133206290000 214044 8/24/2023 AK E-LINE GPT/CIBP/PERF KBU 22-06Y 50133206500000 215044 10/9/2023 AK E-LINE CBL KBU 23-05 50133206300000 214061 10/10/2023 AK E-LINE PLT KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/PERF MPU I-01 50029220650000 190090 11/18/2023 YELLOWJACKET PERF PAXTON 12 50133207100000 223014 11/20/2023 YELLOWJACKET PERF PAXTON 7 50133206430000 214130 9/18/2023 YELLOWJACKET CBL PAXTON 7 50133206430000 214130 10/7/2023 YELLOWJACKET PERF SRU 224-10 50133101380100 222124 12/27/2023 YELLOWJACKET GPT-PLUG-PERF SRU 224-10 50133101380100 222124 11/4/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 11/8/2023 YELLOWJACKET PERF-PLUG-GPT SRU 231-33 50133101630100 223008 11/3/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 10/17/2023 YELLOWJACKET PLUG-PERF-GPT SRU 232-15 50133207140000 223091 12/6/2023 YELLOWJACKET GPT-PERF SRU 232-15 50133207140000 223091 12/2/2023 YELLOWJACKET SCBL Please include current contact information if different from above. T38273 T38275 T38277 T38278 T38279 T38280 T38280 T38281 T38282 T38283 T38284 T38285 T38286 T38287 T38287 T38288 T38288 T38289 T38289 T38289 T38290 T38290 1/18/2024 KALOTSA 8 50133207050000 222003 11/29/2023 YELLOWJACKET PERF Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.18 11:52:00 -09'00' 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 8,603 feet N/A feet true vertical 7,178 feet 7,590 feet Effective Depth measured 7,355 feet 2,031 feet true vertical 5,943 feet 1,558 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 2,041 MD 1,564 TVD 2,031 MD Packers and SSSV (type, measured and true vertical depth)Flex-Lock V 1,558 TVD SSSV - 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 323-633 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 847 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 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' 0 02626 0 5710 139 4-1/2" Intermediate 16" 7-5/8" 120' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 222-003 50-133-20705-00-00 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: ADL0038437 / FEE-Private Ninilchik / Beluga-Tyonek Gas Pool Ninilchik Unit Kalotsa 8 Production Liner 5,535' Casing Structural 6,152'7,566' 120'Conductor Surface 2,287' TVD measured Packer Plugs Junk measured Length 7,500psi 2,980psi 6,880psi 8,430psi 2,287'1,663' Burst Collapse 1,410psi 4,790psi measured true vertical p k ft t Fra O s 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 8:54 am, Jan 08, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.01.05 16:24:49 - 09'00' Noel Nocas (4361) RBDMS JSB 011124 DSR-1/26/24 Page 1/1 Well Name: NINU Kalotsa 8 Report Printed: 1/4/2024www.peloton.com Well Operations Summary Jobs Actual Start Date:11/29/2023 End Date: Report Number 1 Report Start Date 11/29/2023 Report End Date 11/30/2023 Operation Mobilze Eline Unit and Crew From Nikiski to Kalotsa 8 Arrive on location, check equipment. JSA & permit with Operator PT 250/2500, Good test. Operator SI well. RIH with Gun # 1, (16') Geo Dynamic, 6 spf, 15 Gram, Razor Charge. Sent correlation log to Geo for Tie in. Correlate & Perforate Interval: T9A- 5750' - 5766'. Per Geo tie in approval . POOH OOH with Gun # 1 . All shots fired, Bull Plug is Dry MU & RIH with Gun # 2, (24') Gun. Correlate & Perforate Interval: (T8) (5656' - 5680'). Per Geo tie in approval. POOH . OOH with Gun # 2, All shots fired, Bull Plug Dry. MU & RIH with Gun # 3, (20') gun.(5575'-5595') (T-340 psi ). Prior to shot. Correlate & Perforate Interval: (T7) (5575' - 5595'). Per Geo tie in approval POOH . OOH with Gun # 3 . All shots fired, Bull Plug is Dry- T- 340 psi MU & RIH with Gun # 4, 20' gun.(5575'-5595') (T-340 psi ). Prior to shot. Correlate & Perforate Interval: (T6L) (5484' - 5510').Per Geo tie in approval T-~352 psi after shot. POOH . OOH with Gun # 4 . All shots fired, Bull Plug is Dry- T- ~340 psi Break off lubricator and LD. Night cap on the BOP's. Verify Swb is shut Well to be left shut in. Contact Operator. Notify of well status. Job in progress. Will continue tomorrow. Report Number 2 Report Start Date 11/30/2023 Report End Date 12/1/2023 Operation Mobilze Eline Unit and Crew From Nikiski to Kalotsa 8 PT 250/2500, Good test. PT BOP's & 42' lubricator MU gun # 5 (T6U). T-339 psi. RIH with Gun # 5, (26') 2-3/4" Geo Dynamic, 6 spf, 15 Gram, Razor Charge. Log pass, send correlation log to Geo for Tie in Correlate & Perforate Interval: T6U- 5440' - 5466'. Per Geo tie in approval T-339 psi prior to shot. PSI after 5 min- 400 psi , 10 min- 430 psi, 15 min-445 psi. 20 min 450 psi. OOH with Gun # 5 . All shots fired, Bull Plug Dry RIH with Gun # 6, (6') 2-3/4" Geo Dynamic, 6 spf, 15 Gram, Razor Charge. Correlate & Perforate Interval: T5- 5320' - 5326'. Per Geo tie in approval T-450 psi prior to shot. PSI after 20 min- 506 psi. OOH with Gun # 2, All shots fired, Bull Plug Dry. MU & RIH with 2" (2') Geo Dynamic, 6 SPF,6.8 Gram, Razor XDP Charge. 10.5' off set fromGR/CCL to top shot. T-~507 psi before shot. Correlate & Perforate Interval: (T3) Middle of sand (5205' - 5207'). Per Geo tie in approval. No Pressure change after shot. OOH with 2" Gun . All shots fired, Bull Plug is Dry- T- 505 psi . MU & RIH with 2-7/8" , Geo Dynamic, 6 spf, 15 Gram, Razor Charge. Correlate & Perforate Interval: (T3) (5200' - 5212'). Per Geo tie in approval. T-506 psi Before shot. Slight wt loss indicator. Slight drop in pressure after shot. T- 490 psi. POOH. OOH with 2-7/8 Gun For T3 interval . All shots fired, Bull Plug is Dry- T- ~490 psi Break off lubricator and LD. RD Eline. MU Production swab cap . Verify Swb is shut Well to be left shut in for ops. Contact Operator. Notify of well status. Job complete. API: 50-133-20705-00-00 Field: Ninilchik Sundry #: 323-633 State: Alaska Rig/Service:Permit to Drill (PTD) #:222-003 _____________________________________________________________________________________ Updated by DMA 12-04-24 SCHEMATIC Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ T12 Thru T18 T3 Thru T9A RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875”Surf 2,287’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”2,031’7,566’ Tubing Details 4-1/2"Tieback 12.6 L-80 DWC/C HT 3.958”Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 -11.000 Cactus EN-2CCL 11" Hgr w/4-1/2" EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’1,558’4.875”6.540”Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’1,564’4.790”6.340”Seal Assy. PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Size Status T3 5,200'5,212'3,824'3,836'12'11/30/2023 Open T5 5,320'5,326'3,943'3,948'6'11/30/2023 Open T6U 5,440'5,466'4,060'4,086'26'11/30/2023 Open T6L 5,484'5,510'4,103'4,128'26'11/29/2023 Open T7 5,575'5,595'4,192'4,212'20'11/29/2023 Open T8 5,656'5,680'4,272'4,295'24'11/29/2023 Open T9A 5,750'5,766'4,363'4,379'16'11/29/2023 Open T-12U 6,099'6,117'4,707'4,724'18'5/11/2022 2-7/8” HC Open T-12L 6,121'6,127'4,728'4,734'6'5/11/2022 2-7/8” HC Open T-16 6,511'6,525'5,113'5,126'14'5/11/2022 2-7/8” HC Open T-17 6,590'6,638'5,191'5,238'48'5/10/2022 2-7/8” HC Open T-17A 6,677'6,691'5,276'5,290'14'5/10/2022 2-7/8” HC Open T-18A 6,719'6,732'5,317'5,330'13'5/10/2022 2-7/8” HC Open T-18B 6,734'6,744'5,332'5,342'10'5/10/2022 2-7/8” HC Open T-18C 6,768'6,782'5,366'5,380'14'5/10/2022 2-7/8” HC Open T 37 7,008’7,028’5,612’5,632’20’3/4/2022 2-7/8” 6SPF Open T 37 7,028’7,038’5,632’5,642’10’3/4/2022 2-7/8” 6SPF Open OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2”TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’6,166’Stuck BHA (372’ in length) –Contains radioactive sources (2/22/22) 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: Pull Cap String, N2 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): 8,603 7590 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 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: Tubing Size: PRESENT WELL CONDITION SUMMARY Jake Flora, 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 ADL0038437 / FEE-Private 222-003 50-133-20705-00-00 Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 2,041 8,430psi 1,663 Size 120 2,287 MD See Attached Schematic 2,980psi 6,880psi 120120 2,287 December 4, 2023 4-1/2" 7,566 Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Kalotsa 8CO 701 C Same 6,1524-1/2" ~1918psi 5,535 N/A Length Liner Top Pkr & N/A 2,031 (MD) 1,558 (TVD) & N/A 7,178 7,355 5,943 Ninilchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic m n P s 66 t 2 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 8:05 am, Nov 22, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.11.21 13:12:58 - 09'00' Noel Nocas (4361) 323-633 SFD 11/24/2023 Perforate BJM 11/27/23 DSR-11/22/23 10-404 *&:JLC 11/27/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.27 15:28:31 -09'00'11/27/23 RBDMS JSB 112823 Well Prognosis Well Name: Kalotsa 8 API Number: 50-133-20705-00-00 Current Status: Gas Producer Permit to Drill Number: 222-003 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) Maximum Expected BHP: 2482 psi @ 5642’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 1918 psi Based on 0.1 psi/ft gas gradient to surface Well Status: Online gas producer @800 mcfd, 6 bwpd @ 55 psi FTP Brief Well Summary: Kalotsa 8 was drilled and completed in February 2021, targeting the lower Tyonek sands. After reaching TD, and performing a wiper trip, the drilling BHA with logging tools became stuck. A production liner was run and the T- 37 sands were shot. The well IP’d at ~2.0 MMCFD and production increased to 3.0 MMCFD before going on a steady decline. In May 2022 the Tyonek 12 & 16 sands were added, restoring production above 4MM. The well has since been on steady decline to the current rate. The purpose of this work/sundry is to increase productivity by adding perforations. Wellbore Conditions: 05/11/22 Perforated Tyonek 12 & 16 sands, max depth 6525’ MD 11/25/22 2.5 DDB to 7295’, sticky mud in bailer 4/19/23 Ran cap string to 6130’ Pre-Sundry Steps: 1. Pull cap string Procedure: 1. Review all approved COAs 2. RU E-line, PT lubricator to 2500 psi 3. Perforate and test the below sands: PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size Status T3 ±5,200' ±5,212' ±3,824' ±3,836' ±12' Proposed TBD T5 ±5,320' ±5,326' ±3,943' ±3,948' ±6' Proposed TBD T5A ±5,360' ±5,365' ±3,982' ±3,987' ±5' Proposed TBD T6U ±5,440' ±5,466' ±4,060' ±4,086' ±26' Proposed TBD T6L ±5,484' ±5,510' ±4,103' ±4,128' ±26' Proposed TBD T7 ±5,575' ±5,595' ±4,192' ±4,212' ±20' Proposed TBD T8 ±5,656' ±5,680' ±4,272' ±4,295' ±24' Proposed TBD T9A ±5,750' ±5,766' ±4,363' ±4,379' ±16' Proposed TBD a. All sands lie in the NINILCHIK UNIT, BELUGA-TYONEK GAS POOL b. If any zone produces sand and/or water or needs isolated, depress water with nitrogen, RIH and set plug above the perforations OR patch across the perforations. 4. RDMO Well Prognosis 5. Turn well over to production & flow test well Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Standard Nitrogen Operations 4. AOGCC RWO Change Form _____________________________________________________________________________________ Updated By DMA 04-25-23 SCHEMATIC Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ T12 Thru T18 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875”Surf 2,287’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”2,031’7,566’ Tubing Details 4-1/2"Tieback 12.6 L-80 DWC/C HT 3.958”Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 -11.000 Cactus EN-2CCL 11" Hgr w/4-1/2" EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’1,558’4.875”6.540”Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’1,564’4.790”6.340”Seal Assy. PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Size Status T-12U 6,099'6,117'4,707'4,724'18'5/11/2022 2-7/8” HC Open T-12L 6,121'6,127'4,728'4,734'6'5/11/2022 2-7/8” HC Open T-16 6,511'6,525'5,113'5,126'14'5/11/2022 2-7/8” HC Open T-17 6,590'6,638'5,191'5,238'48'5/10/2022 2-7/8” HC Open T-17A 6,677'6,691'5,276'5,290'14'5/10/2022 2-7/8” HC Open T-18A 6,719'6,732'5,317'5,330'13'5/10/2022 2-7/8” HC Open T-18B 6,734'6,744'5,332'5,342'10'5/10/2022 2-7/8” HC Open T-18C 6,768'6,782'5,366'5,380'14'5/10/2022 2-7/8” HC Open T 37 7,008’7,028’5,612’5,632’20’3/4/22 2-7/8” 6SPF Open T 37 7,028’7,038’5,632’5,642’10’3/4/22 2-7/8” 6SPF Open OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2”TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’6,166’Stuck BHA (372’ in length) –Contains radioactive sources (2/22/22) Capillary String (3/8”): Installed 4/18/23 Top Bottom MD 0 6,100’ TVD 0 4,707’ _____________________________________________________________________________________ Updated by DMA 11-20-23 PROPOSED Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ T12 Thru T18 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875”Surf 2,287’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”2,031’7,566’ Tubing Details 4-1/2"Tieback 12.6 L-80 DWC/C HT 3.958”Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 -11.000 Cactus EN-2CCL 11" Hgr w/4-1/2" EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’1,558’4.875”6.540”Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’1,564’4.790”6.340”Seal Assy. PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Size Status T3 ±5,200'±5,212'±3,824'±3,836'±12'Proposed TBD T5 ±5,320'±5,326'±3,943'±3,948'±6'Proposed TBD T5A ±5,360'±5,365'±3,982'±3,987'±5'Proposed TBD T6U ±5,440'±5,466'±4,060'±4,086'±26'Proposed TBD T6L ±5,484'±5,510'±4,103'±4,128'±26'Proposed TBD T7 ±5,575'±5,595'±4,192'±4,212'±20'Proposed TBD T8 ±5,656'±5,680'±4,272'±4,295'±24'Proposed TBD T9A ±5,750'±5,766'±4,363'±4,379'±16'Proposed TBD T-12U 6,099'6,117'4,707'4,724'18'5/11/2022 2-7/8” HC Open T-12L 6,121'6,127'4,728'4,734'6'5/11/2022 2-7/8” HC Open T-16 6,511'6,525'5,113'5,126'14'5/11/2022 2-7/8” HC Open T-17 6,590'6,638'5,191'5,238'48'5/10/2022 2-7/8” HC Open T-17A 6,677'6,691'5,276'5,290'14'5/10/2022 2-7/8” HC Open T-18A 6,719'6,732'5,317'5,330'13'5/10/2022 2-7/8” HC Open T-18B 6,734'6,744'5,332'5,342'10'5/10/2022 2-7/8” HC Open T-18C 6,768'6,782'5,366'5,380'14'5/10/2022 2-7/8” HC Open T 37 7,008’7,028’5,612’5,632’20’3/4/2022 2-7/8” 6SPF Open T 37 7,028’7,038’5,632’5,642’10’3/4/2022 2-7/8” 6SPF Open OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2”TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’6,166’Stuck BHA (372’ in length) –Contains radioactive sources (2/22/22) STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. H i l c o r p A l a s k a , L L C Hi l c o r p A l a s k a , L L C Ch a n g e s t o A p p r o v e d R i g W o r k O v e r S u n d r y P r o c e d u r e Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l K a l o t s a 8 ( P T D 2 2 2 - 0 0 3 ) Su n d r y # : X X X - X X X An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a te d t o t h e AO G C C by t h e r i g w o r k o v e r ( R W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a n g e . Se c Pa g e Da t e Pr o c e d u r e C h a n g e Ne w 4 0 3 Re q u i r e d ? Y / N HA K Pr e p a r e d By (I n i t i a l s ) HA K Ap p r o v e d By (I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : A s s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : F i r s t C a l l O p e r a t i o n s E n g i n e e r D a t e 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 - 1 3 3 - 2 0 7 0 5 - 0 0 - 0 0 We l l N a m e / N o . NI N I L C H I K U N I T K A L O T S A 8 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 3/ 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 0 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 86 0 3 TV D 71 7 8 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 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 : LW D , M u d l o g s , C B L , P e r f 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 3/ 3 / 2 0 2 2 10 8 6 9 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 : K a l o t s a 8 . l a s 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 D a i l y R e p o r t s . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : H i l c o r p K a l o t s a 8 E O W R e p o r t . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 D r i l l i n g D y n a m i c s L o g MD 2 i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 D r i l l i n g D y n a m i c s L o g MD 5 i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 D r i l l i n g D y n a m i c s L o g TV D 2 i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 D r i l l i n g D y n a m i c s L o g TV D 5 i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 F o r m a t i o n L o g M D 2i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 F o r m a t i o n L o g M D 5i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 F o r m a t i o n L o g T V D 2i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 F o r m a t i o n L o g T V D 5i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 G a s R a t i o L o g M D 2i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 G a s R a t i o L o g M D 5i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 G a s R a t i o L o g T V D 2i n . p d f 36 3 8 4 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 1 o f 5 Su p p l i e d b y Op Su p p l i e d b y Op Ka l o t s a 8 . 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 - 1 3 3 - 2 0 7 0 5 - 0 0 - 0 0 We l l N a m e / N o . NI N I L C H I K U N I T K A L O T S A 8 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 3/ 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 0 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 86 0 3 TV D 71 7 8 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 G a s R a t i o L o g T V D 5i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D C o m b o L o g M D 2i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D C o m b o L o g M D 5i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D C o m b o L o g T V D 2i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D C o m b o L o g T V D 5i n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 D r i l l i n g D y n a m i c s L o g MD 2 i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 D r i l l i n g D y n a m i c s L o g MD 5 i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 D r i l l i n g D y n a m i c s L o g TV D 2 i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 D r i l l i n g D y n a m i c s L o g TV D 5 i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 F o r m a t i o n L o g M D 2i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 F o r m a t i o n L o g M D 5i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 F o r m a t i o n L o g T V D 2i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 F o r m a t i o n L o g T V D 5i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 G a s R a t i o L o g M D 2i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 G a s R a t i o L o g M D 5i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 G a s R a t i o L o g T V D 2i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 G a s R a t i o L o g T V D 5i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D C o m b o L o g M D 2i n . t i f 36 3 8 4 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 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 - 1 3 3 - 2 0 7 0 5 - 0 0 - 0 0 We l l N a m e / N o . NI N I L C H I K U N I T K A L O T S A 8 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 3/ 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 0 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 86 0 3 TV D 71 7 8 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D C o m b o L o g M D 5i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D C o m b o L o g T V D 2i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D C o m b o L o g T V D 5i n . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 S h o w R e p o r t s . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 85 8 6 0 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 : K a l o t s a 8 L W D Fi n a l . l a s 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D F i n a l M D . c g m 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D F i n a l T V D . c g m 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 - 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 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 - F i n a l S u r v e y s . x l s x 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 _ D S R - G I S . t x t 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 _ D S R A c t u a l _ P l a n . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 _ D S R A c t u a l _ V S e c . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 _ D S R . t x t 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D F i n a l M D . e m f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D F i n a l T V D . e m f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D F i n a l M D . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D F i n a l T V D . p d f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D F i n a l M D . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 L W D F i n a l T V D . t i f 36 3 8 4 ED Di g i t a l D a t a DF 3/ 2 3 / 2 0 2 2 72 1 4 6 8 5 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 : K a l o t s a 8_ P e r f _ 0 4 - M a r - 2 0 2 2 _ ( 3 6 7 7 ) . l a s 36 4 2 3 ED Di g i t a l D a t a DF 3/ 2 3 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 _ P e r f _ 0 4 - M a r - 20 2 2 _ ( 3 6 7 7 ) . p d f 36 4 2 3 ED Di g i t a l D a t a DF 4/ 1 4 / 2 0 2 2 50 5 2 9 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : K a l o t s a 8 _ C B L _ 2 - Ma r - 2 0 2 2 _ ( 3 6 7 4 ) . l a s 36 4 7 6 ED Di g i t a l D a t a DF 4/ 1 4 / 2 0 2 2 E l e c t r o n i c F i l e : K a l o t s a 8 _ C B L _ 2 - M a r - 20 2 2 _ ( 3 6 7 4 ) . p d f 36 4 7 6 ED Di g i t a l D a t a Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 3 o f 5 Ka l o t s a 8 L W D Fi 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 - 1 3 3 - 2 0 7 0 5 - 0 0 - 0 0 We l l N a m e / N o . NI N I L C H I K U N I T K A L O T S A 8 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 3/ 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 0 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 86 0 3 TV D 71 7 8 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No We l l C o r e s / S a m p l e s I n f o r m a t i o n : Re c e i v e d St a r t S t o p C o m m e n t s To t a l Bo x e s Sa m p l e Se t Nu m b e r Na m e In t e r v a l IN F O R M A T I O N R E C E I V E D DF 5/ 2 5 / 2 0 2 2 68 5 6 6 5 9 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : K A L O T S A - 8 G U N RU N 1 . l a s 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 68 2 4 6 5 8 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 : K A L O T S A - 8 G U N RU N 2 . l a s 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 67 4 6 6 4 6 5 E l e c t r o n i c D a t a S e t , F i l e n a m e : K A L O T S A - 8 G U N RU N 3 . l a s 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 67 0 8 6 4 3 8 E l e c t r o n i c D a t a S e t , F i l e n a m e : K A L O T S A - 8 G U N RU N 4 . l a s 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 66 0 6 6 3 7 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 : K A L O T S A - 8 G U N RU N 5 G U N 1 . l a s 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 62 5 3 5 9 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 : K A L O T S A - 8 G U N RU N 5 G U N 2 . l a s 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 62 1 4 5 9 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 : K A L O T S A - 8 G U N RU N 6 . l a s 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 E l e c t r o n i c F i l e : K A L O T S A - 8 G U N R U N 1 . p d f 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 E l e c t r o n i c F i l e : K A L O T S A - 8 G U N R U N 2 . p d f 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 E l e c t r o n i c F i l e : K A L O T S A - 8 G U N R U N 3 . p d f 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 E l e c t r o n i c F i l e : K A L O T S A - 8 G U N R U N 4 . p d f 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 E l e c t r o n i c F i l e : K A L O T S A - 8 G U N R U N 5 G U N 1. p d f 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 E l e c t r o n i c F i l e : K A L O T S A - 8 G U N R U N 5 G U N 2. p d f 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 E l e c t r o n i c F i l e : K A L O T S A - 8 G U N R U N 6 . p d f 36 6 4 9 ED Di g i t a l D a t a DF 5/ 2 5 / 2 0 2 2 E l e c t r o n i c F i l e : K A L O T S A - 8 P E R F F I N A L . p d f 36 6 4 9 ED Di g i t a l D a t a 3/ 3 0 / 2 0 2 2 22 0 0 8 0 6 3 6 1 8 0 2 Cu t t i n g s Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 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 - 1 3 3 - 2 0 7 0 5 - 0 0 - 0 0 We l l N a m e / N o . NI N I L C H I K U N I T K A L O T S A 8 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 3/ 4 / 2 0 2 2 Pe r m i t t o D r i l l 22 2 0 0 3 0 Op e r a t o r Hi l c o r p A l a s k a , L L C MD 86 0 3 TV D 71 7 8 Cu r r e n t S t a t u s 1- G A S 9/ 2 2 / 2 0 2 3 UI C No 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 : 3/ 4 / 2 0 2 2 Re l e a s e D a t e : 1/ 2 5 / 2 0 2 2 Fr i d a y , S e p t e m b e r 2 2 , 2 0 2 3 AO G C C P a g e 5 o f 5 M. G u h l 9/ 2 2 / 2 0 2 3 RBDMS JSB 040423 Nip Veit Name: K 05_pa. 00 . ; . Welf 'Registration N"o. 5p-133-207 o CAU. NE GBq t QM- 8 Cil. 241BE RADIOACTIVE, SOUR(: 12 Cil CS=13,7 RADIOACTIVE -• • ` ..AND : ONE .74 - G6't 2:.2022.�FIRST SOURCE ABANDONED: February "M : 64 FT. TVD SOURCE LOCATED_AT-787 FT, = COND SoU$CE LOCA�D AT 7887 FT °T, AI D,. SE " 6�k69 FT • rtdD• PLUG _BACK DEPTH FOP T. Y p CEME PLUG7318 FT -'MD, &. 5907, _ AVOiD BORE BE�OW PLI.. CK. AND, D0 NOT :R� ENTER THIS \ NEL- L BEt,OW PLUG BACK BEPOR r CONTACTING THE NUCLEAR •REGULATOR`f``� ' ommiSSION. : 2022-1130_Location_Ninilchiuk_Kalotsa-8_RA_source_sign_bn Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 11/30/2022 P. I. Supervisor FROM: Bob Noble SUBJECT: Location Petroleum Inspector Ninilchik Unit Kalotsa 8 Hilcorp Alaska LLC PTD 2220030; Sundry 322-084 11/30/2022: I was requested to stop by the Kalosta pad to determine of Hilcorp has complied with the conditions of approval for Sundry 322-084 (approval to leave a radioactive source in the well; stuck BHA while drilling). The approval conditions require Hilcorp to affix to the wellhead a permanent surface marker as a visual warning that a radioactive soured was left in the well. The radioactive source is isolated, below the plug back depth. I arrived at the Kalotsa pad and observed a sign consistent with the approved Sundry requirements. Attachments: Photos (2) 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.04.13 12:52:23 -08'00' 2022-1130_Location_Ninilchiuk_Kalotsa-8_RA_source_sign_bn Page 2 of 2 Ninilchik Unit Kalotsa-8 (PTD 2220030) - Radioactive Source Signage Photos by AOGCC Inspector B.Noble 11/30/2022 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 05/23/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 9950 DATA TRANSMITTAL KALOTSA 8 (PTD 222-003) PERF 5/10/2022 Please include current contact information if different from above. PTD:222-003 T36649 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.25 10:49:36 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 4/13/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Kalotsa 8 (PTD 222-003) CBL 3/02/2022 Please include current contact information if different from above. 222-003 T36476 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.04.14 08:22:13 -08'00' 2a_-OD3 Hil" AWL*, LLC Date: 03/30/2022 David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 CenterPoint Drive, Suite 1400 D Anchorage, AK 99503 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 KALOTSA 8 (PTD 222-003) Washed and Dried Well Samples (02/18/2022) A Set (6 Boxes): WELL Box SAMPLE INTERVAL (FEET / MD) KALOTSA 8 BOX 1 OF 6 2200' - 3300' MD KALOTSA 8 BOX 2 OF 6 3300' - 4340' MD KALOTSA 8 BOX 3 OF 6 4340' - 5400' MD KALOTSA 8 BOX 4 OF 6 5400' - 6440' MD KALOTSA 8 BOX 5 OF 6 6440' - 7600' MD KALOTSA 8 BOX 6 OF 6 7600' - 8063' MD (TD) Please include current contact information if different from above. Rec; EN ED MAR 3 0 2ULl Please acknowledge receipt by signing and returning one copy of this transmittal. Received By-:---- Date: ,/, 0GCC Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 3/22/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Kalotsa 8 (PTD 222-003) Perf 3/4/2022 Please include current contact information if different from above. 222-003 T36423 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.23 13:55:25 -08'00' Global Radiation Safety 3000 N. Sam Houston Parkway East · Plaza 1, Office 5320M Houston, Texas 77032-3219 March 9, 2022 U.S. Nuclear Regulatory Commission – Region IV 1600 East Lamar Blvd. Arlington, TX 76011 Attn: Division Director - DNMS Re: Notification of Well Logging Sealed Source Abandonment Halliburton Energy Services, Inc. USNRC License No. 42-01068-07 Amendment No. 86 This letter comprises the required 30-day written notification of source abandonment as required by 10 CFR 39.77(d). This is a follow-up to the communications between Halliburton and NRC Region IV in which permission to proceed with the abandonment was granted on February 22, 2022. Date of Occurrence: Company Name: Well Name & Registration No.: Well Location: Rig Name: 18 – February - 2022 HilCorp Alaska, LLC 3800 Center Point Dr. Suite 1400 Anchorage, AK 99503 Kalotsa 8 / 50-133-20705-00-00 North 60° 06' 13.670" West 151° 35' 25.937" HEC169 Kenai Peninsula Borough Sources Abandoned: One 296GBq (8Ci) Am241Be doubly encapsulated radioactive sealed source, solid, special form. Eckert & Ziegler, Model LWD4133; Source Serial Number S10- 006 and One 74Gbq (2.0 Ci) Cs-137 doubly encapsulated radioactive sealed source, solid, special form. QSA Global, Inc. Model CDC.CY13; Source Serial Number 74855B Immobilization method: Brief Well Summary – The Kalotsa 8 production hole was drilled to a TD of 8,603’. A trip was made to the shoe and then back towards TD. The drilling BHA became stuck with zero movement working drilling jars and unable to circulate. Eline was rigged up to free point then left-hand torque was applied and a string shot fired to back off drill pipe. The drill pipe was recovered leaving top of fish at 7,592’ and 372’ of BHA in the hole. A fishing assembly was run with no movement or circulation gained. The BHA contains two sources and is not recoverable. A sidetrack is too risky. The BHA will be abandoned in place and the well completed as is. 3/9/2022 Notification of Source Abandonment USNRC License No. 42-01068-07 Page 2 of 3 Results of Efforts to Immobilize and set sources in place: Depth of Well: Depth of Bottom of Fish: Depth of Sources: Depth of Top of Fish: Depth of Bottom of Cement Plug: Depth of Top of Cement Plug: Plan Forward: 1.Back off fishing assembly and trip to surface. LD fishing tools. 2. Make 6-3/4” cleanout run to top of fish. Include jars. 3. Run 4-1/2” liner and cement per program. a.Surface casing shoe – 2287’ b.Planned TOL - 2073’ c.Cement volume 189 bbls Abandonment procedure successfully completed on 22 - February - September - 2022 8603 ft. MD / 7187 ft. TVD 7964 ft. MD / 6545 ft. TVD Am241Be source located at 7872 ft. MD / 6454 ft TVD Cs-137 source located at 7887 ft. MD / 6469 ft. TVD 7592 ft. MD / 6177 ft. TVD 7592 ft. MD / 6177 ft. TVD 7318 ft. MD / 5907 ft. TVD Description of Recovery Attempts: Stuck in hole @ 7959' MD, 6547' TVD. Currently free pointing. Once free point is established drill pipe will be backed off and pulled out of hole to pick up fishing jars. Free point was successful, currently tripping out of hole to pick up fishing jars. 20-Feb-22 14:00 Lay down drilling jars. Pick up fishing jars and run back in hole. 21-Feb-22 05:00 Wash down, circulate out gas and screw in to BHA. Start jarring operation. Continuous jarring for 12 Hrs. Attempts to pull up, go down, rotate and circulate all failed. No BHA movement at all was detected. Decision was made by HilCorp to plug and abandon pending approval from the NRC. Warning Plaque: See Attachment 1 for a representation of the plaque. Attached Supporting Documents Kalotsa 8 10-403 Abandon Source Program Kalotsa 8 Proposed Schematic Kalotsa 8 Fish Schematic Kalotsa 8 R200-BHA2-BHA Tally Radiation Source Sealed Source Certificates Radiation Source Leak Tests 3/9/2022 Notification of Source Abandonment USNRC License No. 42-01068-07 Page 3 of 3 Sincerely, Kevin Bowery Sr. Radiation Safety Officer – NAL / GOM Halliburton Energy Services, Inc. Email: Kevin.Bowery@Halliburton.com Attachment: (1) Representation of Warning Plaque ATTACHMENT 1 Representation of Permanent Warning Plaque Well Name: Kalotsa 8 Well Registration No. 50-133-20705-00-00 CAUTION ONE 296 GBq (8 Ci) AM-241BE RADIOACTIVE SOURCE AND ONE 74 GBq (2 Ci) CS-137 RADIOACTIVE SOURCE ABANDONED February 22, 2022. FIRST SOURCE LOCATED AT 7872 FT. MD. 6454 FT. TVD AND SECOND SOURCE LOCATED AT 7887 FT. MD. 6469 FT TVD. PLUG BACK DEPTH TOP OF CEMENT PLUG 7318 FT. MD & 5907 FT. TVD. AVOID BORE BELOW PLUGBACK AND DO NOT RE- ENTER THIS WELL BELOW PLUG BACK BEFORE CONTACTING THE NUCLEAR REGULATORY COMMISSION. Well Prognosis Well: Kalotsa 8 Date: 2/21/22 Well Name: Kalotsa 8 API Number: 50-133-20705-00-00 Current Status: Abandon sources / Run Liner Estimated Start Date: 2/21/22 Rig: Rig 169 Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: TBD Regulatory Contact: Cody Dinger 777-8389 Permit to Drill Number: 222-003 First Call Engineer: Frank Roach (907)777-8413 (O)(907)854-2321 (M) Second Call Engineer Sean Mclaughlin (907)-223-6784 (M) AFE Number: Brief Well Summary – The Kalotsa 8 production hole was drilled to a TD of 8,603’. A trip was made to the shoe and then back towards TD. The drilling BHA became stuck with zero movement working drilling jars and unable to circulate. Eline was rigged up to free point then left-hand torque was applied and a string shot fired to back off drill pipe. The drill pipe was recovered leaving top of fish at 7,592’ and 372’ of BHA in the hole. A fishing assembly was run with no movement or circulation gained. The BHA contains two sources and is not recoverable. A sidetrack is too risky. The BHA will be abandoned in place and the well completed as is. Plan Forward: 1.Back off fishing assembly and trip to surface. LD fishing tools. 2.Make 6-3/4” cleanout run to top of fish. Include jars. 3.Run 4-1/2” liner and cement per program. a.Surface casing shoe – 2287’ b.Planned TOL - 2073’ c.Cement volume 189 bbls Attachments 1.Actual Schematic 2.Proposed Schematic 3.BHA Tally Updated by FVR 02-18-2022 Proposed SCHEMATIC Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 TOF @ 7,592’ MD TD = 8,603’ / TVD = 7,178’ RKB to GL = 18’ 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 CDC 6.875” Surf 2,288’ 4-1/2” Prod Liner 12.6 L-80 DWC/C HT 3.958” 2,069’ 7,592’ 4-1/2” Prod Tieback 12.6 L-80 DWC/C HT 3.958” Surf 2,069’ 4-3/4" Stuck BHA 7,592’ 7,967’ 1 16” 7-5/8” 9-7/8” hole Stuck BHA JEWELRY DETAIL No. Depth ID OD Item 1 2,069’ 4.875” 6.540” Liner hanger / LTP Assembly 2 2,069’ 4.790” 6.340” Seal Stem OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 L – 345 sx / T – 240 sx 4-1/2” TBD 6-3/4” hole 2 TOF @ 7,592’ Updated by FVR 02-18-2022 Current Fish SCHEMATIC Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 TOF @ 7,592’ MD TD = 8,603’ / TVD = 7,178’ RKB to GL = 18’ 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 CDC 6.875” Surf 2,288’ 4-3/4" Stuck BHA CDS-40 7,592’ 7,967’ 16” 7-5/8” 9-7/8” hole Stuck BHA OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 L – 345 sx / T – 240 sx 4-1/2” TBD 6-3/4” hole TOF @ 7,592’ WELL INFORMATION Created On : Feb 11 2022 Customer :Hilcorp Alaska, LLC Well Name :Kalotsa 8 Job Number :AK-XX-0907653458 Rig Name :HEC 169 Field Name :Ninilchik Unit Country :USA BHA Tally Drillstring IADC Rig BHA#2 Run#200 Length (ft)Length Cumulative COMPONENT DATA (ft) Item #Description Serial Number OD ID Gauge Weight Top Connection Bottom Connection(in)(in)(in)(lbpf) 1 6.75" HDBS MM55D PDC 12998262 4.770 1.500 6.750 54.88 P 3-1/2" REG 0.96 0.96 2 4 3/4" SperryDrill Lobe 5/6 - 8.3 stg 11625350 4.750 2.794 44.57 B 3-1/2" IF B 3-1/2" REG 29.79 30.75 3 4 3/4" DM Collar 12040980 4.660 1.250 48.20 B 3-1/2" IF P 3-1/2" IF 8.97 39.72 4 4 3/4" GM Collar 90669807 4.740 1.250 48.20 B 3-1/2" IF P 3-1/2" IF 9.27 48.99 5 4 3/4" ADR Collar 90669956 5.050 1.250 53.70 B 3-1/2" IF P 3-1/2" IF 27.29 76.28 6 4 3/4" ALD Collar 90669107 5.140 1.250 5.690 45.50 B 3-1/2" IF P 3-1/2" IF 14.35 90.63 Stabilizer 5.690 7 4 3/4" CTN Collar 90669107 4.740 1.250 50.50 B 3-1/2" IF P 3-1/2" IF 11.13 101.76 8 4 3/4" PWD 90669011 4.710 1.250 47.90 B 3-1/2" IF P 3-1/2" IF 9.15 110.91 9 4 3/4" TM HOC 12334772 4.850 1.250 46.10 B 3-1/2" IF P 3-1/2" IF 11.09 122.00 10 4 3/4" Flex Collar 11564357 4.690 2.250 45.33 B 3-1/2" IF P 3-1/2" IF 31.15 153.15 11 4 3/4" Flex Collar 11623625 4.700 2.250 45.58 B 3-1/2" IF P 3-1/2" IF 30.75 183.90 12 X-Over Sub UCOD 4886 5.220 2.690 53.57 B 5.25" CDS-40 P 3-1/2" IF 2.49 186.39 13 6 jts 4.5" 36.86# CDS40 HWDP 4.500 2.813 36.86 183.25 369.64 14 X-Over Sub UCOD 4708 5.200 2.250 58.83 B 3-1/2" IF P 5.25" CDS-40 2.54 372.18 15 4 3/4" YellowJacket Jar A23804 4.860 2.250 49.67 B 3-1/2" IF P 3-1/2" IF 29.24 401.42 16 X-Over Sub UCOD 4705 5.130 2.310 56.16 B 5.25" CDS-40 P 3-1/2" IF 2.41 403.83 17 11 jts 4.5" 36.86# CDS40 HWDP 4.500 2.813 36.86 336.01 739.84 Total:739.84 BIT DATA Bit Number :2 Nozzles :5x11 Bit Size (in):6.750 TFA (in2):0.4640 Manufacturer :HDBS Dull Grade In :NEW Model :MM55D Dull Grade Out : Serial Number :12998262 INSITE V9.2.0 Page 1Job No:AK-XX-0907653458 Well Name:Kalotsa 8 BHA Tally MOTOR DATA Motor Number :Bend (deg) :1.502 OD (in):4.750 Nozzles (32nd) :0.0 Manufacturer :Sperry Drilling Avg Diff Press : Model :TerraForce Cumul Cir Hrs : Serial Number :11625350 BHA Weight (klb)(klb) in Air (Total):29.71 in Mud (Total):25.64 Mud Weight (ppg) :9.00 in Air (Below Jars) :15.74 in Mud (Below Jars) :13.58 COMMENTS Motor assembly for 6-3/4” Production Hole section 4-3/4” TerraForce Mud Motor, @ 1.50°, 5/6 8.3stg, 1.00 Rev/Gal Dir: 34.97’, Gamma: 44.28’ Res: 62.44’, Density: 80.82’, Porosity: 95.59’, PWD: 107.27’ RFO= 350/481 x 360= 261.95° Planned Parameters: 200-290 GPM, 60-80 RPM, 3k-8k WOB Torque Bit - 8K, 3-1/2” IF - 10K Jar Hrs. In: 133.26 / Jar Hrs. Out: XXX INSITE V9.2.0 Page 2Job No: AK-XX-0907653458 Well Name: Kalotsa 8 BHA Tally STATE OF WISCONSIN RADIOACTIVE MATERIALS LICENSE 071-1234-01 SEALED SOURCE LEAK TEST CERTIFICATE RAM ACCESSION NO.186573 HALLIBURTON ENERGY SERVICES -SPERRY LOCATION 0190 -PRUDHOE BAY -AK (LWD) CONTACT PERSON CRAIG ZAWADZKI/JOHN REYNOLDS PHONE 907-670-5828 HALLIBURTON ENERGY SERVICES SPERRY SPERRY DRILLING SERVICES 2805 Spine Road PRUDHOE BAY,AK 99734 UNITED STATES LEAK TEST ANALYSIS EQUIPMENT NO.11509998 DEVICE/TOOL NUMBER MODEL #LWD4133 MANUFACTURER SOURCE SERIAL NO.S10-006 MANUFACTURER S/N ISOTOPE Am-241Be SOURCE ORIGINAL ACTIVITY 8000 mCi 296 GBq ASSAY DATE 1/21/2010 DATE SOURCE WIPED 26 Oct 2021 REASON FOR TEST PERIODIC ANALYSIS DATE 02 Nov 2021 ANALYTICAL METHOD Liquid Scintillation Counting GROSS SAMPLE COUNT 21.33 cpm INSTRUMENT Perkin Elmer Tri-Carb 3110TR 130414 BACKGROUND 21.33 cpm COUNTING EFFICIENCY 95% NET SAMPLE COUNT 0 dpm MINIMUM DETECTABLE ACTIVITY 1.16E-05 µCI 0.43 Bq SAMPLE ANALYSIS ACTIVITY 0 µCI 0 Bq SOURCE PASSES TEST PASS/FAIL CRITERION 0.005 µCI 185 Bq ACTION LEVEL 0.001 µCI 37 Bq ANALYST Jerry Wiza COMMENTS:_ STATE OF WISCONSIN RADIOACTIVE MATERIALS LICENSE 071-1234-01 SEALED SOURCE LEAK TEST CERTIFICATE RAM ACCESSION NO.186571 HALLIBURTON ENERGY SERVICES -SPERRY LOCATION 0190 -PRUDHOE BAY -AK (LWD) CONTACT PERSON CRAIG ZAWADZKI/JOHN REYNOLDS PHONE 907-670-5828 HALLIBURTON ENERGY SERVICES SPERRY SPERRY DRILLING SERVICES 2805 Spine Road PRUDHOE BAY,AK 99734 UNITED STATES LEAK TEST ANALYSIS EQUIPMENT NO.11794119 DEVICE/TOOL NUMBER MODEL #CDC.CY13 MANUFACTURER SOURCE SERIAL NO.74855B MANUFACTURER S/N ISOTOPE Cs-137 SOURCE ORIGINAL ACTIVITY 2000 mCi 74 GBq ASSAY DATE 8/18/2009 DATE SOURCE WIPED 26 Oct 2021 REASON FOR TEST PERIODIC ANALYSIS DATE 02 Nov 2021 ANALYTICAL METHOD Liquid Scintillation Counting GROSS SAMPLE COUNT 21.33 cpm INSTRUMENT Perkin Elmer Tri-Carb 3110TR 130414 BACKGROUND 21.33 cpm COUNTING EFFICIENCY 95% NET SAMPLE COUNT 0 dpm MINIMUM DETECTABLE ACTIVITY 1.16E-05 µCI 0.43 Bq SAMPLE ANALYSIS ACTIVITY 0 µCI 0 Bq SOURCE PASSES TEST PASS/FAIL CRITERION 0.005 µCI 185 Bq ACTION LEVEL 0.001 µCI 37 Bq ANALYST Jerry Wiza COMMENTS: From:McLellan, Bryan J (OGC) To:AOGCC Records (CED sponsored) Subject:Kalotsa 8 (PTD 222-003) wellfile Date:Thursday, December 8, 2022 4:23:45 PM Attachments:NRC 30 Day Letter of Abandonment Feb_22_2022 Alaska.pdf Please add the attached to the wellfile in association with Sundry 322-084. Thank you 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 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): Ninilchik Field GL: 126.6' 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 (ft MSL) 22. Logs Obtained: 23. BOTTOM 16" X-56 120' 7-5/8" L-80 1,662' 4-1/2" L-80 6,152' 4-1/2" L-80 1,564' 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 Rate232 February 17, 2022 February 6, 2022 C061505 / ADL384372 N/A N/A N/AN/A N/A 8,603' MD / 7,178' TVD LWD, Mudlogs, CBL, Perf Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 002689 Oil-Bbl: suspension, or abandonment, 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 if necessary N/A2689 Flowing *** Please see attached schematic for perforation detail *** 0 Water-Bbl: PRODUCTION TEST 3/6/2022 Date of Test: 0 3/13/2022 24 Flow Tubing 0 84# 29.7# 120' 2,031' 7,566' Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 12.6# 2,041' 1,560' Surface DEPTH SET (MD) PACKER SET (MD/TVD) Surface CASING WT. PER FT.GRADE 12.6# 207419 207394 TOP SETTING DEPTH MD Surface SETTING DEPTH TVD 2235407 BOTTOM TOP 6-3/4" 93 bbls Surface 9-7/8" HOLE SIZE AMOUNT PULLED 50-133-20705-00-00 Kalotsa 8 209768 2233354 1356' FNL, 2021' FEL, Sec 12, T1S, R14W, SM, AK CEMENTING RECORD 2235172 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 3/4/2022 2078' FSL, 373' FWL, Sec 7, T1S, R13W, SM, AK 1121' FNL, 2052' FEL, Sec 12, T1S, R14W, SM, AK 222-003 / 322-084 / 322-077 Beluga / Tyonek Gas Pool 144.6' 7,355' MD / 5,943' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas Conductor Surface 2,287' L - 345 sx / T - 210 sx Driven L - 423 sx / T - 95 sx Surface N/A SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 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, Tieback Assy.Tieback TUBING RECORD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 8:12 am, Mar 16, 2022 G Completion Date 3/4/2022 MDG RBDMS 3/16/2022 MDG SFD 11/8/2022 DSR-3/16/22DLB 03/23/2022BJM 10/26/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval T-37 7,008' 5,612' 914' 885' 990' 950' 5,062' 3,689' 5,164' 3,789' 6,945' 5,540' 7,807' 6,390' 8,313' 6,891' 8,500' 7,076' 8,573' 7,149' T 110 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 Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 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: 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. 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). 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, 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. T 110 Formation at total depth: T 2 Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Reports. Signature w/Date: 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. INSTRUCTIONS Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME T 100 T 37 Bel A Bel 136 ST 6 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager T 60 T 90 Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 3.15.2022Digitally 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: 2022.03.15 16:59:09 -08'00' Monty M Myers _____________________________________________________________________________________ UpdatedBy: CJD03/15/22 Schematic Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 1 T-37 PBTD = 7,355’ / TVD = 5,943’ TD = 8,603’ / TVD = 7,161’ RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” TOF @ 7,590 Note: Contains radioactive sources 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 CDC 6.875”Surf 2,287’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”2,031’7,566’ Tubing Details 4-1/2"Tieback 12.6 L-80 DWC/C HT 3.958”Surf 2,041’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 17.63 17.63 -11.000 Cactus EN-2CCL 11" Hgr w/4-1/2"EUE 8RD lift & suspend threads, 4" type H BPV profile, 1-3/8" NPT Control Line ports 1 2,031’1,558’4.875”6.540”Flex-Lock V Liner Hanger, HRD-E ZXP, 5.5" x 7.63" L- 80 Liner Top Packer w/5.75" PBR 2,041’1,564’4.790”6.340”Seal Assy. PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Size Status T 37 7,008’7,028’5,612’5,632’20’3/4/22 2-7/8” 6SPF Open T 37 7,028’7,038’5,632’5,642’10’3/4/22 2-7/8” 6SPF Open OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2”TOC 2,103’ MD CBL 3-2-22 FISH Depth MD Depth TVD Description 7,590’6,166’Stuck BHA (372’in length) –Contains radioactive sources (2/22/22) Activity Date Ops Summary 2/3/2022 Disconnect service lines Mud water and air, Pull electrical lines and coil on buildings, Disconnect service loop and kelly hose, L/D torque bushing, P/U cradle and L/D Top Drive, Clear floor of all non essential equipment, Install shipping beams in cellar, Prep and scope derrick L/D torque tube,;Prep to Lay Over derrick unspool drilling line and coil on derrick with service loop and kelly hose, remove wind walls f/ pits and rig floor, crane off centrifuge, start cooling down boiler, Move offices to Kalotsa pad and set up.;Lay over derrick and prep f/ transport, disconnect pit interconnects and lower degasser prep pits f/ transport L/D pit rooves, disconnect f/ power, Prep and lower dog house into water tank, disconnect all power to all modules and coil up electric lines, swing grasshoppers into travel position and;pin, clear snow and misc equipment and ship to Kalotsa Pad, Prep and lay pad f/ felt liner and mats over well, organize pad and clear snow. ETA rig movers 0700 hrs 2/4/2022 Set matting on Liner on Kalotsa 8. Load out and haul Pits 1,2,3, Pumps 1,2, Doghouse, Gen House, TD HPU, Boiler, Chip out handy berm from around rig and load in C-Can. Crain Iron Roughneck and Choke House. Lay over floor windwall. Chip out and rig down 2" water lines. fold over board widwalls. Snow;removal with Loader. Miscellaneous rigging down and securing by hand. Crane off derrick, draworks, and sub. Load out and haul derrick, draworks, sub, Iron Roughneck HPU, Pony subs. Finish setting matts on Kalotsa 8. Replace shut in valve on boiler #2. Miscellaneous rigging down by hand. Snow;removal by hand and loader. Clean and organize Paxton 11 Pad. Sent 48 hour notice to AOGCC for Diverter test at 15:54pm.;Set pony subs, set sub over well and center, set draw works skid, crane off derrick and pin to sub, Spot in dog house water tank, raise derrick board and pin with crane , set iron roughneck on floor, raise wind wall on rig floor set choke house;spot Top drive HPU, Set pit modules and Jig, Set in pump 1&2, Spot in boiler and diesel tank, fire up gen and plug in lights, Raise dog house into drilling position, prep to scope derrick, raise pit rooves, hook up interconnects between modules, swing grasshoppers into;drilling position and run electrical lines, power up modules, spot in third party shacks, spot in gen 3, spot pipe tubs and clear snow for catwalk area, Organize pad, raise derrick and pin, prep to scope derrick. Hook up break linkage and electrical to dog house. 2/5/2022 Move Boiler house forward for proper jumper line reach. M/U equalizers and jumper lines in between pits. Untie kelly hose/ service loop from mast, lower drill line for mast. Take on water in water tank. Finish prepping boiler for operation. Complete felt, liner and matts for catwalk and set catwalk;and rig up same. Set clamshell and pit windwalls with crane. Install remaining floor windwall framework. Set cement water tank and gas buster. Begin dressing mud pump # 2 with 5- 1/2" Liners. Install S-Pipe on standpipe. Continue hooking up Pason Lines, Spool up drilling line on draworks. Secure;torque tube in upper section of derrick. Bring in 21-1/4" Annular Preventer and hand off to cellar bridge cranes. Bring in crew change trailer and power trailer and set up. Installing Handy Berm around Rig. Raise upper section of mast and set dogs. Install omniwrap on kelley hose, raise gas buster;and hook up flow line/ panic line. Install T-Bar, Dressing MP #1 with 5-1/2" Liners and swabs.;Continue dressing mud pump #2 w/ 5.5'' liners and swabs, take on water to pits and heat with steam to roll through pits, pressure up on #2 boiler and put on line, Hoist top drive to floor and pin to blocks unpin and remove cradle, M/U torque bushing and pin, organize pad build docks;Turn S pipe on top drive, hook up service loop and Kelly hose.;Orient Kelly hose for better travel through derrick and pipe clearance, Replace double Ball actuator on top drive M/U saver sub and clamp, adjust lower torque tube f/ well center, Continue dressing mud pump#1, suck out rinse water in pits, start filling pits with water and building spud mud.;Hang bails and elevators, adjust load collar on top drive, tie wire all bolts. 2/6/2022 Hang pull tongs and stage handling equipment on rig floor. Adjust Top Drive torque t/ 16K ft/ lbs. Make up 2" bleeder line t/ standpipe. Hang miscellaneous tarps around sub and rig floor. Continue working through rig acceptance checklist items. Continue to organize yard area.;Break out saver sub and flip rotating hydraulic actuator ring.. Re-install saver sub. Remove excess felt from outside of berm.;Quadco representative test gas alarms while DSM confirms all settings for alarms. Receive test certificate from quadco. Pump through pop off and bleeders, test centrifuge. Test Rig ESD system and set pop offs at 3K.;Break off short tee from diverter preventer. Set DSA and orient tall tee onto surface head. Prep diverter preventer flange to install on tee. Rig up and run diverter preventer and knife valve control lines.;Rig accepted at 12:00 hours. Continue nippling up diverter preventer, Knife valve and vent line. Continue organizing yard. Continue building spud mud. Install bell nipple, fill up line, bleeder and pressure up accumulator.;Test Diverter System by installing joint of 4-1/2" Drill Pipe in elevators inside conductor. Perform Drawdown on Diverter by turning off electric pumps and Function Diverter and confirm closing time of 38 seconds. Knife valve opens in 3 seconds after diverter closes.;Pump water through mud pumps to purge all lines and get reurns to pits. Closed IBOP and pressure tested to 1500 psi. Good test.;Load racks w/ DP and HWDP strap and Tally.;P/U and stand back 52 jts of DP in derrick and 17 jts of HWDP including jar stand, tag bottom 123', install wear ring.;M/U Surface Drilling BHA, Bit motor and MWD, upload MWD and shallow test tools 400 gpm.;Drilling Ahead 9.875'' Surface Hole f/ 123' t/ 338' 405 gpm 750 psi 40 rpm 4k tq on bottom, 4/6k WOB, 50 psi Diff pressure, MW 8.7 ppg, Kicked off 200' 4°/100, Racked back HWDP and P/U Jar stand continued Drilling.;Solids Hauled to G&I 1 bbls Total Solids Hauled to G&I 1 bbls Fluid Hauled to G&I 74 bbls Total Fluid Hauled to G&I 74 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls Daily Metal 0 lbs Total Medal 0 lbs 18 n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NINU Kalotsa 8 Ninilchik Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00022 Kalotsa 8 Drilling Spud Date: 2/7/2022 Cont. Drilling F/ 332' T/ 766' WOB 8-10K, GPM 530, SPP 1475psi, DIFF 50psi, RPM 60, TQ on bottom 4.3K, TQ off bottom 3.7K, PUW 44k, SOW 45k, ROT 45K MW in 8.7ppg with 224 Vis, 8.7ppg with 220 Vis.;Cont. Drilling F/ 766' T/ 1198' WOB 8-12K, GPM 530, SPP 1500psi, DIFF 60psi, RPM 70, TQ on bottom 5.3K, TQ off bottom 4.2K, PUW 48k, SOW 48k, ROT 48K MW in 8.8ppg with 120 Vis, 8.8ppg with 142 Vis. Back ream stand obtain bottoms up and survey.;POOH f/ 1198' t/ 336' with no hole issues, hole took correct fill Cal 10.78 act 10.80.;Service draw works and top drive, grease crown, jack up off drillers side and add shims to level derrick, clean suction screens 70% packed off.;RIH f/ 336' t/ 1198' wash last stand to bottom no hole issues, pump sweep hole unloading on bottoms up, 20% increase in cuttings on sweep back.;Cont. Drilling f/ 1295' t/1553' 530 gpm SPP 1660 psi, 60 rpm 5700 tq on bottom, PUW 51k SOW 49k ROT 50k, MW 9.0 ppg, 205 vis, Distance to plan 12.53' 11.43' high and 5.13' left Max gas 118 units.;Solids Hauled to G&I 104 bbls Total Solids Hauled to G&I 105 bbls Fluid Hauled to G&I 216 bbls Total Fluid Hauled to G&I 290 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls Daily Metal 0 lbs Total Medal 0 lbs 2/8/2022 Drilled 9 7/8” surface hole from 1553’ to 1678’, washpipe leaking on topdrive, pull up hole and rack back one stand. Up wt 51K, down wt 49K.;Replaced washpipe on topdrive, circulated hole off bottom to ensure washpipe secure and holding. Made hook and went back to bottom with no issue.;Resumed drilling from 1678' to 1750', rot wob 14K, 530 gpm-1690 psi, 42 ft/hr ROP,MW 9.1/vis 120, ECD's at 9.6 ppg, BGG 17 units. max gas 51 units.;Cont drilling surface hole from 1750' to 1940', rot wob 14K, 528 gpm-1726 psi, 70 rpm-6913 ft/lbs on bott torque, 32 to 67 ft/hr ROP. Sliding wob 15K, 1628 psi, 36 psi diff, 18 ft/hr ROP, MW 9.1+/vis 117, BGG 13 units, max gas 33 units. Increased pump rate to 545 gpm to see if ROP would increase.;Cont drilling surface hole from 1940' to 2166' WOB 14k 540 gpm 1830 psi SPP 6800 tq on bottom MW 9.2 ppg, sliding 140R every stand to counter 2°/ 100 building in rotary, SLiding WOB 15-16k Diff 60 psi ROP still 15-60 ft/hr.;Cont drilling surface hole ftom 2166' t/ 2295' 14k WOB 6700 tq on bottom, 550 gpm 1944 psi SPP, 52k PUW 47k SOW 48k ROT, Distance to plan 7.47' 5.28' High 5.28' Right.;CBU 550 GPM, Obtain survey on bottom, Flow check well static slight seepage, Blow down top drive and mud lines.;Make Wiper trip f/ 2295' t/ 1104' No hole issues hole took correct fill 20k bobble @ 1319' RIH f/ 1104' t/ 2295' with no issues.;Pump Hi Vis Sweep with wallnut around 550 gpm 1870 psi.;Solids Hauled to G&I 60 bbls Total Solids Hauled to G&I 165 bbls Fluid Hauled to G&I 180 bbls Total Fluid Hauled to G&I 470 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls Daily Metal 0 lbs Total Medal 0 lbs 2/9/2022 From 2295', racked one stand back, flow checked while blow down topdrive and mudline, seeing slight seepage. Cont POOH to 305' LD single HWDP and jars, pulled up to 148', LD NM flex DC's and TM collar.;At 76' plugged in and downloaded MWD at ADR collar.;Cont POOH LD Sperry tools, flushed motor twice and broke off bit. Bit graded 5-4 and is 1/8" under gauge, bearings still good. Sent notification to AOGCC of upcoming initial BOP test at 09:48 on 2-9-22.;Cleared and cleaned rig floor, PU test joint and retrieval tool, drained BOP stack and pulled wear ring, LD same. Flushed hanger profile, PU landing joint/hanger dummy ran and LD same.;RU fill up line, staged centralizers on rig floor, RU Weatherford tongs/elevators and held PJSM, loaded pipe racks with casing. Called for cementers to get pump skid headed to location.;Inspected, PU and MU 3 joint shoe track filling each joint, checked floats (OK). Cont PU single in hole with 7 5/8" 29.7# L-80 CDC casing, torqued to 15,500 ft/lbs, filling on the fly, top filling every 10 jnts. At 2263' MU landing jnt/hanger, S/O and landed on hanger, shoe depth at 2287.55'.;MU circ swedge and topdrive, circ at 222 gpm-49 psi while staging and RU cementers, spot in trucks and R/U Hard line to floor, Load plugs and M/U Cement Head.;PJSM,MU plug launcher and hardline, Halliburton loaded lines with 5 bbls water and checked for leaks. Halliburton pressure tested lines at 870 psi low 3900 psi high, good tests. Halliburton pumped 37 bbls 10.5 ppg Tuned Spacer at 5 bpm- 210 psi, dropped bottom plug and pumped 150 bbls (345 sx);12 ppg Type I II lead cement at 5.2 bpm- 182 psi, followed by 46 bbls (210 sx) 15.8 ppg Type I II tail cement at 4.2 bpm-190 psi. Halliburton dropped top plug, then displaced with 9.4 ppg Spud Mud at 5.7 bpm 190 psi. Slowed pump to 2 bpm with 10 bbl to go. Did bump the plug at 101 bbls into;displacement (calculated 101.3bbls). Held 1060 psi (FCP of 500 psi) for 3 minutes, bled off and floats held. Bled back .5 bbls to pump. Had 37 bbls of Spacer returns to surface and 97 bbls lead cement to surface. Added LCM to lead cement at 2 lb/sx (Bridge Maker). Mix water temp 87 deg. Pumped 100%;excess on both lead and tail. Lost 0 bbls throughout the job. Did reciprocate. CIP at 22:35, 2/9/2022. RD and released Halliburton.;M/U Pack off running tool on landing jt and RIH and set RILD, L/D Landing jt and Running tool, Flush stack with black water function bag multiple times, Blow down lines;N/D Diverter assembly and vent lines, break annular bolts and remove Accumulator lines and plug, remove from well and clean up ring grooves and grease, remove from cellar with loader, break 4'' valves on conductor and clean up and store in drilling connex, break bolts on DSA and remove from well.;Solids Hauled to G&I 64 bbls Total Solids Hauled to G&I 229 bbls Fluid Hauled to G&I 256 bbls Total Fluid Hauled to G&I 726 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls Cement hauled to G&I 93 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 0 lbs p pppppg Did bump the plug at 101 bbls into;displacement (calculatedp ppg p p p pp p 101.3bbls). Held 1060 psi (FCP of 500 psi) for 3 minutes, bled off and floats held. p p Pumped 100%;excess on both lead and tail. Lost 0 bbls throughout the job. Did reciprocate. d 97 bbls lead cement to surface. A )p( p dropped bottom plug and pumped 150 bbls (345 ppgg pp ppg p pp sx);12 ppg Type I II lead cement at 5.2 bpm- 182 psi, followed by 46 bbls (210 sx) 15.8 ppg Type I II tail cement a 2/10/2022 Set wellhead "B" section and hammered up same. Wellhead Rep tested at 250 for 10 min and 3000 for 15 min, good tests. Staged crane at cellar and folded over beaver slide. Cont hauling spud mud to G&I and pit cleaning.;Brought in bed truck and staged BOP cradle at cellar entrance. Stood BOP stack and RU on crane. Transferred BOP stack to cellar bridge cranes, released and parked crane, layed beaver slide back over. Installed caps on 4" outlets on conductor.;Installed BOP stack on wellhead, installed choke and kill lines, obtained RKB measurements for stack and new LD's. Installed drip pan, flow line, riser and 4 way chains. Installed koomey lines, function tested BOPE, opened lower ram doors and installed 2 7/8" x 5" variable rams, buttoned up doors.;Fill Stack with water and Shell test to 3500 psi, leak on choke line bleed off and tighten, retest good.;Test BOP's with 2 7/8'' & 4.5'' Test Jts to 250/3500 psi Test CMV 1-15, Auto and Man IBOP, TIW and Dart, Upper Lower and blind rams, Annular, HCR and Man Choke and Kill, Electric and Man Choke to 1500 psi, Perform Accumulator Draw down test 20 sec/200 psi 88 sec t/ Full Pressure, had three Fail/Pass;Lower Ram Door leaking tighten and retest Pass, Annular on 2 7/8'' Function and retest Pass, lower pipe rams function and retest pass.;Blow down Lines R/D Test Equipment, Set wear ring, Rig up to test Casing, purge lines.;Test Casing t/ 3500 psi f/ 30 min Pumped 1.26 bbls in, bled off 1.6 bbls t/ trip tank.;Blow down choke and mud lines, clear floor and prep t/ P/U DP.;RIH P/U DP f/ rack rabbiting on skate t/ 1428'.;Solids Hauled to G&I 19 bbls Total Solids Hauled to G&I 248 bbls Fluid Hauled to G&I 391 bbls Total Fluid Hauled to G&I 1117 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 0 lbs 2/11/2022 Cont POOH hole with 4 1/2" CDS-40 DP from 1440', racking back stands in derrick.;PU single in hole to 1500' with 4 1/2" DP.;POOH from 1500' racking back in derrick.;Serviced rig and topdrive, checked driveline bolts, installed chain on HES decoder.;PU single in hole with 4 1/2" DP to 1616'.;POOH racking back in derrick from 1616' to surface. Staged BHA #2 items on catwalk and pipe racks, received two trailers of 4 1/2" liner, loaded diverter hardware to be staged at Whiskey pad later.;Held PJSM, PU mudmotor and MU PDC jetted w/5 x 11's, PU DM, GM collars. Scribed tools, RFO = 261.95°, PU ADR, ALD, CTN, PWD and TM HOC collars. Plugged in and downloaded MWD tools. Shallow pulse tested, held PJSM and loaded sources. Blew down topdrive and mudline.;Cont TIH with HWDP and jars to 739'. Cont PU single in hole with 4 1/2" DP from 739' to 2169'.;Wash last stand down tag FC @ 2210' Drill float equipment and cement 235 gpm 1350 psi 35 rpm 5-7k WOB Drill 20' of new hole t/ 2315'.;Displace well t/ 9.1 ppg KCL Polymer mud, 231 gpm 841 psi shut down clean up under shakers and clean pits.;R/U and perform FIT t/ 16.6 ppg EMW 654 psi @ 1666' TVD pumped .27 bbls in bled back .24 bbls, blow down lines and rig up to drill.;Drill Ahead 6.75'' Hole section f/ 2315' t/ 2599' 300 gpm 1540 psi SPP, 65 RPM 5700 ft/lb of torque on bottom, MW 9.1 ppg 10.03ppg ECD, 62k PUW 37k SOW 49k ROT, Distance from Plan 1.17' .88' low .77' right, Madd Passing Slide Intervals as per MWD.;Solids Hauled to G&I 10 bbls Total Solids Hauled to G&I 258 bbls Fluid Hauled to G&I 240 bbls Total Fluid Hauled to G&I 1357 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 0 lbs 2/12/2022 Cont directional drilling 6 3/4" hole from 2599' to 2922'. Sliding wob 2K, 286 gpm-1368 psi, 89 psi diff, 90 to 120 ft/hr ROP. Rot wob 3K, 289 gpm-1405 psi, 65 rpm-5800 ft/lbs on bott torque, 120 ft/hr ROP. MW 9.1/vis 50, ECD's at 10.3 ppg, BGG 15 units, max gas 142 units at 2660'. Mad Pass slides.;DIrectional drill from 2922' to 3341'. Rot wob 3-4K, 291 gpm-1532 psi, 70 rpm-5980 ft/lbs on bott torque, 120 to 130 ft/hr ROP. Sliding wob 2K, 291 gpm-1574 psi, 194 psi diff, 107 ft/hr ROP, MW 9.2/vis 51, ECD's at 10.6 ppg, BGG 7 units, max gas 127 units at 3019'. Mad Pass slide intervals.;CBU for wiper trip at 291 gpm-1380 psi, 80 rpm-6694 ft/lbs off bott torque. Obtain survey and blow down topdrive.;Pull up hole on elevators from 3341' to 2229' No hole issues hole took correct fill.;Service rig, grease blocks and top drive, crown and draw works, pump up compensators on top drive and clean suction screens 20% packed off.;RIH f/ 2229' t/ 3341' wash last stand to bottom, no hole issues hole displaced correct amount, pump Hi Vis Sweep, back on time 10% increase in cuttings, 34 units of gas on bottoms up.;Drilling Ahead f/ 3341' t/ 3475' 290 gpm 1400 psi, 80 rpm 7500 ft/lbs of torque on bottom, 5-9k WOB MW 9.2 ppg 10.44 ppg ECD, Slide Drilling dropping 3°/100 Madd passing slide intervals.;Drilling Ahead f/ 3475' t/ 3777' 290 gpm 1600 psi SPP, 80 rpm 7200 ft/lbs of torque on bottom, MW 9.2 ppg ECD 10.65 ppg ECD, 74k PUW 49k SOW 57k ROT, Slide Drilling 3°/100' Dropping angle t/ 11°, Distance to Plan 4.44' 2.2' Low 3.5' Right.;Solids Hauled to G&I 40 bbls Total Solids Hauled to G&I 298 bbls Fluid Hauled to G&I 120 bbls Total Fluid Hauled to G&I 1477 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 0 lbs p ;Wash last stand down tag FC @ 2210' Drill float equipment and cement 235jg g@qp gpm 1350 psi 35 rpm 5-7k WOB Drill 20' of new hole t/ 2315'.;Displace well t/ 9.1 ppg KCL Polymer mud, 231 gpm 841 psi shut down clean up under shakers gp p p and clean pits.;R/U and perform FIT t/ 16.6 ppg EMW 654 psi @ 1666'TVD pumped .27 bbls in bled back .24 bbls, pppgygp pp ;Test Casing t/ 3500 psi f/ 30 min Pumped 1.26 bbls 2/13/2022 Cont directionally drilling 6 3/4" hole from 3777' to 4111'. Sliding wob 3K, 291 gpm-1500 psi, 22 psi diff, 60 ft/hr ROP. Rot wob 3-4K, 291 gpm-1638 psi, 75 rpm- 7500 ft/lbs on bott torque 120 ft/hr ROP, MW 9.2+/vis 53, ECD's at 10.9 ppg, BGG 14 units, max gas 404 units at 4021'.;Cont drilling from 4111' to 4332'. Rot wob 4K, 290 gpm-1705 psi, 75 rpm-8143 ft/lbs on bott torque, 130 ft/hr ROP. Sliding wob 4K, 291 gpm-1798 psi, 234 psi diff, 103 ft/hr ROP. MW 9.3/vis 51, ECD's 10.8 ppg, BGG 14 units, max gas 538 at 4148'. CBU during mad pass, obtained on bott survey and SPR's.;Pulled 17 stand wiper trip from 4332' up to 3701' on elevators. At 3701' pulled tight numerous times in sand/sandstone and slide. MU topdrive and circ at 289 gpm-1460 psi, 65 rpm-6800 to 7300 ft/lbs off bott torque, backreamed up to 3343' (previous wiper depth). Attempted to pull each stand on;elevators from 3701' to 3343' with no luck. Acted like pulling something up hole that never did clean up. Could slack off 30' after back ream stand and pull up hole just pumping with no issue.;CBU at 3343', 290 gpm-1402', serviced rig while circ, at CBU shut down and serviced topdrive.;TIH on elevators from 3343' to 4275' with no issues. MU last stand and filled pipe. Washed to bottom and made hook.;Cont drilling from 4332' to 4581' 290 gpm 1560 psi SPP, 80 rpm 9100 ft/lbs of torque on bottom, MW 9.3 ECD 10.74,PUW 105k SOW 55k ROT 72k, Pumped Sweep @ 4332' No increase in cuttings return back on time.;Cont drilling from 4581' t/ 4906' 290 gpm 1550 SPP, 80 rpm 11000 ft/lbs torque on bottom, PUW 110k SOW 60k ROT 77k, MW 9.35 ECD 10.75, Sliding and Madd Passing Every Stand, Distance to Plan 9.03' 7.62' Low 4.85' Left.;Solids Hauled to G&I 64 bbls Total Solids Hauled to G&I 362 bbls Fluid Hauled to G&I 96 bbls Total Fluid Hauled to G&I 1573 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 0 lbs 2/14/2022 Cont directionally drilling 6 3/4" hole from 4906' to 5327'. Rot wob 3 to 6K, 291 gpm-1733 psi, 76 rpm-11,600 ft/lbs on bott torque, 125 ft/hr ROP. Sliding wob 3K, 291 gpm-1658 psi, 135 psi diff, 40 to 60 ft/hr ROP, MW 9.3/vis 50, ECD's 10.6 ppg, BGG 27 units, max gas 287 units at 5327'.;Obtained on bottom survey then CBU twice at 120 gpm-1529 psi, 75 rpm-13,300 to 14,700 ft/lbs off bottom torque. Added 1 drum to active pits to aid in wiper trip. Obtained SPR's at 5327', pulled up hole one stand and blew down topdrive.;Pulled up hole on elevators from 5264’ to 4751’ where we encountered tight hole, unable to work through on elevators, MU topdrive and pumped up hole to 4707’ with no issue, no rotary. Up wt coming off bottom 150K. Cont pulling up hole on elevators with two more tight spots at 3264' and 3249', S/O.;and pulled back up hole through tights spots with no issue. Cont pulling up hole to surface casing shoe and parked string at 2241'. Calculated hole fill = 18.4 bbls, actual hole fill = 22.2 bbls.;Serviced rig and topdrive, checked calibration on MWD encoder on drawworks.;RIH on elevators from 2241' to 5272' with no issues. Filled pipe every 1500'. MU topdrive on last stand, filled pipe and washed to bottom. Calculated displacement = 58.5 bbls, actual displacement = 57.2 bbls. Started 20 bbl hi-vis sweep down drillstring and made hook.;Cont directionally drilling 6 3/4" hole from 5327' to 5764' 290 gpm 1869 psi SPP, 80 rpm 12,500 ft/lbs torque on bottom, 9.3 ppg mw 10.7 ppg ECD, PUW 148k SOW 63k ROT 87k.;Cont directional drilling from 5764' to 6133' 290 gpm 1717 SPP, 80 rpm 14000 ft/lbs of torque on bottom, 4-6k WOB, MW 9.35ppg ECD 10.78 ppg, 148k PUW 63k SOW 87k ROT, Distance to Plan 26.46' 26.16' High 3.96' left.;Solids Hauled to G&I 67 bbls Total Solids Hauled to G&I 429 bbls Fluid Hauled to G&I 273 bbls Total Fluid Hauled to G&I 1849 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 0 lbs 2/15/2022 Cont directional drilling 6 3/4" hole from 6133' to 6442'. Rot wob 3 to 5K, 286 gpm-1850 psi, 70 rpm-12,700 ft/lbs on bott torque, 100 ft/hr ROP. Sliding wob 6K, 290 gpm-1875 psi, 172 psi diff, 62 ft/hr ROP, MW 9.3+/vis 55, ECD's at 10.8 ppg, BGG 25 units, max gas 254 at 6439'.;CBU twice at 289 gpm-1716 psi, 70 rpm- 13,200 to 14,600 ft/lbs off bott torque. Obtained on bottom survey and SPR's, pulled one stand and blew down topdrive. Received last 40 jnts 4 1/2" liner and shoe track, Halliburton offloaded 250 sacks lead cement in silo.;Pulled up hole on elevators from 6378', up wt 175K, to 6126' and into tight hole. Made three attempts to work through on elevators, MU topdrive and pumped ourselves up hole to 6026'. Pulled on elevators from 6026' to 5966'. Pumped up hole from 5966' to 5700'. Backreamed from 5700' to 5329'.;Serviced rig and topdrive, increase drilling torque to 17,000 ft/lbs. Received another 250 sacks lead cement in silo (total on location = 500 sacks).;RIH from 5329', dwn wt 70K, to 6385' with no issues. MU last stand and topdrive, filled pipe and washed/reamed to bottom. No fill but did see some swelled formation. Started 20 bbl hi-vis sweep down drill string and made hook.;Cont. directionally drilling 6 3/4" hole F/6444'-T/6827'. Sweep came back on time w/ a 10% increase in cuttings. Added 2 drum of 776 lube to system to help reduce TQ. Finished strap and tally of 4.5" liner/casing.;P/U-185K S/O-70K ROT-105K GPM-290 SPP-1964 Diff-250 psi WOB-4.7K RPM-80 TQ on BTM-16.5K , TQ off BTM-17.9K ECD-10.48 ppg Max gas 377 units @ 6754' MW-9.4 ppg Vis-56.;Crew change, held PTSM. Cont. directionally drilling 6 3/4" production hole F/6827' to current depth of 7104'. P/U- 202K S/O-76K ROT-109K GPM-290 SPP-1727 Diff-232 psi WOB-5.7K RPM-80 TQ on BTM-17.2K , TQ off BTM-17.9K ECD-10.59 ppg Max gas 559 units @ 7040'.;MW-9.4 ppg Vis-55. Distance to well plan: 23.58' 23.24' High 3.96' Left.;Solids Hauled to G&I 49 bbls Total Solids Hauled to G&I 478 bbls Fluid Hauled to G&I 201 bbls Total Fluid Hauled to G&I 2047 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 0 lbs Cont directionally drilling 6 3/4" hole from 4906' to 5327'. Rot w 2/16/2022 Cont drilling 6 3/4" hole from 7104' to 7366'. Rot wob 4-5K, 289 gpm-1925 psi, 65 rpm-16,500 ft/lbs on bott torque, 20 to 100 ft/hr ROP. MW 9.3+/vis 55, ECD's 10.5 ppg, BGG 28 units, max gas 221 units at 7185'. Made a couple attempts to slide with no luck. Off bottom torque try to stall topdrive.;Cont drilling from 7366' to 7494', our next planned wiper trip depth in the T_50. Rot wob 4K, 290 gpm-1898 psi, 70 rpm-17,500 ft/lbs on bott torque, 117 ft/hr ROP, MW 9.3+/vis 56. ECD's 10.4 ppg, BGG 21 units, max gas 192 units at 7437'. Still can't slide. Received 12 drums Baroid Gold Seal lube.;CBU twice at 290 gpm-1723 psi, 60 rpm-18,600 to 20,925 ft/lbs off bott torque. Added two drums lube during circ to help with wiper trip and topdrive torque. Obtained on bottom survey and SPR's. Up wt 215K, down wt 85K with no pump.;Pulled up hole from 7494' to 7414' on elevators, hole got tight, MU topdrive and pumped up hole to 7368', then pulled on elevators to 6377' with no issues. S/O and parked at 6440'.;CBU one time at 268 gpm-1402 psi, 72 rpm-13,600 to 15,000 ft/lbs off bott torque. Had 20% increase in cuttings at bottoms up then cleaned up. Up wt 195K down wt 76K with no pump.;Serviced rig and topdrive, blew down topdrive and flow checked = static.;RIH on elevators from 6440' to 7434' with no issue. MU topdrive on last stand and filled pipe, washed and reamed to bottom at 7494'.;CBU, pumped tandem 45 bbl sweep around at GPM-290 SPP-1780 psi RPM-65 Off BTM TQ-14,470 ft/lbs Had 460 units gas at bottoms up. Sweep came back on time w/ a 10% increase in cuttings.;Resumed directional drilling 6.75" production hole F/7494'-T/7742'. P/U-207K S/O-78K ROT-115K GPM-280 SPP-2030 psi Diff-330 psi RPM-65 TQ-18.8K WOB-5K Max gas 303 units @ 7536' ECD-10.6 ppg MW-9.35 Vis-56.;Crew change, held PTSM. Cont. directional drilling 6.75" production hole F/7742'-T/7927'. P/U-215K S/O-80K ROT-121K GPM-290 SPP-2296 psi Diff-387 psi RPM-65 TQ-19.4K WOB-8K Max gas 443 units @ 7741' ECD-10.7 ppg MW-9.35 Vis-57.;At 7927' proceeded to rotate and reciprocate pipe due to high TQ (19-21K). Added 1 drum of 776 , 1 drum of Baralube gold seal, and 10 sxs of walnut to suction pit to help reduce TQ. TQ dropped to 16-17K. Made the hook and resumed drilling ahead.;Cont. directional drilling 6.75" production hole F/7927' to current depth of 7989'. P/U-215K S/O-80K ROT-121K GPM-286 SPP-1813 psi Diff-360 psi RPM-70 TQ-17.5K WOB-8K Max gas 252 units @ 7979' ECD-10.51 ppg MW-9.35 Vis-55.;Distance to well plan: 17.15' 9.15' High 14.5' Left.;Solids Hauled to G&I 81 bbls Total Solids Hauled to G&I 559 bbls Fluid Hauled to G&I 249 bbls Total Fluid Hauled to G&I 2296 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 0 lbs 2/17/2022 Cont drilling 6 3/4" hole from 7989' to 8346'. Rot wob 6K, 289 gpm-2011 psi, 75 rpm-17,555 ft/lbs on bott torque, 70 to 100 ft/hr ROP, MW 9.4/vis 53, ECD's at 10.5 ppg, BGG 23 units, max gas 289 units at 8052'. Have 20 bbl LCM pill staged in pill pit in case we see fluid loss, 20 bbls in trip tank;for same. Background LCM at 24 ppb in active system. Have seen no losses yet. Received 4114 gals rig fuel.;Cont drilling 6 3/4" hole from 8346' to TD at 8603' md/7178' tvd. Rot wob 6K, 290 gpm-2238 psi, 65 rpm-19,852 to 21,800 ft/lbs on bott torque, 52 to 105 ft/hr ROP, MW 9.4/vis 61, ECD's at 10.6 ppg, BGG 24 units, max gas 216 units at 8574'. Have seen no losses. Received 4 drums gold seal lube and;Added twp drums of each and 5 sacks nut plug to suction pit which resulted in minimal reduction in on or off bottom torque. Received 34 more centralizers for liner run and tieback hanger/landing joint.;CBU twice at 291 gpm-1918 psi 70 rpm-20,165 ft/bs torque on down stroke, 22,700 ft/lbs on up stroke. Obtained on BTM survey, flow checked well (static) and blew down TDS.;POOH on elevators F/8603'-T/3502' w/ 5-10K drag till 4100'. Worked through multiple tight spots F/5484'-T/4213' w/ 25-35K over pull. Worked though on elevators 2/3 time and cleaned up (Swelling clays, coals, and hole geometry). Had calculated hole fill. P/U140K S/O-99K.;M/U TDS, broke circ. CBUX3, no increase in cuttings at first BU. Blew down TDS. GPM-291 SPP-1500 RPM-80 TQ-7K ECD-10.8 ppg Mw-9.4 Vis-52.;Cont. POOH on elevators F/3502'-T/2333'. Worked through one tight spot @ 3339' on elevators, and cleaned up. Had calculate hole fill for remainder of the trip. P/U-60K S/O-40K.;Cleaned rig floor, Hung the blocks. Slip & cut drill line-cut 19 wraps=90' of line. Serviced rig- greased crown, TDS, blocks, brake linkage, drive shaft, DWKS and IR. Rest set crown-o-matic and recalibrate hook load. Monitored well on the TT, static loss rate= .5 bph.;RIH F/2333' to current depth of 5530' w/ no issue and calculated pipe displacement . filling DP every 2000'. P/U-148K S/O-67K Distance to well plan: 34.71' 16.25' Low 30.68' Right.;Solids Hauled to G&I 25 bbls Total Solids Hauled to G&I 584 bbls Fluid Hauled to G&I 145 bbls Total Fluid Hauled to G&I 2441 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 0 lbs Cont drilling 6 3/4" hole from 7104' to 7366' 2/18/2022 Cont to RIH on elevators from 5530' to 7813', filled pipe at 6033' and 7647'. At 7813' we set down 3 times in mudstone, claystone, carbonaceous shale/coal, transitioning into silty claystone. Could pick up off it ok each time, MU topdrive, filled pipe, increased circ to 288 gpm-2080 psi, 50 rpm-;19,851' ft/lbs off bott torque. Washed and reamed stand down to 7834', stopped rotating, pulled back up through tight spot no issue, shut down pump and S/O to 7834' no issue. Up wt 235K, down wt 75K with pump on. Ran next stand on elevators with no issue to 7897'. Cont RIH and set down at;7967', in sandstone, set down about 25K. Made an attempt to pull back up hole and pulled 30K over to 280k with no movement. MU topdrive and attempted to break circ and rotate. Could not circulate or rotate. Could not move up hole or down. Notified Drilling Engineer.;Start pulling staging up from 280K to 325K firing jars, but initially firing weak. Cont attempting to rotate and circulate at times between jar licks. Started applying pump pressure on upstroke, after cocking jars, parking string at 325K, stop pumping with 1800 to 1900 psi on drill string, and jar.;Tool Push called and discussed with Drilling Superintendent. Given OK to pull to 350K max. Cont to apply pump pressure to 1800 to 1900 psi during up stroke, parking string at 350K and shut down pump to fire jars. Getting good hammering with jars. Jarring for one hour intervals, then;allowing jars to cool for 30 min while inspecting derrick, topdrive and drill line. Called out YellowJacket fishing with tools, notified AK E-Line for potential freepoint run and string shot run. Fishing hand on location at 17:00 hrs. Obtained some parameters for him. Averaging 35 licks an hour;jarring up. Did make several attempts at down jarring with no movement. Cont jarring for one hour intervals at 350K (100K over), cool down and inspect derrick etc for 30 minutes. Discussed ops with Drilling Manager and decision made to call out AK E-Line at 20:00 hrs.;Functioned annular, upper and lower pipe rams and both HCR valves during derrick inspection at 13:30 pm on 2-18-22 with no issues. Cont. w/ jarring operations. Attempted to close grabber box and noticed we had lost robotics to grabber box and TD extend. Ceased jarring operation.;Started trouble shooting robotic issues. Called out rig mechanic and electrician. Found bad wire in 37 pin cable. Switch out w/ 2 spares wires. Functioned and tested robotics (ok). AK E-line showed up on location @ 23:00 hrs.;Crew change., held PTSM. Held PJSM w/ rig crew and AK E-line. Spotted E-line unit. R/U E-line sheaves in derrick and floor. Broke out TD from stump. Ran rope socket and E-line through TD. M/U E- line tools to rope socket (free point tool and CCL). Lowered E-line tools into stump. M/U TD to stump.;RIH w/ E-line. Run #1. Correlated depth from MWD TM HOC up to XO on top of flex collars. OD of E-line tool-1.44". Set free point tool/arms @ 7800'. String weight 250K, P/U 35K over to observe free travel multiple time w/ (no luck). Rest free point tool/arms @ 7696'. String weight 250K, P/U 35K;over to observe free travel multiple time w/ (no luck). Currently resting free point tools inside the jars @ 7560'.;Solids Hauled to G&I 27 bbls Total Solids Hauled to G&I 611 bbls Fluid Hauled to G&I 63 bbls Total Fluid Hauled to G&I 2504 bbls Losses Downhole 0 bbls Total Losses Downhole 0 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 0 lbs 2/19/2022 POOH from 7560', base of jars, could see no movement with free point tool anywhere down hole, e-line operator thinks anchor arms too small. With e-line near surface broke off topdrive, pulled e-line out of DP, swapped anchors, started tool string into DP, MU topdrive. E-line RIH to 4285' and parked.;Worked drillstring from 250K to 285K multiple times as per AK e-line, then they RIH to 4955' and parked. Worked drillstring from 250K to 325K. Freepoint tool still not reading any movement. POOH with e-line and near surface broke off topdrive, pulled e-line out of DP. E-line crew swapped double pin;connector around, recalibrated tool. Lost power on Kalotsa Pad at 10:00 so no comms. Attempted to get productions back up gen re-started with no luck.;Started e-line tool down DP, MU topdrive, e- line RIH to 4500' and parked. Worked drillstring from 250 to 300K numerous times and saw no movement. E-line pulled up hole to 4005' and parked. Worked drillstring from 150 to 300K numerous times, tried rotating string 2 rounds, still no movement of;string detected. E-line pulled up hole to 2200' and parked, worked drillstring from 150 to 250K numerous times, no movement detected. E-line pulled up hole to 600' and parked, worked drillstring from 150 to 250K with 100% movement detected. E-line RIH to 850' and parked, worked drillstring from;150 to 250K, 100% movement detected. E-line RIH to 1000' and parked, worked drillstring from 150 to 250K, no movement detected. E-line pulled up hole to 910' and parked, worked drillstring from 150 to 250K, 40% movement detected. E-line RIH to 950' and 970' with no movement detected at those;depths. Notified Drilling Engineer, decision made to POOH with freepoint, attempt to fire jars, and RIH with string shot if jars fire, indicating movement down to drilling jars. POOH with e-line, near surface broke off topdrive, removed freepoint tool string from DP and tie back out of way.;MU topdrive on drillstring, S/O to 50K to cock jars, pulled up to 300-350K and parked, jars fired, repeated this 2 more times, jars fired each time. R/U tongs to break out single. Blew down TD. L/D top single.;M/U TD to string. Started working left handed TQ down hole as per Yellow Jacket fishing hand. Putting one wrap in at a time while P/U to 150K and S/O to 50K work TQ down hole (Total of 6 left handed wraps). Trapped left handed into string by setting slips and locking the rotary table.;M/U TIW, side entry sub, XO, and XO back to bowen connection on top of string. R/U low TQ valve, chicksan, and 50' high pressure hose off side entry sub. M/U E-line string shot tool-CCL, 4' weight bar, and 5' of primer cord (Total lenth12.05'-OD-1.69") .;Armed E-line tool. RIH w/ string shot. logged and correlated for correct depth. Set string shot @ 7756' (Top of flex collars). Fired shot, lost 50 lbs of E-line wire weight. POOH w/ E-line, confirmed shot fired. R/D -E-line tools. R/D XO's, side entry sub, TIW, chicksan, and low torque on stump.;M/U TD to stump, P/U out of slips w/ grabber box close, slowly let out left handed TQ while P/U to 150K and S/O-50K. Backed out a total of 5 wraps. P/U to 205K and had free travel (lost 50K in string weight), had good conformation of back off. Racked back 1 std. in the derrick.;CBU x2 while performing derrick inspection. Currently blowing down TD. P/U-196K S/O-80K SPM-119 GPM-287 SPP-767 Max gas 962 units MW-9.45 ppg Vis-57.;Solids Hauled to G&I 0 bbls Total Solids Hauled to G&I 611 bbls Fluid Hauled to G&I 0 bbls Total Fluid Hauled to G&I 2504 bbls Losses Downhole 8 bbls Total Losses Downhole 8 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 0 lbs pp p /arms @ 7800'. String weight 250K, P/U 35K over to observe free travel multiplepp time w/ (no luck). Rest free point tool/arms @ 7696'. String w q pp Backed out a total of 5 wraps. P/U to 205K and had free travel (lost pg y 50K in string weight), had good conformation of back off. Racked MU topdrive and attempted to break circ and rotate. Could not circulate or pp p rotate. Could not move up hole or down. pp ;RIH w/ E-line. Run #1. gp y () RIH w/ string shot. logged and correlated for correct depth. Set string shot @ 7756' (Top of flex collars). Fired shot, lost 50 lbs of E-line wire weight. P y M/U E-line string shot tool-CCL, 4' weight bar, and 5' of primer cord ggp Set free point tool/ could see no movement with free point tool anywhere down hole, e-line operator thinks anchor arms too small. 2/20/2022 POOH from 7529’, up wt 195K. Recovered upper 367’ of HWDP, XO and drilling jars (jars backed out of 3 ½” IF box for XO back to HWDP). We have 372.18’ of BHA in the hole, top at +/- 7592’. LD last HWDP single and jars.;Staged fishing tools on catwalk, changed oil in floormotor and transmission, inspected and tightened bolts on torque tube, inspected topdrive/washpipe, functioned blind rams. Staged smaller fishing tools on rig floor, changed to 3 1/2" elevators.;Held PJSM with fishing rep and rig crew. MU 282' fishing BHA as follows: 3 1/2" IF screw in sub, circ control sub with 2500 psi shear disc, bumper sub, oil jar, 8 x 4 3/4" drill collars, intensifier jar, XO CDS-40 box X 3 1/2" IF pin. moved 5 stands HWDP in derrick, start RIH on 4 1/2".;RiH on elevators F/282'-T/2205'. P/U-48K S/O-40K.;Slip & cut 9 wraps=43' of drill line. Static loss rate= .8 bph, circulated pipe volume at 241 gpm-150 psi.;Cont. RIH w/ fishing BHA F/2205'-T/4250'. P/U- 82K S/O-58K.;Circ. hole clean. GPM-290 SPP-750 psi Max gas-46 units.;Resumed RIH w/ fishing BHA F/4250'-T/7532'. Lost 4 bbls during the trip. Running speed 60-70 fpm. P/U-180K S/O-78K.;Circ. hole clean. GPM-267 SPP-696 psi Max gas-129 units. M/U last std. washed down GPM-206 SPP-442 psi, tagged TOF @ 7592' SPP-206 SPP-752psi. Cont. circ. and cleaning of TOF. Spotted 3 drums of lube on the back side up to 3000'. Shut down MP.;Crew change, held PTSM and weekly safety meeting w/ rig crew. Blew down TD, P/U & M/U working single off the walk. Got parameter for engaging fish. P/U-185K S/O-85K ROT- 116K RPM-25 TQ-16-17K. Eased down and screwed into fish applying 11K TQ to string while working it down hole. P/U to;150K and S/O-75K working TQ to screw in sub (3.5" IF connection).;Stated jarring operations- S/O to 75K to cock the jars, P/U to 275K parking string, firing jars, over pulling from 300K and working up to max over at 350K. Repeating same. Every so often we are applying pump pressure 700-1500 psi to drill string for HYD jar assist.;Shouting down every hour to let jars cool and performing derrick inspection and fill back side of the hole. Static loss rate=.8 bph. Cont. with jarring operations at report time.;Solids Hauled to G&I 0 bbls Total Solids Hauled to G&I 611 bbls Fluid Hauled to G&I 0 bbls Total Fluid Hauled to G&I 2504 bbls Losses Downhole 4 bbls Total Losses Downhole 12 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 2 lbs Total Medal 2 lbs 2/21/2022 Cont to jar on fish for 1 hour intervals, working pipe from 75K to cock jars, apply 1200 psi pump pressure and straight pull to 285K, park string, fire jars, straight pull to 350K. After 1 hour jarring inspected derrick, drill line and topdrive. Held conference call with Engineers on forward plan.;Cont jarring one hour, then cocked jars, straight pull to 350K and allow to sit one hour with 1204 psi on DP, pressure bled to 1167 psi over one hour. Inspected derrick and topdrive.;Broke off single and with topdrive MU, rolled pump to circ through standpipe, Kelly hose and topdrive to ensure nothing freezing, MU single and topdrive. Jarred one hour, applied 1075 psi to drill string, fired jars at 285K, pulled and parked at 350K leaving pressure on DP for an hour. Bled to 1048;Cont jarring working pipe from 75K to 285K, fire jars, pull to 350K. No pipe movement. Notified at 15:30 by Drilling Engineer to stop jarring, back off fishing BHA from fish and POOH for cleanout run.;Inspect topdrive and blow down same. MU on string. Applied 5 rounds left hand torque to drill string (stalled) and work down hole 5 times from 120K to 85K, then 150K to 85K. Released grabber on topdrive and string rotated left a couple more rounds on it's own. PU slow and string is free, up wt 190K,;previous up wt was 190K prior to engaging fish. Down wt 87K. Brought on pump at 209 gpm-583 psi, S/O slow and as we tagged up psi rose to 2400 psi indicating bumper sub closing. Shut down pump.;LD top single, rack one stand back, MU topdrive, CBU at 290 gpm-775 psi, fair amount of fine sand at bottoms up, max gas at bottoms up 224 units.;POOH F/7532' to fishing BHA at 282', still had cut lip screw in sub on bottom. L/D fishing BHA- XO, intensifier jars, 8 DC, oil jars, bumper sub, circ. control joint, and screw in sub. Had calculated hole fill for the trip.;Cleaned & cleared rig floor. L/D Yellow Jacket fishing handline equip.;Crew change, held PTSM. Removed fishing tools & equip. of catwalk. Staged BHA #4- cleanout assy. on the catwalk. Racked and tally BHA #4.;P/U & M/U cleanout assy. BHA #4- 6.75" Tricone bit, bit sub, stab, 2 jts HWDP, jars, and 11 jts. of HWDP (442').;RIH on elevators filling pipe every 2000'. F/442' to current depth of 4035'. Had 2 15-20K set downs @ 3268' and 3780', P/U and went right through on elevators. P/U-80K S/O-50K.;Solids Hauled to G&I 0 bbls Total Solids Hauled to G&I 611 bbls Fluid Hauled to G&I 0 bbls Total Fluid Hauled to G&I 2504 bbls Losses Downhole 6 bbls Total Losses Downhole 18 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 2 lbs 2/22/2022 Cont TIH with dumbiron cleanout assembly from 4035' to 7574', filling pipe every 2000'. Up wt 185K, down wt 83K no pump. MU topdrive and filled pipe.;CBU one time at 290 gpm-866 psi, 35 rpm-15,600 to 18,600 ft/lbs off bottom torque. Worked down to 7580' staying 10' off top of fish (TOF at 7590'). Max gas at bottoms up 189 units. Pumped a 20 bbl hi-vis nut plug sweep around at 290 gpm-928 psi. sweep back 230 strokes late. 75% increase in cuttings.;Record new Slow Pump Rates @ 7580' W/ 9.4 ppg MW= MP1: 47 spm with 269 psi., MP2: 46 spm with 271 psi. Monitor Well with weeping losses of 1/2 bph, pump dry job and blow down Top Drive.;POOH laying down 4-1/2" CDS40 drill pipe F/ 7580' T/ 7538'. PUW=190K, SOW=80K.;Crew Change, Continue POOH with clean out assembly F/ 7538' T/ 2552'' while monitoring proper hole fill from trip tank.;RIH w/ remaining std. out of derrick F/2552'-T/3358'. P/U-57K S/O-43K.;POOH L/D 4.5" DP singles F/3358'-T/2427'. Cont. vacuuming wiper balls through pipe, cleaning & re-doping threads, and installing thread protectors on tight. P/U-65K S/O- 40K.;Dropped metal drift on wire. POOH racking 32 stds. in derrick F/2427'-T/474'. Gave WOTCO 3 hr. notice.;L/D cleanout BHA- HWDP, jars, stab, bit sub, and 6.75" bit (bit in gauge). Had calculated hole fill for the entire trip.;Cleaned & cleared rig floor. R/D DP handling equip. R/U WOTCO handling equip. Emptied out pits 9 & 10 to take back cmt displacement. Cleaned PP & TT for black water.;Crew change, held PTSM. Cont. R/U to run 4.5" liner.;Serviced rig while loading 4.5" DWC/C HT 12.6 ppf L-80 liner on the racks. Greased crown, blocks, TD, DWKS, drive shaft, brake linkage, and IR.;Held PJSM w/ rig crew, WOTCO, and DSM. Flash lighted, BakerLok threads, and M/U shoe track. Tested floats (ok). Tested drive sub. Cont. running 4.5" DWC/C HT 12.6 ppf L-80 liner as per run tally F/211'-T/2260'. P/U-35K S/O-30K.;M/U drive sub XO to liner. Screwed in TD, broke circ. Staged up pump. Currently CBUx2. GPM-175 SPP- 44 psi.;Solids Hauled to G&I 0 bbls Total Solids Hauled to G&I 611 bbls Fluid Hauled to G&I 360 bbls Total Fluid Hauled to G&I 2864 bbls Losses Downhole 0 bbls Total Losses Downhole 18 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 2 lbs Recovered upper 367’ of HWDP, XO and drilling jars (jars backed out of 3 ½” IF box for XO back to HWDP). We have 372.18’ of p BHA in the hole, top at +/- 7592’ 2/23/2022 RIH with 4-1/2", 12.6#, L-80 DWC-C-HT Production Liner F/ 2260' T/ 4160' PUW 55K, SOW 35K. Submit BOPE Test for By-Weekly Test with AOGCC @ 05:45am. Finished build 250 batch of 6% KCL brine in pit 9&10.;Make up Floor Valve and crossover, CBU @ 208 GPM with SPP of 165psi. max gas observed at bottoms up 34 units.;RIH with 4-1/2", 12.6#, L-80 DWC-C-HT Production Liner F/ 4160' T/ 5495' PUW 87K, SOW 50K. Calculated displacement= 28.5 BBLS, Actual Displacement= 24.3 BBLS, 4.2 BBLS difference. Confirm 82 joints of 4-1/2" Production Liner on pipe racks outside. Transfer 90 BBLs from Pits 4,5 & 6 to vac truck;for disposal. Receive AOGCC notice of waived witness from Jim Regg at 09:47am.;Make up Flex-Lock V Liner Hanger, HRD-E ZXP 5-1/2" X 7- 5/8" Liner Top Packer Assembly as per Baker Representative. DSM confirm 5 shear pins in Hanger and 7 shear screws in Liner Top Packer.;Circulate Bottoms up on first stand of drill pipe at 5609' staging pump up to 168 GPM with SPP at 250 psi. MW in at 9.6ppg with Vis at 53, MW out at 9.6ppg with Vis at 63. Blow down Top Drive and continue RIH.;Continue RIH with Liner Assembly by running stands of Drill Pipe in derrick F/ 5495' T/ 7439'. set down 10K at 7439'. PUW 135K SOW 65K. calculated displacement on trip.;Wash down liner F/ 7439' T/ 7566'. 114 GPM with 275 psi. Make up cement head.;Circulate and Condition mud for cement job. Stage pumps up to 5 BPM with 450 psi. MW in 9.6ppg VIS 54, MW out 9.6ppg VIS 54, max gas at bottoms up 124 units. PJSM with personnel involved with cement job.;Halliburton pumped 5 bbls to fill lines. Shut in at Baker cement head and PT lines at 613 psi low 5006 psi high. Good tests. Lined up Baker cement head to Halliburton, pumped 30 bbls 10.5 ppg Tuned Prime Spacer at 5 bpm-570 psi, followed with 182 bbls (423 sx) 12 ppg Type I/II Lead;cement at 5 bpm, 490 to 160 psi, followed with 19 bbls (95 sx) 15.3 ppg Type I/II Tail cement at 2 bpm, 276 psi. Had 2 pps of Bridge Maker LCM in lead, none in tail. Baker released dart, Halliburton then displaced with 10 bbls water followed with 9.65 ppg 6% KCL mud at 5 bpm-500 psi ICP.;Saw dart latch wiper plug 26.8 bbls into displacement. With 12 bbls to go, reduced rate to 3 bpm-1350 psi, set on depth. Bumped wiper plug/landing collar 108.5 bbls into displacement (calculated at 110 bbls). FCP 2040 psi. Held pressure for 3 min. bled back .75 bbls to truck. Floats;held. CIP at 20:13 hrs on 2-23-22. Lost 0 bbls during cement job. Got 30 bbls of spacer back and a trace of cement to surface after un-stinging running tool and CBU.;Brought pressure up to 2544 to set hanger, held for 2 min. Slacked of from 65K to block weight-15K. Confirmed hanger set. Brought pressure up to 2820 psi and held for 2 min. Visually seen packer setting tool shift. Brought pressure to 4577 psi and held for 2 min. Bled off pressure.;P/U 1' and seen free travel (50K string weight). R/D & L/D Baker cmt head. M/U TD to stump. Applied 697 psi to drill string. P/U 11' and seen pressure dump. Brought both pumps on line, CBUx2 GPM-500 SPP-550 psi. Seen 30 bbls of spacer and a trace of cmt at surface.;L/D single. Washed up and broke down cmt lines on rig floor. Pumped wiper ball around and CBUx2 GPM-500 SPP- 490 psi.;Flow checked well (static). Blew down TD. POOH F/1982'-T/surface. Had calculated hole fill for the trip. Inspected & L/D hanger running tool. HES cmt's cont. rinsing up unit. Started hauling off mud from pits 1-6.;B/O XO's and 5' pup off Baker cmt head. Johnny whacked the stack and pump across mud cross w/ black water. Blew down choke and kill lines.;Crew change. Held PTSM. Blew TD and mud lines. Pumped out remaining black water from TT. Cleaned and organized rig floor. Staged polish mill assy. on catwalk. HES cmt finished rinsing up pump unit. Cont. hauling off mud from pits.;M/U polish mill assy. as per Baker Rep. RIH F/21.80'-T/2031.9'. Seen polish mill enter SBR w/ 80 psi increase, Tagged w/ 5K set down, cont. to polishing w/ GPM-140 RPM-20 SPP-55 psi TQ off BTM-3.2K TQ on BTM-4.2K P/U-39K S/O-39K ROT-42K.;CBU @ 2026' GPM-210 SPP-20 psi. Flow checked well (static). Blew down TD.;POOH racking back in the derrick F/2026'-T/21.80'. Seen good compression marks on bottom of dressing mill. L/D Baker polishing mill assy.;Performed rig service- Greased & inspected DWKS, TD, crown, blocks, drive shaft & linkage, and IR. Charged TD compensator.;Drained stack, vac'd out cellar. B/O lock downs and pulled 9" wear ring. Change out test plug seal and installed test plug. Currently R/U testing equip.;Solids Hauled to G&I 0 bbls Total Solids Hauled to G&I 611 bbls Fluid Hauled to G&I 620 bbls 2/24/2022 Flood BOPE stack and all test equipment. Obtain good shell test after purging all air from system.;Bi-Weekly BOPE Test with 2-7/8" and 4-1/2" Test Joints. Annular Test 250/ 2500 psi low and high. All other components tested to 250/ 3500 psi low and high. All tests charted and held for 5 minutes each. Accumulator Drawdown results: Before Closure- Accumulator Pressure= 3050, Manifold Pressure= 1575;, Annular Pressure=1200, After Closure- Accumulator Pressure= 1700, Manifold Pressure= 1525, Annular Pressure= 1200. Closure Times: Annular=18 seconds, UPR= 4 seconds, Blinds= 4 seconds (Simulated by opening UPR), LPR= 4 seconds, Choke/ Kill HCRs= 1.5 seconds each.;Nitrogen avg.= 2500, Recharge Time: +200psi=24 seconds, Full Recovery= 90 seconds.;Rig Down test equipment and pull test plug. Install 9" ID Wear Ring, Blow Down Choke and Top Drive.;Load pipe racks and tally 2-7/8" PH6 , Rig up 2-7/8" handling equipment. redress air slips to 2-7/8". Bring BHA to floor, strap and tally BHA.;Make up 3.75" Bit, 4-1/2" Scraper, Float sub and crossover to first joint of PH6 and RIH F/ Surface and set down 5K at 2060'. Made up top drive and rotated through with no problems. Continue RIH with 2-7/8" F/2060"-T/ 2430'.;Cont. RIH w/ 2- 7/8" PH-6 work string F/2430'-T/5357'. M/U XO's and 7-5/8" scraper, XO to 4.5" DP. P/U-70K S/O-35K.;RIH w/ 4.5" DP F/5357'-T/7310'. Had calculated pipe displacement for the trip. P/U-105K S/O-54K.;Filled pipe and washed down at an idle GPM-115 SPP-1014 psi F/7310'. Tagged up on cmt @ 7318'. Top of LC @ 7354'. Staged up pump GPM-170 SPP-1910 psi, attempted to wash down w/ 4K (no luck). CBU.;CBU while holding PJSM on displacement. Pumped 20 bbls Hi-Vis spacer, followed by 8.6 ppg 6% KCL brine. GPM-205 SPP-2500 psi.;Crew change, held PTSM. Finished displacing well over to 6% KCL brine. Obtained new SPR's. Performed 15 min flow check ( Static.).;POOH L/D 4.5" CDS-40 DP F/7318'T/5348'. Vacuuming wiper balls through pipe on the racks, cleaning & re- doping threads and install thread protectors on tight.;Inspected and L/D 7-5/8" scraper and XO's. R/U WOTCO 2-7/8" work string handling equip. P/U-115K S/O- 52K. Organized rig floor and change out handling equip. for L/D 2-7/8" work string.;POOH L/D 2-7/8" work string F/5348' to current depth of 3554'. Cont. to vacuum wiper balls through pipe on the catwalk racks, cleaning & re-doping threads and install thread protectors on tight.;Solids Hauled to G&I 0 bbls Total Solids Hauled to G&I 611 bbls Fluid Hauled to G&I 270 bbls Total Fluid Hauled to G&I 3754 bbls Losses Downhole 0 bbls Total Losses Downhole 22 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 2 lbs Lost 0 bblspp during cement job. Got 30 bbls of spacer back and a trace of cement to surface after un-stinging running tool and CBU. ;Saw dart latch wiper p ppg p p plug 26.8 bbls into displacement. With 12 bbls to go, reduced rate to 3 bpm-1350 psi, set on depth. Bumped wiper plug/landing collar 108.5 bbls intopg p displacement (calculated at 110 bbls). p( ) pjpp ppg Lined up Baker cement head to Halliburton, pumped 30 bbls 10.5 ppg Tuned Prime Spacer at 5 bpm-570 psi, followed with 182 bbls r (423 sx) 12 ppg Type I/II pppppgppp Lead;cement at 5 bpm, 490 to 160 psi, followed with 19 bbls (95 sx) 15.3 ppg Type I/II Tail cement at 2 bpm, 276 psi. Floats;held. pp No mention of red dye in last 10 bbls cement per condition on sundry 322-084. See email from Sean McLaughlin dated 12/8/22 -bjm RIH with 4-1/2", 12.6#, L-80 DWC-C-HT Production Liner 2/25/2022 Continue Laying down 2-7/8" PH6 F/ 3554' and 4-1/2" scraper assembly.;Clean and clear rig floor. Pull stripping rubbers, Pick up test joint and Pull Wear Ring.;Test 4-1/2" Liner and 7-5/8" casing to 3000 psi for 30 charted minutes. ( Good Test) 92.4 gallons pumped and bled back.;PJSM, Pick up and make up 4- 1/2" 12.6# L-80 DWC-C-HT Tie-Back assembly as per approved tally. RIH and locate PBR at 2031' Lower in hole and place seal assembly on No-Go at 2042'. Space out with 2 pup joints and hanger. Make up and land Tie-Back string at 2040.60', 1.86' off of No-Go. PUW 35K SOW 33K;RILDS on Hanger and rig up equipment for testing.;Test tubing T/ 3000 psi. for 30 charted minutes with the Annulus valve open and being monitored. Good Test with 53 gallons pumped and bled back. Test 7-5/8" x 4-1/2" Annulus T/ 2500 psi. for 30 charted minutes with the tubing open to atmosphere. Good Test with 26.5 gallons pumped and bled back.;WHR set 2 way check on T-bar. Flushed through TD, kill & choke lines, and mud lines w/ Barakleen pill and blew down same. De-energized koomey. Opened ram doors and inspected cavities (ok). Cont. hauling off fluid from pits and cleaning tank bottoms.;N/D BOP's- R/D flow line, catch can, flow nipple, chains, fill up hose, and bell nipple from stack. R/D kill & choke lines, and koomey hoses. Un-bolted stack flange to well head. Used bridge cranes to move stack into position to be picked with CCI crane.;Brought in dry hole tree to cellar, and prepped tree and well head. Installed tree on well head and tightened flange.;Crew change, held PTSM. Finished N/U tree, WHR tested void 500 psi Low 5 min -5000 psi High 15 min (ok). Tested dry hole tree 500 psi Low 5 min- 5000 psi High 15 min (ok). Installed shipping beams. Cleaned up equip. & tools in sub. Winterized test pump. Installed blind flanges on kill & choke lines.;R/D , inspected and greased MP's. Power washed mast, TD, floor equip and sub. Finished cleaning pits, vacuumed out hopper house manifolds and drained snail shells on centrifugal pumps. CCI cont. loading out mud product, de-watering pad, and loading out misc. equip. onto trailers.;R/D jumper hoses between pit module 1 and MP 1 skid, equalizer lines between pits modules, and suction lines on MP's. Opened and cleaned degasser. Installed shipping blocks on centrifuge and R/D hoses. Cont. working on R/D and prepping for rig move to Whiskey Gulch pad.;Final report for Kalotsa 8. Moving to Whiskey Gulch 14 AFE as of 06:00 hrs.;Solids Hauled to G&I 0 bbls Total Solids Hauled to G&I 611 bbls Fluid Hauled to G&I 510 bbls Total Fluid Hauled to G&I 4264 bbls Losses Downhole 0 bbls Total Losses Downhole 22 bbls Cement hauled to G&I 0 bbls Total Cement Hauled to G&I 93 bbls Daily Metal 0 lbs Total Medal 2 lbs g ;Test tubing T/ 3000 psi. foggp pg Test 7-5/8" x 4-1/2" Annulus T/ 2500 psi. for 30 charted minutes with the tubing open to atmosphere. Good Test w gp yg p y ;Test 4-1/2" Liner and 7-5/8" casing to 3000 psi for 30 charted minutes. ( Good Test) Activity Date Ops Summary 3/1/2022 13:00 ARRIVE AT KALOSTA FROM PAX 11. SPOT EQUIPMENT WHILE WELLHEAD IN COMPLETED. 13:15 PJSM, SIGN PERMIT. 13:30 MAKE UP TOOLS, OP CHECK. 15:30 CONTINUE ELINE RIG UP. STAB ON. DEAD WELL.,16:20 RIH W/ HEAD (6X2) / CCL / CENT / 2.75" CBL / CENT / GR CENT, OAL = 24', OAW = 340 LB, MAX OD = 3.13" (CCL). SITTING DOWN AT 30'. (CCL ZERO AT GL + 18' KB HEIGHT). 16:40 UNSTAB. ADJUST CENTRALIZER OD'S TO MINUMUM. (3.8" CLOSED, 4.7" OPEN). 17:20 TRY RIH AGAIN. SAT DOWN AT 30'. HARD SIT DOWN. UNABLE TO WORK TOOLSTRING THROUGH.,17:30 UNSTAB, RECONFIGURE TOOLSTRING TO SLIM. 17:50 RIH W/ HEAD (6X2) / CCL / WEGHT X 2 / BNS, OAL = 15', OAW = 175 LB, MAX OD = 2-1/8" (CCL). FALL WITH NO ISSUES TO 2500' POOH. 18:20 AT SURFACE. STANDBY FOR JUNKBASKET TO AOL. 19:00 RIH W/ HEAD (6X2) / CCL / WEIGHT X 2 / JUNKBASKET WITH 3.75" GR, OAL = 21.5', OAW = 220 LB, MAX OD = 3.75" (GR). RUN THROUGH TREE THREE TIMES TO 200' AND BACK.,19:30 AT SURFACE. CEMENT PIECES AND THICK TREE GREASE IN JB. MAKE UP CBL AGAIN. 19:41 RIH W/ HEAD (6X2) / CCL / CENT / 2.75" CBL / CENT / GR CENT, OAL = 24', OAW = 340 LB, MAX OD = 3.13" (CCL). SITTING DOWN AT 30'. (CCL ZERO AT GL + 18' KB HEIGHT). 19:50 AT SURFACE. LAY DOWN FOR THE NIGHT. 20:45 RIG DOWN COMPLETE. WELL SECURE. CREW DEPART FROM LOCATION. ***JOB IN PROGRESS*** 3/2/2022 AK E-line arrive on location. Warm up equipment. Conduct JSA and approve PTW. MU 1-11/16" CBL, 1-11/16" GR/CCL and 2.75" centralizers set up for 4-1/2" tubing.,Open well and RIH. No indication of collars while RIH. POOH. Change out panel and wait for backup GR/CCL to come from shop. Change out GR/CCL and RIH. Still no good indication of collars. Gamma Ray is good and CBL data good. Continue to RIH.,Good indication of collars at Liner. Tie into Liner hanger depth from tubing tally. RIH and tag at 7292'. Log up 200' and repeat pass.,Log up from tag depth at 7292' (uncorrected) at 60 fpm to 1900'.,POOH and laydown toolstring. RDMO. 3/3/2022 Fox coil arrive on location. Conduct JSA and approve PTW. Spot equipment. RU treating and return lines to choke skid and tank. NU Flowcross and BOPs on tree.,Function test BOP rams. Test Full body, blind/shear rams, pipe/slip rams, choke skid valves, to 250 psi low / 3500 psi high. Jim Regg with AOGCC waived witness on 3/1/22 at 11:56.,MU 1.75" stinger, 1.75" DFCV's, 1.75" downjet nozzle. PT lubricator to 250/3500 psi. Open well and RIH. Start pumping N2 at 1000 scfm at 2000' ctmd Tag at 7339' (m), 7327' (e). Pick up 10' and stay on bottom for 10 minutes pumping N2.,POOH pumping N2 at 1000 scfm. Getting N2 and fluid back to return tank. Shut in choke once all returns turn to N2. Recover total of 109 bbls. Trap 1600 psi on well. Shut in swab.,Laydown coil BHA and lubricator. Set injector on back deck. SDFN. 3/4/2022 AKEL move equipment from Paxton 5 to Kalotsa 8. PJSM and fill-out permit. Rigup equipment. Bleed WHP from 1600 psi to 1300 psi. Check fire. Confirmed AOGCC approved CBL prior to perforating. Rewire firing head. Stab on with 20' of 2-7/8" 6 spf, 60 deg phasing gun. 8' from CCL to top shot. PT lubricator 250 psi / 2600 psi. Good test. RIH. Pull correlation log from 7200' to 6750'. Send to town, approved.,Shoot the T37 from 7008' to 7028'. Good indication of fire. Pressure data: Initial - 1348 psi, 5 min - 1385 psi, 10 min - 1415 psi, 15 min - 1455 psi. POOH. Lay down guns, all shots fired, gun was slightly damp. Check fire. MU 10' gun. CCL to top shot 12'. Stab on and RIH. Pull correlation log from 7200' to 6850'. Send to town, approved. Shoot the T37 from 7028' to 7038'. Good indication of fire. POOH.,Pressure data after 10' gun: Initial - 1942 psi, 5 min - 1944 psi, 10 min - 1945 psi, 15 min - 1946 psi. Lay down guns, all shots fired, gun was slightly damp. Tree cap is on and PT. RDMO. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NINU Kalotsa 8 Ninilchik Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00022 Kalotsa 8 Completion Spud Date: pgpgg ,Shoot the T37 from 7008' to 7028'. 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678 < 678 435*. 6 8 45* 6 8  ,- 6 8 ,- 6 8   0 68  30 68 -   68  675=8  ,)  8$+&99 3&8+ 893&$+ ' +3&9% $ +99&92 !2 %22&+(' 392&+% 2 289 8'&(( 2(3 8+8&88 (&3$ 8 $$8&(8 8@0/<=$// 6)2,  8$&8$ 3&'+ 89+&(% ' +9&3' $ +'8&'$ !2 %28&$'' $%&$' 2 289 83'&$( 2(3 8+8&23 (&'2 8 $$&%% 8@0/<=$// 6)2,  %%%&8' &$ (&$% 3 (2$&2$ $ +32&82 !2 %28&22' 3'&'$ 2 289 8%&$ 2(3 8+8&%2 (&$ 8 $2%&( 8@0/<=$// 6)2,  9(&$ &$% $&$8 3 (%&8 $ +$&8 !2 %28&$2' +8+&3 2 289 8+8&' 2(3 8+8&38 (&28 8 $2+&2 8@0/<=$// 6)2,  9'3&(% &(+ 8&$9 3 $%2&'' $ ++&' !2 %22&$' ++&(' 2 289 %(2&$9 2(3 8+%&2% (&%+ 8 $8%&+2 8@0/<=$// 6)2,  '(8&(( &(+ 8&$9 3 $3&2' $ ++%&38 !2 %22&983 (88&'' 2 289 %(3&$+ 2(3 8+%&'% (&(( 8 $83&+' 1-C*.*. 7"A 7"A  A    Benjamin Hand Digitally signed by Benjamin Hand Date: 2022.03.01 12:29:11 -09'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2022.03.02 10:05:06 -09'00' TD Shoe Depth: PBTD: Jts. 2 56 Yes X No X Yes No Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes X 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?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: l ll 345 2.4 l ll 210 1.16 5.2 21.39 Hanger 16 CDC Cactus 1.09 23.59 20.30 2,207.35 23.59 Pup Joint 7 5/8 29.7 L-80 CDC USS 2.20 23.59 1.38 2,208.73 2,207.35 Casing 7 5/8 29.7 L-80 CDC USS 2,183.76 Float Collar 8 5/8 BTC Innovex Every Other Joint Up To 297' Casing 7 5/8 29.7 L-80 CDC USS 77.32 2,286.05 2,208.73 www.wellez.net WellEz Information Management LLC ver_04818br 4.2 Type of Shoe:Innovex Bullnose Casing Crew:Weatherford 12 150 2,287.552,295.00 CEMENTING REPORT Csg Wt. On Slips: Spud Mud 22:35 2/9/2022 Surface 15.8 46 Bump press Visual Bump Plug? 101/101.3 1060 97 Halliburton FI R S T S T A G E 10.5Tuned 37 9.4 5.7 100 500 Csg Wt. On Hook:73,397 Type Float Collar:Innovex No. Hrs to Run:4 BTC Innovex 1.50 2,287.55 2,286.05 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.NINU Kalotsa 8 Date Run 9-Feb-22 CASING RECORD County State Alaska Supv.R Pederson / J Riley 2,207.35 Floats Held Spud Mud Rotate Csg Recip Csg Ft. Min. PPG9.4 Shoe @ 2287.55 FC @ Top of Liner Casing (Or Liner) Detail Shoe 8 5/8 TD Shoe Depth: PBTD: Jts. 1 4 128 Yes X No Yes X No 40 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?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Type I II 423 2.39 Type I II 95 1.24 5 2,065.56 2,031.09 4.72 2,070.28 2,065.56 Hanger 6 5/8 DWC/C HT Baker ZXP 34.47 Pup 4 1/2 12.6 L-80 DWC/C HT Vam 7,354.77 Liner 4 1/2 12.6 L-80 DWC/C HT Vam 5,284.49 7,354.77 2,070.28 7,521.52 7,355.98 Landing collar 5 BTC Baker 1.21 7,355.98 1.30 7,522.82 7,521.52 Liner 4 1/2 12.6 L-80 DWC/C HT Vam 165.54 Float collar 5 BTC Innovex Run 132 centralizers. Liner 4 1/2 12.6 L-80 DWC/C HT Vam 41.39 7,564.21 7,522.82 Baker Flex Lock V liner hanger www.wellez.net WellEz Information Management LLC ver_04818br 2 Type of Shoe:Innovex Casing Crew:WOTCO 12 182 7,565.957,592.00 7,354.77 CEMENTING REPORT Csg Wt. On Slips:85,000 6% KCL PHPA 20:13 2/23/2022 2,103' 15.3 19 Bump press CBL Bump Plug? 108.5/110 2040 Trace Halliburton FI R S T S T A G E 10.5Tuned 30 9.65 5 100 1350 Csg Wt. On Hook:100,000 Type Float Collar:Innovex No. Hrs to Run:16.5 BTC Innovex 1.74 7,565.95 7,564.21 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.NINU Kalotsa 8 Date Run 23-Feb-22 CASING RECORD County State Alaska Supv.J Murphy / J Richardson Floats Held 6% KCL PHPA Rotate Csg Recip Csg Ft. Min. PPG9.65 Shoe @ 7565.95 FC @ Top of Liner 2031.09 Casing (Or Liner) Detail shoe 5 1 Guhl, Meredith D (OGC) From:Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Sent:Thursday, December 8, 2022 2:33 PM To:McLellan, Bryan J (OGC) Cc:Frank Roach Subject:RE: [EXTERNAL] Kalotsa 8 (PTD 222-003) Sundry 322-084 - Radioactive source Bryan,    Frank will get you the NRC report.    The documentation of adding red dye was missed.  I recall speaking to the Forman about it prior to the job and asking it  to be added to the morning report afterwards.  However, I never followed up on that request.  The Foreman remembers  the red dye discussion but not much else.  To much time has elapsed for his memory to be good.  The cement Supervisor  remembers taking a sample of the tail (with red dye) and handing it to the Foreman.  He also remembered putting the  red dye on the subsequent ticket.  There were two bottles of dye charged to Whiskey Gulch 14.  One for the surface  spacer and the one used on the Kalotsa 8 liner tail.  The addition of dye was not documented on any report.  The people  involved have a poor memory given the time that has elapsed.  Two bottles of dye charged on the next well is all the  information we have.    Regards,  sean    From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>   Sent: Tuesday, December 6, 2022 11:41 AM  To: Frank Roach <Frank.Roach@hilcorp.com>; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>  Subject: [EXTERNAL] Kalotsa 8 (PTD 222‐003) Sundry 322‐084 ‐ Radioactive source      Frank, Sean,  This is the well where the radioactive source was left downhole.  I’m copying you both since I think it was Frank’s well,  but Sean was covering for vacation during part of the operation.    Sundry 322‐084 had several conditions of approval related to the radioactive source being left in the well.  I couldn’t find  any mention of how these were addressed in the 10‐407.       I can’t find a record of the final report sent to the NRC for Notification of incidents and lost sources”.   I have  some email correspondence between Hilcorp and Halliburton, stating that verbal approval for leaving the source  in hole was obtained from the NRC, but no final report that I could find.  If there was a final report, could you  send it over so I can attach to the 10‐407.   The cement job summary in the 10‐407 did not mention anything about red dye being added to the last 10 bbls  of tail cement.  Do you have a more detailed cement report that indicates whether the red dye was added or  not?     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 Regards    Bryan McLellan  Senior Petroleum Engineer  Alaska Oil & Gas Conservation Commission  333 W 7th Ave  Anchorage, AK 99501  Bryan.mclellan@alaska.gov  +1 (907) 250‐9193      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.     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: 3/03/2022 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL KALOTSA 8 - PTD 222-003 - API 50-133-20705-00-00 FINAL LWD FORMATION EVALUATION LOGS (02/07/2022 to 02/21/2022) ROP, DGR, GM, ADR, ALD, CTN (2” & 5” MD/TVD Color Logs) Final Definitive Directional Survey Folder Contents: Please include current contact information if different from above. 222-003 T36384 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.03 14:03:39 -09'00' 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: 03/03/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KALOTSA 8 - PTD 222-003 - API 50-133-20705-00-00 MUDLOGS - EOW DRILLING REPORTS (02/07/2022 to 02/17/2022) 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) Formation Log LWD Combo Log Gas Ratio Log Drilling Dynamics Log SFTP Transfer - Data Folders: Please include current contact information if different from above. 222-003 T36384 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.03 13:36:48 -09'00'  5HJJ-DPHV% 2*& )URP-D\0XUSK\ & -D\0XUSK\#KLOFRUSFRP! 6HQW0RQGD\)HEUXDU\30 7R5HJJ-DPHV% 2*& '2$$2*&&3UXGKRH%D\%URRNV3KRHEH/ 2*& :DOODFH&KULV' 2*& 6XEMHFW5(>(;7(51$/@5(+LOFRUS1,18.DORWVD0,7 V :ŝŵ͕ tŝƚŚƚŚĞĐŽŶƐŝƐƚĞŶĐLJŽĨƚŚĞƉƌĞƐƐƵƌĞůŽƐƐĂŶĚƚŚĞƚŝŵŝŶŐŐŝǀŝŶŐƵƐĂ͘ϬϭϲϱƉĞƌĐĞŶƚĂŐĞŽĨůŽƐƐŽǀĞƌĂůů/ƐƚŽƉƉĞĚĂŶĚ ĂƉƉƌŽǀĞĚƚŚĞƚĞƐƚ͘tŚĞŶ/ƌƵŶŝŶƚŽƚŚŝƐŬŝŶĚŽĨƐĐĞŶĂƌŝŽŵŽǀŝŶŐĨŽƌǁĂƌĚ͕/ǁŝůůĞdžƚĞŶĚƚŚĞƚĞƐƚ͘ :ĂLJ &ƌŽŵ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗DŽŶĚĂLJ͕&ĞďƌƵĂƌLJϮϴ͕ϮϬϮϮϭϭ͗ϯϲD dŽ͗:ĂLJDƵƌƉŚLJͲ;Ϳф:ĂLJ͘DƵƌƉŚLJΛŚŝůĐŽƌƉ͘ĐŽŵх͖ĚŽĂĂŽŐĐĐƉƌƵĚŚŽĞďĂLJфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂLJΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх͖tĂůůĂĐĞ͕ŚƌŝƐ;K'ͿфĐŚƌŝƐ͘ǁĂůůĂĐĞΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗΀ydZE>΁Z͗,ŝůĐŽƌƉϭϲϵͬE/Ehͬ<ĂůŽƚƐĂϴD/dΖƐ ZĞŐĂƌĚŝŶŐƚŚĞĐĂƐŝŶŐƚĞƐƚ͕ϮϬϮϱ͘ϬϯϬ;ĞͿƌĞƋƵŝƌĞƐƐƚĂďŝůŝnjŝŶŐƉƌĞƐƐƵƌĞŝŶĂĚĚŝƚŝŽŶƚŽŶŽƚŵŽƌĞƚŚĂŶϭϬйƚŽƚĂůƉƌĞƐƐƵƌĞ ůŽƐƐ͘dĞƐƚƌĞƉŽƌƚŝŶĚŝĐĂƚĞƐϮϱƉƐŝƉƌĞƐƐƵƌĞĚƌŽƉĚƵƌŝŶŐĞĂĐŚϭϱŵŝŶƵƚĞƚĞƐƚƉĞƌŝŽĚ͘tŚĂƚŝƐƚŚĞƌĞĂƐŽŶĨŽƌŶŽƚĞdžƚĞŶĚŝŶŐ ƚŚĞƚĞƐƚĂŶĂĚĚŝƚŝŽŶĂůϭϱͲϯϬŵŝŶƵƚĞƐ͍ :ŝŵZĞŐŐ ^ƵƉĞƌǀŝƐŽƌ͕/ŶƐƉĞĐƚŝŽŶƐ K' ϯϯϯt͘ϳƚŚǀĞ͕^ƵŝƚĞϭϬϬ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ϵϬϳͲϳϵϯͲϭϮϯϲ &ƌŽŵ͗:ĂLJDƵƌƉŚLJͲ;Ϳф:ĂLJ͘DƵƌƉŚLJΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗^ĂƚƵƌĚĂLJ͕&ĞďƌƵĂƌLJϮϲ͕ϮϬϮϮϳ͗ϱϰD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂLJфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂLJΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх͖tĂůůĂĐĞ͕ŚƌŝƐ;K'ͿфĐŚƌŝƐ͘ǁĂůůĂĐĞΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗,ŝůĐŽƌƉϭϲϵͬE/Ehͬ<ĂůŽƚƐĂϴD/dΖƐ dŚĂŶŬzŽƵĂŶĚĞƐƚZĞŐĂƌĚƐ͕ :ĂLJDƵƌƉŚLJͬ^D +LOFRUS$ODVND//& ,<ZŝŐϭϲϵ KĨĨŝĐĞ͗ϵϬϳͲϳϳϲͲϲϳϳϲ Ğůů͗ϵϬϳͲϳϭϱͲϵϮϭϭ :ĂLJ͘DƵƌƉŚLJΛ,ŝůĐŽƌƉ͘ĐŽŵ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH 1LQLOFKLN.DORWVD 37' -5HJJ 37' Submit to: OOPERATOR: FIEL D / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2220030 Type Inj N Casing 0 3075 3050 3025 Type Test P Packer TVD NA BBL Pump 1.3 IA 0 0 0 0 Interval I Test psi 3000 BBL Return 1.3 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2220030 Type Inj N Tubing 0 0 0 0 Type Test P Packer TVD 1562 BBL Pump 0.6 IA 0 2610 2600 2600 Interval I Test psi 2500 BBL Return 0.6 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 Ninilchik / Ninilchik Unit / Kalotsa Pad Witness Waived Jay Murphy 02/25/22 Notes:Pumped 53 gallons, bled back 53 gallons on 4.5'' Liner and tieback Notes: Notes: Notes: Kalotsa 8 Kalotsa 8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec han i c al In t eg r i t y Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Pumped 26.5 gallons , bled back 26.5 gallons on 7 5/8'' x 4.5'' IA Notes: Notes: Form 10-426 (Revised 01/2017)MIT Kalotsa 8 02-25-22 9 9 9 9 9 9 9 9 - 5HJJ 02/25/22 From: Jacob Flora To: McLellan, Bryan J I0G0 Subject: RE: [EXTERNAL] Kalotsa 8 (PTD 222-003) Perf sundry - Date: Wednesday, February 23, 2022 10:14:18 AM 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. Bryan, Drilling stuck a BHA and we are running casing to just above it and will complete from there up. Pressure calculation update: Our deepest zone of interest now is the Tyonek 37 sand: 5650' TVD 2576 psi BHP (using 0.456) 2011 psi MPSP (with 0.1 psi/ft gas gradient to surface) 7-5/8" casing shoe at 1650' TVD FIT 16.6 ppg EMW Using a target EMW of 16.6 ppg (0.863 psi/ft) to stay 0.5 ppg under the FIT: MPSP = Shallowest Allowable Perf TVD x (0.863 psi/ft — 0.1 psi/ft) 2011 psi = Shallowest Allowable Perf TVD x 0.763 psi/ft 2635 ft = Shallowest Allowable Perf TVD (near the Beluga 80 sand) The original math was done prior to losing part of the deeper hole section and therefore is now more conservative. We are good sticking with the Tyonek 2 at —3800' TVD as the top sand for now per the original sundry. Let me know if you need more data, Thanks, Jake From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, February 23, 2022 8:42 AM To: Jacob Flora <Jake.Flora@hilcorp.com> Subject: [EXTERNAL] Kalotsa 8 (PTD 222-003) Perf sundry Jake, What did you use as your basis for the upper limit of the proposed perf interval in this well? Did you consider pore pressure/frac gradient? 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 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. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25-280 RECEIVED By Samantha Carlisle at 12:30 pm, Feb 22, 2022 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: Abandon BHA (RA0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 0 - Stratigraphic ❑ Service ❑ 222-003 ' 3. Address: 6. API Number: 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-133-20705-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes❑ No ❑.1 Kalotsa 8 9. Property Designation (Lease Number): 10. Field/Pool(s): C061505, ADL384372 Ninilchik / Beluga/Tyonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,603' 7,178' 7,592' 6,187' 997 6,187' 7,592' Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' Surface 2,288' 7-5/8" 2,288' 1.660' 6,880psi 4,790psi Intermediate Production FISH 375' 4-3/4" Dir BHA 7,592' 6,187' N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A 12. Attachments: Proposal Summary L,,J Wellbore schematic Lvj 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑J Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/22/2022 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Yes Date: 2/22/22 AOGCC Representative: Bryan McLellan GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. DIN: —Monty M Myers, c US, Mont M Digitallysi,,,byWntyMMyers Contact Name: Sean Mclaughlin Authorized Name and Y o=HIlmrpAlaska ,LLC,on=Tachnlcal Services -AK Drilling, 2. 2 2. 2 0 2 2 Digital Signature with Date: Reas'o ;a a@",'o°p,hsaee"men, Contact Email: SeBn.mCIBU hlin hIICOr .COm Date: 2022.02,2210:58:18-09'00' Contact Phone: 907-223-6784 Authorized Title: Drilling Manager AOGCC USE ONLY Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: 322-084 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Submit a copy of the report sent to the NRC for "Notification of incidents and lost sources; abandonment procedures for irretrievable sources" within 14 days of submittal to NRC. Affix to the wellhead a permanent surface marker as a visual warning to any person who may reenter the hole for any reason, showing that it con radioactive source. This marker shall contain the PTD number and information required in the NRC regulations 39.15(a)(5)(iii) and a warning not below the plug back depth. Within 30 days of moving the rig off the well. Add Red Iron Oxide Dye to the last 10 bbls of liner cement so the cement inside and outside the shoe is dyed red. Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 101 Subsequent Form Required: 10-407 Jeremy Price oa9eally ozzs;aaesz Price oAPPROVED BY 2/23/22 Approved by: COMMISSIONER THE AOGCC Date: CommdtS 2/23/2022 COmm.JLC 2/23/2022 Sr Pet EngBJM 2/22/22 1 Sr Pet Geo SFD 2/22/2022 JSr Res Eng DSR-2/22/22 ains a o drill Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. RBDMS SJC 022822 Hilcorp Alaska, LL Well Prognosis Well: Kalotsa 8 Date: 2/21/22 Well Name: Kalotsa 8 API Number: 50-133-20705-00-00 Current Status: Abandon sources / Run Liner Estimated Start Date: 2/21/22 Rig: Rig 169 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: TBD Regulatory Contact: Cody Dinger 777-8389 Permit to Drill Number: 222-003 First Call Engineer: Frank Roach (907) 777-8413 (0) (907) 854-2321 (M) Second Call Engineer Sean Mclaughlin (907)-223-6784 (M) AFE Number: Brief Well Summary — The Kalotsa 8 production hole was drilled to a TD of 8,603'. A trip was made to the shoe and then back towards TD. The drilling BHA became stuck with zero movement working drilling jars and unable to circulate. Eline was rigged up to free point then left-hand torque was applied and a string shot fired to back off drill pipe. The drill pipe was recovered leaving top of fish at 7,592' and 372' of BHA in the hole. A fishing assembly was run with no movement or circulation gained. The BHA contains two sources and is not recoverable. A sidetrack is too risky. The BHA will be abandoned in place and the well completed as is. [Ann Cnr\A/nrrl• 1. Back off fishing assembly and trip to surface. LD fishing tools. 2. Make 6-3/4" cleanout run to top of fish. Include jars. 3. Run 4-1/2" liner and cement per program. a. Surface casing shoe — 2287' b. Planned TOL - 2073' c. Cement volume 189 bbls Attachments 1. Actual Schematic 2. Proposed Schematic 3. BHA Tally Note: Approximately 270 feet of HWDP and drill collars will be left above the radioactive sources to act as a non -drillable diversion to prevent inadvertent intrusion of the source as required by NRC regulations 39.15(a)(5)(ii). bjm NRC approval to implement P&A procedures per 39.77(c)(1)(i) is attached. bjm Ninilchik Unit Current Fish SCHEMATIC Kal t222-003 API: 50-133-20705-00-00 Hileorp Alaska, LIA: 16" 9-7/8" hole RKB to GL = 18' 7-5/8" ' hole Size Type Wt 16" Conductor— Driven 84 to Set Depth 7-5/8" Surf Csg 29.7 4-3/4" Stuck BHA containing radioactive sources. sFD 2/22/22 CASING DETAIL Grade Conn. X-56 Weld L-80 I CDC CDS-40 ID Top Btm 15.01" Surf 120' 6.875" Surf I 2,288' 7,592' 7,967' OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 L — 345 sx / T — 240 sx 4-1/2" TBD Stuck BHA TOF @ ® 7.592' Contains radioactive sources. sFD 2/22/22 TOF @ 7,592' MD TD = 8,603'/ TVD = 7,178' Updated by FVR 02-18-2022 16 9-7/8" hole 7.5/8" Stuck Proposed SCHEMATIC Hile-p Alaska, LLC RKB to GL =18' TOF @ 7,592' MD TD = 8,603'/ TVD = 7,178' Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 CASING DETAIL Size Type Wt Grade I Conn. ID I Top I Btm 16" Conductor —Driven 84 X-56 Weld 15.01" Surf 120' to Set Depth 7-5/8" Surf Csg 29.7 L-80 I CDC 6.875" I Surf I 2,288' 4-1/2" Prod Liner 12.6 L-80 I DWC/C HT 3.958" 12,069' I 7,592' 4-1/2" Prod Tieback 12.6 L-80 I DWC/C HT I 3.958" I Surf I 2,069' 4-3/4" Stuck BHA I I 17,592' I 7,967' containing radioactive sources. sFD 2/22/22 JEWELRY DETAIL No. Depth ID OD Item 1 2,069' 4.875" 6.540" Liner hanger / LTP Assembly 2 2,069' 4.790" 6.340" Seal Stem OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess) curt returns t/surf 2/9/22 L — 345 sx / T — 240 sx 4-1/2" TBD 32' ,ntains radioactive urces. sFD 2/22/22 Updated by FVR 02-18-2022 HALLIBURTON I 9Perry Defiling i BHA Tall y Customer Hilcorp Alaska, LLC Well Name Kalotsa 8 Job Number AK-XX-0907653458 Drillstring Rig Name HEC 169 IADC Rig BHA# 2 Field Name Ninilchik Unit Run# 200 Country USA COMPONENT DATA Item .Serial Number E[AID Gauge Um �elg& Top Bottom AMLL Cumulative 1 6.75" HDBDSCMM55D 12998262 in 4.770 1.500 6.750 .. 54.88 0 P 3-1/2" REG 0.96 0.96 2 4 3/4" SperryDrill Lobe 11625350 4.750 2.794 44.57 B 3-1/2" IF B 3-1/2" REG 29.79 30.75 5/6 - 8.3 stg 3 4 3/4" DM Collar 12040980 4.660 1.250 48.20 B 3-1/2" IF P 3-1/2" IF 8.97 39.72 4 4 3/4" GM Collar 90669807 4.740 1.250 48.20 B 3-1/2" IF P 3-1/2" IF 9.27 48.99 5 4 3/4" ADR Collar 90669956 5.050 1.250 53.70 B 3-1/2" IF P 3-1/2" IF 27.29 76.28 6 4 3/4" ALD Collar 90669107 5.140 1.250 5.690 45.50 B 3-1/2" IF P 3-1/2" IF 14.35 90.63 Stabilizer 5.690 7 4 3/4" CTN Collar 90669107 4.740 1.250 50.50 B 3-1/2" IF P 3-1/2" IF 11.13 101.76 8 4 3/4" PW D 90669011 4.710 1.250 47.90 B 3-1/2" IF P 3-1/2" IF 9.15 110.91 9 4 3/4" TM HOC 12334772 4.850 1.250 46.10 B 3-1/2" IF P 3-1/2" IF 11.09 122.00 10 4 3/4" Flex Collar 11564357 4.690 2.250 45.33 B 3-1/2" IF P 3-1/2" IF 31.15 153.15 11 4 3/4" Flex Collar 11623625 4.700 2.250 45.58 B 3-1/2" IF P 3-1/2" IF 30.75 183.90 12 X-Over Sub UCOD 4886 5.220 2.690 53.57 B 5.25 P 3-1/2" IF 2.49 186.39 CDS-40 13 6 jts 4.5" 36.86# CDS40 4.500 2.813 36.86 183.25 369.64 HWDP 14 X-Over Sub UCOD 4708 5.200 2.250 58.83 B 3-1/2" IF P 5.25 2.54 372.18 CDS-40 15 4 3/4" YellowJacket Jar A23804 4.860 2.250 49.67 B 3-1/2" IF P 3-1/2" IF 29.24 401.42 16 X-Over Sub UCOD 4705 5.130 2.310 56.16 B 5.25 P 3-1/2" IF 2.41 403.83 CDS-40 17 11 jts 4.5" 36.86# 1 4.500 2.813 36.86 336.01 739.84 CDS40 HWDP RPr'n\/PrPri iarc anri i in t"_rnccnvar anri halr-M/ loft in hnla (177 1 R'1 ' • 739.84 Bit Number 2 Nozzles : 5x11 Bit Size (in) 6.750 TFA (in2) : 0.4640 Manufacturer HDBS Dull Grade In : NEW Model MM55D Dull Grade Out Serial Number 12998262 Job No: AK-XX-0907653458 Well Name: Kalotsa 8 BHA Tally INSITE V9.2.0 Page 1 HALLtBURTON I 9—Iry Orklling _ t • •' DATA Motor Number 2 Bend (deg) 1.50 OD (in) : 4.750 Nozzles (32nd) 0.0 Manufacturer Sperry Drilling Avg Diff Press Model TerraForce Cumul Cir Hrs Serial Number 11625350 BHA Weight (klb) (klb) in Air (Total) 29.71 in Mud (Total) 25.64 Mud Weight (ppg) 9.00 in Air (Below Jars) 15.74 in Mud (Below Jars) 13.58 Motor assembly for 6-3/4" Production Hole section 4-3/4" TerraForce Mud Motor, @ 1.50°, 5/6 8.3stg, 1.00 Rev/Gal Dir: 34.97', Gamma: 44.28' Res: 62.44', Density: 80.82', Porosity: 95.59', PWD: 107.27' RFO= 350/481 x 360= 261.95' Planned Parameters: 200-290 GPM, 60-80 RPM, 3k-8k WOB Torque Bit - 8K, 3-1/2" IF - 10K Jar Hrs. In: 133.26 / Jar Hrs. Out: XXX Job No: AK-XX-0907653458 Well Name: Kalotsa 8 BHA Tally INSITE V9.2.0 Page 2 Carlisle, Samantha J (OGQ From: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Tuesday, February 22, 2022 12:04 PM To: Rixse, Melvin G (OGC) Cc: McLellan, Bryan J (OGC); Frank Roach; Regg, James B (OGC) Subject: FW: [EXTERNAL] FW: Halliburton Alaska NRC License 42-01068-07 - Source Abandonment 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. Mel, Below is what was sent to the NRC after verbal approval was given. Regards, lean From: Aaron Wisroth <Aaron.Wisroth@halliburton.com> Sent: Tuesday, February 22, 2022 9:51 AM To: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com> Cc: Frank Roach <Frank.Roach@hilcorp.com>; Steve Greene <Stephen.Greene@Halliburton.com>; Craig Zawadzki <Craig.Zawadzki@HALLIBURTON.com> Subject: [EXTERNAL] FW: Halliburton Alaska NRC License 42-01068-07 - Source Abandonment Sean, see below for the email our North America Radiation Safety Officer sent back to the NRC following their verbal approval. Thank you, Aaron From: Craig Zawadzki<Craig.Zawadzki@HALLIBURTON.com> Sent: Tuesday, February 22, 2022 9:18 AM To: Aaron Wisroth <Aaron.Wisroth@halliburton.com> Subject: FW: Halliburton Alaska NRC License 42-01068-07 - Source Abandonment Aaron, Here is the followup email to the verbal approval from the NRC this morning. Thanks, Craig From: Kevin Bowery <Kevin.Bowery@halliburton.com> Sent: Tuesday, February 22, 2022 8:20 AM To: lizeppe.roldan@nrc.gov Cc: James.thompson@nrc.gov; Craig Zawadzki <Craig.Zawadzki@HALLIBURTON.com>; Bradley Seguin <Bradley.Seguin@halliburton.com>; Santiago Aguirre <Santiago.Aguirre@halliburton.com>; Robert Richard <Robert.Richard@ halliburton.com>; Lee Heft <Lee.Heft@halliburton.com> Subject: Halliburton Alaska NRC License 42-01068-07 - Source Abandonment Hello Ms. Roldan, Just to follow up on the verbal approval granted at approximately 11:OOam on February 22, 2022 to abandon the following radioactive sources. 1 - Am24113e 8Ci well logging source 1— Cs-137 2Ci well logging source Drill Company: HilCorp Alaska, LLC Well Name: Kalotsa 8 Well Registration Number: 50-133-20705-00-00 Please let me know if you require any other information at this time. I will provide a written notice on behalf of Halliburton Energy Services within 30 days of February 22, 2022 as required by 39.77 Notification of incidents and lost sources; abandonment procedures for irretrievable sources. Thank you, Kevin Bowery Sr. Radiation Safety Officer - North America 3000 N. Sam Houston Pwky E Houston, TX 77032 - 3219 Email: kevin.bowery(J)Oalliburton.com Mobile: +1 325-208-5472 Follow Halliburton: Linkedln I Facebook I Twitter I YouTube I Blo4 HAL LIBURTON This e-mail, including any attached files, may contain confidential and privileged information for the sole use of the intended recipient. Any review, use, distribution, or disclosure by others is strictly prohibited. If you are not the intended recipient (or authorized to receive information for the intended recipient), please contact the sender by reply e-mail and delete all copies of this message. 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. Carlisle, Samantha J (OGQ From: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Tuesday, February 22, 2022 3:10 PM To: McLellan, Bryan J (OGQ Subject: NRC abandonment requirements 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. Bryan, Below are the abandonment requirements in the NRC Regulations (NRC, 10 CFR). The Hilcorp and Halliburton plan meets or exceeds these requirements. Regards, sean 39.15 Agreement with well owner or operator. (a) A licensee may perform well logging with a sealed source only after the licensee has a written agreement with the employing well owner or operator. This written agreement must identify who will meet the following requirements: (1) If a sealed source becomes lodged in the well, a reasonable effort will be made to recover it. (2) A person may not attempt to recover a sealed source in a manner which, in the licensee's opinion, could result in its rupture. (3) The radiation monitoring required in § 39.69(a) will be performed. (4) If the environment, any equipment, or personnel are contaminated with licensed material, they must be decontaminated before release from the site or release for unrestricted use; and (5) If the sealed source is classified as irretrievable after reasonable efforts at recovery have been expended, the following requirements must be implemented within 30 days: (i) Each irretrievable well logging source must be immobilized and sealed in place with a cement plug. (ii) A means to prevent inadvertent intrusion on the source, unless the source is not accessible to any subsequent drilling operations; and (iii) A permanent identification plaque, constructed of long lasting material such as stainless steel, brass, bronze, or monel, must be mounted at the surface of the well, unless the mounting of the plaque is not practical. The size of the plaque must be at least 17 cm [7 inches] square and 3 mm ['/a inch] thick. The plaque must contain -- (A) The word "CAUTION"; (B) The radiation symbol (the color requirement in § 20.1901(a) need not be met); (C) The date the source was abandoned; (D) The name of the well owner or well operator, as appropriate; (E) The well name and well identification number(s) or other designation; (F) An identification of the sealed source(s) by radionuclide and quantity; (G) The depth of the source and depth to the top of the plug; and (H) An appropriate warning, such as, "DO NOT RE-ENTER THIS WELL." (b) The licensee shall retain a copy of the written agreement for 3 years after the completion of the well logging operation. (c) A licensee may apply, pursuant to § 39.91, for Commission approval, on a case -by -case basis, of proposed procedures to abandon an irretrievable well logging source in a manner not otherwise authorized in paragraph (a)(5) of this section. (d) A written agreement between the licensee and the well owner or operator is not required if the licensee and the well owner or operator are part of the same corporate structure or otherwise similarly affiliated. However, the licensee shall still otherwise meet the requirements in paragraphs (a)(1) through (a)(5). Sean McLaughlin Hilcorp Alaska, LLC Drilling Engineer Sean.McLaughlin@hilcorp.com Cell: 907-223-6784 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. Carlisle, Samantha J (OGQ From: McLellan, Bryan J (OGC) Sent: Tuesday, February 22, 2022 4:56 PM To: Sean Mclaughlin Cc: Rixse, Melvin G (OGC); Boyer, David L (OGC); Davies, Stephen F (OGC); Roby, David S (OGC); Chmielowski, Jessie L C (OGC) Subject: Kalotsa 8 (PTD 222-003) Radioactive Source abandonment sundry Sean, You have verbal, conditional approval to proceed with running the production liner above the stuck radioactive source in Kalotsa 8 as outlined in the sundry application submitted by Hilcorp today. Conditions of approval: 1. Ensure that you have obtained NRC approval to implement these abandonment procedures. 2. Include a red Iron Oxide Dye in the last 10 bbls of cement to ensure the cement in the shoe and outside the shoe is red. 3. Submit a copy of the final report sent to the NRC for "Notification of incidents and lost sources; abandonment procedures for irretrievable sources" Within 14 days of submittal to NRC. 4. Affix to the wellhead a permanent surface marker as a visual warning to any person who may reenter the hole for any reason, showing that it contains a radioactive source. This marker shall contain the PTD number and information required in the NRC regulations 39.15(a)(5)(iii) and a warning not to drill below the plug back depth. 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 Carlisle, Samantha J (OGQ From: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Monday, February 21, 2022 5:10 PM To: william.cartwright@halliburton.com Cc: Frank Roach; Rance Pederson - (C); Monty Myers Subject: RE: [EXTERNAL] Nuke Source Abandonment procedures.... Attachments: Kalotsa 8 10-403 Abandon Sources Program.docx; Kalotsa 8 Fish Schematic 2-21-22.doc; Kalotsa 8 Proposed Schematic 2-21-22.doc; Kalotsa 8_R200_BHA2_BHA Tally.pdf Hi Bill, - 80' cemented shoe track - 271' of non -drillable BHA above the upper source. - A plaque will be placed at the wellhead - The well will produce from a shallower depth (7020' is planned perforation depth, 7,592' is top of fish, 7,863' is upper source depth). Give me a call if you have any questions. Sean 907.223.6784 From: Rance Pederson - (C) <rpederson@hilcorp.com> Sent: Monday, February 21, 2022 4:58 PM To: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com>; Monty Myers <mmyers@hilcorp.com> Cc: william.cartwright@halliburton.com Subject: FW: [EXTERNAL] Nuke Source Abandonment procedures.... See page 15. Would the 6 jnts HWDP, NM flex DC's etc count as a non -drillable device? If you have any questions please call Bill Cartwright at 907-394-1239 From: William Cartwright <William.Cartwright@halliburton.com> Sent: Monday, February 21, 2022 4:51 PM To: Rance Pederson - (C) <rpederson@hilcorp.com> Subject: [EXTERNAL] Nuke Source Abandonment procedures.... FYI.... Thanks, Bill Cartwright Halliburton I Sperry 6900 Arctic Blvd, Anchorage, AK Cell: (907)394-1239 I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED By Samantha Carlisle at 1:02 pm, Feb 18, 2022 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 ❑r Re-enter Susp Well ❑ Alter Casing ❑ Other: CT / N2 Operations ❑r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ 222-003 ' 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99516 50-133-20705-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701 C Will planned perforations require a spacing exception? Yes ❑ No Kalotsa 8 9. Property Designation (Lease Number): 10. Field/Pool(s): C061505 / ADL384372 Ninilchik Field / Beluga-Tyonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,603' ±7,178 (proposed) ±8,523 (proposed) ±7,083 (proposed) 2,557 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' 2,980psi 1,410psi Surface 2,287' 7-5/8" 2,287' 1,663' 6,880psi 4,790psi Intermediate Production ±6,534' (proposed) 4-1/2" ±8,603' (proposed) ±7,178' (proposed) 8,430psi 7,500psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: ng Grade: Tubing MD (ft): N/A N/A 4-1/2"(proposed) F12.6#/ L-80 (proposed) ±2,069'(proposed) Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Liner Hanger/LTP Assembly ±2,069 MD (proposed) / ±1,573 TVD (proposed) 12. Attachments: Proposal Summary Q Wellbore schematic (] 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/23/2022 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: AOGCC Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Digitally signed by Dan Marlowe Dan Marlowe 1s7 Contact Name: Jake Flora DIN cn=Dan Marlowe (1267), Authorized Name and (1267) o"=users Date: 2022.02.18 11:48:50-09'00' Digital Signature with Date: Contact Email: Jake. FlOra hIICOr .COm Contact Phone: 907 777-8442 Authorized Title: Dan Marlowe, Operations Manager AOGCC USE ONLY Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: 322-077 Plug Integrity ❑ BOP Test ® Mechanical Integrity Test ❑ Location Clearance ❑ Other: CT BOP test to 3500 psi. Review results of CBL with AOGCC and obtain approval before perforating. Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Fd Subsequent Form Required: 10-407 Jeremy n'e"my;,9ee"'y APPROVED BY 2/24/22 tl: Price 1D 85Z2-2 Approved by: COMMISSIONER THE AOGCC Date: Comm.dts 2/24/2022 Comm-JLC 2/24/2022 JSr Pet Eng BJM 2/23/22 1 JSr Pet Geo SFD 2/22/2022 1 ISr Res Eng DSR-2/18/22 Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. RBDMS SJC 022822 Kalotsa-08 Initial Completion l[itrurp Alaska. UAI Well Name: Kalotsa 8 API Number: 50-133-20705-00-00 Current Status: New Drill Gas Producer Permit to Drill Number: 222-003 Regulatory Contact: Juanita Lovett (907) 777-8332 (0) First Call Engineer: Jake Flora (907) 777-8442 (0) (720) 988-5375 (C) Second Call Engineer: Ryan Rupert (907) 777-8503 (0) (907) 301-1736 (C) Maximum Expected BHP: 3275 psi Max. Potential Surface Pressure: 2557 psi Brief Well Summary 0.456 psi/ft gradient (7180' TVD) BHP minus 0.1 psi/ft gradient Kalotsa 8 is a grass roots well targeting the Tyonek and Beluga Sands. All perforations below are within the same pool. No SSSV is required for this well. The purpose of this work/sundry is to complete the well for production Notes Regarding Wellbore Condition • 4-1/2" liner and tubing will be filled with 6% KCL • WBV—130bbls • Max inclination: 68 degrees at 2050' MD • Sail angle of 58 degrees from 2400 — 3200' MD Prnrarlura 1. RU E-line, pressure test lubricator above MPSP 2. Log CBL, send results to AOGCC 3. MIRU Coiled Tubing, Notify AOGCC 24 hrs. in advance of BOP test 4. Test CT BOPE to 250 low / 3500 psi high 5. RIH with coil tubing to PBTD, jet well dry with Nitrogen 6. Consult OE for nitrogen pressure to leave trapped on well 7. RDMO Coiled Tubing 8. RU E-line and pressure control equipment, test Lubricator above MPSP 9. Ensure AOGCC approval has been obtained to perforate (since receiving the CBL) 10. Perforate sands from the bottom up: Top Tyonek 2 — Tyonek 110 (-3800' — —7178' TVD) a) All perforations lie in the NINILCHIK, BELUGA-TYONEK GAS POOL 11. Turn well over to production 12. Notify AOGCC 24hrs before testing, and then test SSV Note: BHA was stuck while drilling and liner run above stuck BHA, so PBTD is now shallower. Deepest proposed perf is now 5650' TVD. bjm Contingency EL Plug or Patch 1. MIRU E-line, PT lubricator above MPSP 2. RIH W/ GPT tool and find fluid level 3. RU Nitrogen Truck a. Push water back into formation Kalotsa-08 Initial Completion b. Use GPT tool to confirm water level is below interval to perf c. Consult OE for pressure to leave on well for perforating 4. Once fluid level is below interval to isolate, MU 4-1/2" patch or plug 5. RIH and set plug or patch per OE. 6. RD E-Line Unit and turn well over to production. Attachments- 1. Proposed Well Schematic 2. Fox Energy Coil tubing BOPE 3. Standard Well Procedure— N2 Operations Hilcarp Alaska, LLC 16" 9 7/8" hole 7-5/1" 6-3/4" hole awe 4-1/2' RKBtoGL=18' PBTD=±8,523' / TVD = ±7,083' TD = 8,603' / TVD=±7,178' a m " Ninilchik Unit Kalotsa 8 PTD: 222-003 API: 50-133-20705-00-00 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 CDC 6.875" Surf 2,287' 4-1/2" Prod Lnr 12.6 L-80 DWC/C HT 3.958" ±2,069' ±8,603' Tubing Details 4-1/2" 12.6 1 L-80 I DWC/C HT 3.958" Surf ±2,069' JEWELRY DETAIL No. Depth ID OD Item 1 ±2,069' 4.875" 6.540" Liner hanger/ LTP Assembly 2 ±2,069' 4.790" 1 6.340" Seal Stem PERFORATION DETAIL Zone Top (MD) l3tm (MD) Top (TVD) Btm (TVD) FT Date Status T-2—T-110 ±5,175' ±8,603' ±3,800' ±7,178' FUTURE PROPOSED OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess) cmt returns t/surf 2/9/22 4-1/2" Est. TOC @ TOL (40% excess) Updated By: JLL 02/18/22 min e2 WH fs t 1502 r 2-1ri! R-g.d v.o- ;Minim I 10K Rallod tMm d Coil Tubing HR6801njettorHead & Goaseneck Weight = 12,850 lb 4-1016' 10K ODnVentianal Stripper 15K PSt C646 Lubricator 1SK PSI CB45 commection 4,1J16' 10K Combi BOP rtw Sr r sift?s l+er Snoone Sd-R aSl. 4-V16' 1OK Flow Cress Mmudl 2a Ve4e !: 2' 1502 x 2- U16' 1GK Fletc. U-14 24 V-1-2- 7•rn614K ar 2,IJIW DM R-N M.n W 2.2 VtF b I2-111fi' ' 1OK x2-cliff e}K %N. Mmid 2.2 V.h*4: 2' 102 .2-1116' 10K nJYgn C111V 10K x lWlhead Adapter Flange "Item 11 STANDARD WELL PROCEDURE HilcorpAlaska, LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINALv1 Page 1 of 1 FLOOR SAFTY VALVES: BOP STACK: STATE OF ALASKA Reviewed By: J2 OIL AND GAS CONSERVATION COMMISSION P.I. Supry Lc— BOPE Test Report for: NINILCHIK UNIT KALOTSA 8 Comm Contractor/Rig No.: Hilcorp 169, PTD#: 2220030 - DATE: 2/11/2022 Inspector Austin McLeod Insp Source Operator: Hilcorp Alaska, LLC P/F Operator Rep: Pederson/Riley Rig Rep: Davis/Lynch Inspector Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopSAM220211180131 Quantity P/F Rams. Annular: Valves: n1ASP: Type Test: INIT P _ 250/3500 - 250/2500 250/3500 ' 997 Related Insp No: 0 - __- -_ NA TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: - 1 P/F Visual Alarm Time/Pressure P/F Location Gen.: P - Trip Tank P P System Pressure _ 3025___ P Housekeeping: -P-_ Pit Level Indicators P P Pressure After Closure 1625 P- PTD On Location P Flow Indicator P P 200 PSI Attained 20 P Standing Order Posted - P_ " Meth Gas Detector P "_- P Full Pressure Attained 88 P Well Sign P H2S Gas Detector P_ P Blind Switch Covers: All stations P _ DO. Rig P MS Mise NA_- NA Nitgn. Bottles (avg): 4 a4 2 _ P Hazard Sec. P " ACC Mise _ 0 NA Misc NA #3 Rams FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly I _ P _ Stripper 0 - __- -_ NA No. Valves 15 P, Lower Kelly - 1 P Annular Preventer 1 l 1" FP ✓ Manual Chokes 1 P " Ball Type - I P #1 Rams 1 2-7/8"x5" _ P Hydraulic Chokes 1 P Inside BOP I P #2 Rams 1 " Blinds P _ CH Misc 0--- NA FSV Misc - - 0 - NA #3 Rams -_ 1 2-7/8"x5" ✓ -FP - #4 Rams #5 Rams -_0 0 -- -NA NA ----- INSIDE REEL VALVES: #6 Rams - 0 NA_ (Valid for Coil Rigs Only) Choke Ln. Valves 1 3-1/8" P Quantity P/F HCR Valves 2' 2-1/16"/3-1/8 P Inside Reel Valves 0 NA__-_ Kill Line Valves 2 ' 2-1/16" P Check Valve 0 NA BOP Misc I " FP Number of Failures: 3 ' Test Results Test Time 6.5 Remarks: 2-7/8" & 4-1/2" joints. Annular functioned for a pass. LPR functioned for a pass. BOP mise is LPR door leak -tightened for a pass. Annular 18 secs; R 6 secs; 4 secs; HCR's 1 sec. THE STATE °'ALASKA GOVERNOR MICHAEL J. DUNLEAVY Monty Myers Drilling Manger Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Ninilchik Field, Beluga/Tyonek Oil Pool, Kalotsa 8 Hilcorp North Slope, LLC Permit to Drill Number: 222-003 Surface Location: 2078' FSL, 373' FWL, SEC. 07, T1S, R13W, SM, AK Bottomhole Location: 1107' FNL, 2079' FEL, SEC. 12, T1S, R14E, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced 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 Digitally signed by Y Jeremy Price Price Date:2022.01.25 14:39:30-09'00' Jeremy M. Price Chair DATED this 25 day of January, 2022. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL RECEIVED By Samantha Carlisle at 10:26 am, Jan 18, 2022 1 a. Type of Work: Drill Q * Lateral ❑ Redrill ❑ Reentry ❑ 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ Stratigraphic Test ❑ Development -Oil ❑ Service- Winj ❑ Single Zone 0 Exploratory - Oil ❑ Development - Gas Q Service - Supply ❑ Multiple Zone ❑ 1 c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: Hilcorp Alaska, LLC 5. Bond: Blanket Q Single Well ❑ Bond No. 022224484 11. Well Name and Number: Kalotsa 8 3. Address: 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 6. Proposed Depth: MD: 8,603' TVD: 7,161' 12. Field/Pool(s): Ninilchik Field Beluga/Tyonek Gas Pool 4a. Location of Well (Governmental Section): Surface: 2078' FSL, 373' FWL, Sec 7, T1S, R13W, SM, AK Top of Productive Horizon: 2252' FSL, 353' FEL, Sec 12, T1S, R14W, SM, AK Total Depth: 1107' FNL, 2079' FEL, Sec 12, T1S, R14W, SM, AK 7. Property Designation: C061505, ADL384372 8. DNR Approval Number: N/A 13. Approximate Spud Date: 2/1/2022 9. Acres in Property: 4762 14. Distance to Nearest Prooertv: 3909'to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 209768 y- 2233354 ' Zone-4 10. KB Elevation above MSL (ft): 144.6 GL / BF Elevation above MSL (ft): 126.6 115. Distance to Nearest Well Open to Same Pool: 115' to Kalotsa 5 16. Deviated wells: Kickoff depth: 200 feet Maximum Hole Angle: 66 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 1606 Surface: 997 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 16" 84# X-56 Weld 120' Surface Surface 120' 120' Driven 9-7/8" 7-5/8" 29.7# L-80 CDC 2,269' Surface Surface 2,269' 1,655' L - 818 ft3 / T - 236 ft3 6-3/4" 4-1/2" 12.6# L-80 DWC 6,534' 2,069' 1,493' 8,603' 7,161' L - 1187 ft3 / T - 104 ft3 Tieback 4-1/2" 12.6# L-80 DWC 2,069' Surface Surface 2,069' 1,493' Tieback Assy. 119. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑✓ OP Sketch lling Program Time v. Depth Plot 11 Shallow Hazard Analysis 20. Attachments: Property Plat Q Divertter Sketch e DSleabed Report 8 Drilling Fluid Program V 20 AAC 25.050 requiementse 21. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Frank Roach Authorized Name: Monty Myers Contact Email: frank. roach hllcor .Corn Authorized Title: Drilling Manager Contact Phone: 907-777-8413 Monty M DigiallylcorM-ty byMontyM S, DN: cn=Monty M Myers, c=T1S • . ^ O ^ ^ o=Mi— Alaska,LLC, ou=Technical G G G Authorized Signature: sen-i�ea-AlcDmlmg, Date: Myers Reason: I am approving this document Commission Use Only Date: 2022.01.1 B 095909 A9'00' Permit to Drill JAPI Number:50-133-20705-00-00 Permit Approval 1/25/22 JSee cover letter for other Number: 222-003 Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Q BOP test to 3500 psi, annular test to 2500 psi. Samples req'd: Yes ❑ i Mud log req'd: YesEl No0 Send LOT/FIT data to AOGCC within 2 days of performing test. HZS measures: Yes ❑ No[g Directional svy req'd: YesRR No❑ Spacing exception req'd: Yes ❑ No0 Inclination -only svy req'd: YesO No[9 Post initial injection MIT req'd: YeLl No❑ Jeremy Price DigltallysignedbyJe nnyPki IAPPROVEDBY 1/25/22 by: Date: 2022.01.25 14:40:37 -09'00' COMMISSIONER THE COMMISSION Date: LC 1 /25/2022 Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Hilcorp Alaska, LLC Kalotsa 8 Drilling Program Ninilchik Unit January 14, 2021 Hilcorp Energy Company Contents 1.0 Well Summary........................................................................................................................... 2 2.0 Management of Change Information........................................................................................3 3.0 Tubular Program: ...................................................................................................................... 4 4.0 Drill Pipe Information: .............................................................................................................. 4 5.0 Internal Reporting Requirements............................................................................................. 5 6.0 Planned Wellbore Schematic.....................................................................................................6 7.0 Drilling / Completion Summary................................................................................................7 8.0 Mandatory Regulatory Compliance / Notifications..................................................................8 9.0 R/U and Preparatory Work.....................................................................................................10 10.0 N/U 21-1/4" Conductor............................................................................................................11 11.0 Drill 9-7/8" Hole Section..........................................................................................................13 12.0 Run 7-5/8" Surface Casing......................................................................................................15 13.0 Cement 7-5/8" Surface Casing.................................................................................................18 14.0 BOP N/U and Test.................................................................................................................... 21 15.0 Drill 6-3/4" Hole Section.......................................................................................................... 22 16.0 Run 4-1/2" Production Liner................................................................................................... 25 17.0 Cement 4-1/2" Production Liner............................................................................................. 28 18.0 4-1/2" Liner Tieback Polish Run and Cleanout Run..............................................................32 19.0 4-1/2" Tieback Run.................................................................................................................. 32 20.0 RDMO......................................................................................................................................33 21.0 BOP Schematic........................................................................................................................ 34 22.0 Wellhead Schematic.................................................................................................................35 23.0 Days Vs Depth..........................................................................................................................36 24.0 Geo-Prog.................................................................................................................................. 37 25.0 Anticipated Drilling Hazards.................................................................................................. 38 26.0 Hilcorp Rig 169 Layout........................................................................................................... 40 27.0 FIT/LOT Procedure................................................................................................................. 41 28.0 Choke Manifold Schematic...................................................................................................... 42 29.0 Casing Design Information...................................................................................................... 43 30.0 6-3/4" Hole Section MASP....................................................................................................... 44 31.0 Spider Plot (Governmental Sections)...................................................................................... 45 32.0 660' Radius for SSSV............................................................................................................... 46 33.0 Surface Plat (As -Built NAD27)................................................................................................ 47 KALOTSA 8 Drilling Procedure Rev 0 MCorp Energy Company 1.0 Well Summary Well Kalotsa 8 Pad & Old Well Designation Kalotsa Pad / grass roots well Planned Completion Type 4-1/2" Cemented Production Liner Target Reservoir(s) Belu a/T onek Gas Sands Planned Well TD, MD / TVD 8,603' MD / 7,161' TVD PBTD, MD / TVD 8,523' MD / 7,083' TVD Surface Location Governmental 2078' FSL, 373' FWL, Sec 7, T1S, R13W, SM, AK Surface Location AD 27 X=209768.46 Y=2233354.75 Top of Productive Horizon Governmental 2252' FSL, 353' FEL, Sec 12, T1S, R14W, SM, AK TPH Location AD 27 X=209046.94, Y=2233459.63 BHL Governmental 1107' FNL, 2079' FEL, Sec 12, T1S, R14W, SM, AK BHL AD 27 X=207368.07, Y=2235421.65 AFE Number AFE Drilling Days 3 MOB, 19 DRLG AFE Completion Days AFE Drilling Amount AFE Completion Amount Maximum Anticipated Pressure Surface 997 psi Maximum Anticipated Pressure Downhole/Reservoir 1606 psi Work String 4-1/2" 16.6# S-135 CDS-40 RKB — GL 144.6' 126.6 + 18 Ground Elevation 126.6' BOP Equipment 11" 5M Annular BOP 11" 5M Double Ram 11" 5M Single Ram Page 2 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Enema Company 2.0 Management of Change Information Hilcorp Alaska, LLC Changes to Approved Permit to Drill Date: January 10, 2021 Subject: Changes to Approved Permit to Drill for Kalotsa 8 File #: Kalotsa 8 Drilling Program Hilcorp Fnrrgy C�pany Any modifications to Kalotsa 8 Drilling Program will be documented and approved below_ Changes to an approved PTD will be communicated and approved by the AOGCC prior to continuing with work. Procedure Change Approval: Monty Myers Drilling Manager Prepared: Frank Roach Drilling Engineer Date Date Page 3 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Enema Company 3.0 Tubular Program: Hole Section OD (in) ID (in) Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) Cond 16" 15.01" 14.822" - 84 X-56 Weld 2980 1410 - 9-7/8" 7-5/8" 6.875" 6.750" 8.500" 29.4 L-80 USS-CDC 6880 4790 683 6-3/4" 4-1/2" 3.958" 3.833" 5.000" 12.6 L-80 DWC/C-HT 8430 7500 288 4.0 Drill Pipe Information: Hole Section OD (in) ID (in) TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn 11 Burst (psi) Collapse (psi) Tension (k-lbs) All 4-1/2" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k Cleanout 2-7/8" 2.323 2.265" 3.438" 7.9 P-110 PH-6 16,896 16,082 194k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Energy Company 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area — this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini(cr�,hilcorp.com, mmyers(cr�,hilcorp.com, Frank.Roach@hilcorp.com, and cdin er(cr�,hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by lam on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. This could be one of (3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: 0: (907) 777-6726 C: (907) 227-3189 b. Jacob Nordwall: 0: (907) 777-8418 C: (907) 748-0753 2. Spills: Keegan Fleming: 0:907-777-8477 C:907-350-9439 • Notify Drlg Manager 1. Monty M Myers: 0: 907-777-8431 C: 907-538-1168 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Run" Casing tally to mmyers(&hilcorp.com, Frank.Roach(c-r�,hilcorp.com, and cdinger@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to mmyerskhilcorp.com, Frank.Roachghilcorp.com, and cdingerghilcorp.com Page 5 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Energy Company 6.0 Planned Wellbore Schematic Ninilchik Unit AS -DRILLED SCHEMATIC Plc 8 : API: i5 9.7/1' hae 7-5 jw RK8 to GL=19' PBT➢ = 8, 523' / TV❑ = 7,083' TD = 8,603' j TVD = 7,16V C451NC f]FTAII Size Type Wt Grade Conn. ID Top Rim Sb" Conductor—Drlvan to Set De 84 X•55 Weld 15.0, Surf 12cr 7.5 j8- Surf Csg 29.7 L-90 CDC 6.875' Surf 2„269' 4.112' Pmd Lnr 12.6 L•81) DWCIC HT 3.958- 2,469' 8,6103' - 4-1f2- Prod Tieback 12.6 L-20 DWCfC HT 3558' Surf 2,069' JFWFI RY WFAII No. Depth ID 100 Item 1 2,069' 1 4,875" 1 6.54D" Lkner hanger f LT-9 Assembly 2 2pMr I 4,790" I S.MT Seal Stem OPERA HOLE f CEMENT DETAIL 7 sI8" Est. TOC LO Surface f100% excess 4•1/2" 1 Est. TOC @ TOL (40%excess) Page 6 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Energy Company 7.0 Drilling / Completion Summary Kalotsa #8 is a grassroots development well to be drilled from Kalotsa Pad. This will be an infill well, targeting the Beluga and Tyonek sands for gas production. The base plan is a directional wellbore with a kickoff point at —220' MD. Maximum hole angle will be 67 deg before dropping to 10 deg and TD of the well will be 8,603' TMD/ 7,16 V. TVD. Drilling operations are expected to commence approximately February 1, 2022. The Hilcorp Rig # 169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to —2,269' MD / 1,655' TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 —18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal / beneficial reuse depending on test results. General sequence of operations: 1. MOB Hilcorp Rig # 169 to well site 2. N/U diverter 3. Drill 9-7/8" hole to 2,269' MD. 4. Run and cement 7-5/8" surface casing. 5. ND conductor riser, N/U & test I I" x 5M BOP. 6. Drill 6-3/4" hole section to 8,603' MD. Perform wiper trips as needed. 7. POOH w/drillpipe. 8. Run and cmt 4-1/2" production liner. 9. PU clean out assembly and RIH to clean out 4-1/2" to landing collar 10. Displace well to completion fluid. 11. POOH and LD drillpipe and clean out assembly. 12. RIH and land 4-1/2" tieback string in liner top. 13. N/D BOP, N/U tree, RDMO. Reservoir Evaluation Plan: 1. Surface hole: Gr/Res MWD 2. Production Hole: Triple Combo MWD 3. Mud loggers from surface casing point to TD. Page 7 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Energy Company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling of KALOTSA 8. Ensure to provide AOGCC at least 24 hrs notice prior to testing BOPS. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 515 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the PTD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14-day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure AOGCC approved drilling permits are posted on the rig floor and in Co Man office. • Review all conditions of approval of the PTD on the 10-401 form. Ensure that the conditions of approval are captured in shift handover notes until they are executed and complied with. Regulation Variance Requests: Page 8 Version 0 January, 2022 Hilcorp Energy Company Summary of BOP Equipment and Test Requirements KALOTSA 8 Drilling Procedure Rev 0 Hole Section Equipment Test Pressure(psi) 9-7/8" • 21-1/4" x 2M Hydril MSP diverter Function Test Only • 11" x 5M Annular BOP • 11" x 5M Double Ram Initial Test: 250/3500 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 6-3/4" 11" x 5M Single Ram • 3-1/8" 5M Choke Line Subsequent Tests: • 2-1/16" x 5M Kill line 250/3500 • 3-1/8" x 2-1/16" 5M Choke manifold (Annular 2500 psi) • Standpipe, floor valves, etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon (12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event (BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPS. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in PTD. Additional requirements may be stipulated on PTD and Sundry. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: iim.reggkalaska.gov Bryan McLellan / Petroleum Engineer / (0): 907-793-1226 / Email: bryan.mclellankalaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: victoria.loeppkalaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectorskalaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Version 0 January, 2022 Hilcorp Energy Company 9.0 9.1 9.2 9.3 9.4 9.5 KALOTSA 8 Drilling Procedure Rev 0 R/U and Preparatory Work 16" conductor and cellar already set on pad. Install slip-on 16-3/4" 3M "A" section. Ensure to orient wellhead so that tree will line up with flowline later. Level pad and ensure enough room for layout of rig footprint and R/U. Layout Herculite on pad to extend beyond footprint of rig. R/U Hilcorp Rig # 169, spot service company shacks, spot & R/U company man & toolpusher offices. RU Mud loggers on surface hole section for gas detection only. No samples required 9.7 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.8 Mix mud for 9-7/8" hole section. 9.9 Install 5-1/2" liners in mud pumps. • HHF-1000 mud pumps are rated at 3036 psi (85%) / 370 gpm (100%) at 120 strokes with 5-1/2" liners. Page 10 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Energy Company 10.0 N/U 21-1/4" Conductor 10.1 N/U 21-1 /4" Diverter • N/U 21-1 /4" diverter "T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. Ensure to notify AOGCC inspector to witness function test of diverter. • NOTE: Ensure closing time on diverter annular is in line with API RP 64: o Annular element ID 20" or smaller: Less than 30 seconds o Annular element ID greater than 20": Less than 45 seconds 10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set wear bushing in wellhead. Page 11 Version 0 January, 2022 Hilcorp Energy Company 10.5 Rig 169 Orientation: Note: Actual layout may be different on location KALOTSA 8 Drilling Procedure Rev 0 KALOT A, #4 KALOTSA #3 S ALOT A # `----- — ---,_---- 0� -- ---- I ALLOT A ##7 KALOTSA #6 y ! _ IALOTA #5 I I I ------------- -- 4 LOTSA #8 ' r _ LOTSA P 55 1 R ! � k I 1 ! ! ! ! a I ! 1 1 I I 1 OVT LOT 3�'-- 7, TI, R131, SM A ;x 1 Page 12 Version 0 January, 2022 MCorp Energy Company 11.0 11.2 11.3 KALOTSA 8 Drilling Procedure Rev 0 Drill 9-7/8" Hole Section P/U 9-7/8" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. • Workstring will be 4.5" 16.6# 5-135 CDS40 4-1/2" Workstring & HWDP will come from Hilcorp. Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 11.4 Drill 9-7/8" hole section to 2,269' MD/ 1,655' TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize past experience to drill through coal seams efficiently (Kalotsa 5 and Kalotsa 7 were drilled in 2020). Coal seam log will be provided by Hilcorp Geo team. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • TD the hole section in a good mudstone/siltstone (1,655' TVD). • Take MWD surveys every stand drilled (60' intervals). 11.5 9-7/8" hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud logger's office. System Type: 8.8 — 9.5 ppg Pre -Hydrated Aquagel/freshwater spud mud Properties: De the Density ViscosityPlastic Viscosity Yield Point API FL pH 120-2269' 8.8 - 9.5 85-150 20 - 40 25 45 <10 Page 13 Version 0 January, 2022 Hilcorp Energy Company 11.6 11.7 KALOTSA 8 Drilling Procedure Rev 0 System Formulation: Aquagel + FW spud mud Product Concentration FRESH WATER 0.905 bb1 SODA ASH 0.5 ppb AQUAGEL 12-15 ppb CAUSTIC SODA 0.1 ppb (9 pH) BARAZAN D+ as needed BAROID 41 as required for weight PAC-L /DEXTRID LT if required for <12 FL ALDACIDE G 0.1 ppb X-TEND II 0.02 ppb At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. TOH with the drilling assy, handle BHA as appropriate. Page 14 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 MCorp Energy Company 12.0 Run 7-5/8" Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 7-5/8" casing running equipment. • Ensure 7-5/8" CDC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill -up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 12.3 P/U shoe joint. Visually verify no debris inside joint. 12.4 Continue M/U & thread locking shoe track assy consisting of- (1) Shoe joint w/ float shoe bucked on (thread locked). • (1) Joint with coupling thread locked. • (1) Joint with float collar bucked on pin end & thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1) centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 7-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use "API Modified" thread compound. Dope pin end only w/ paint brush. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 7-5/8" 29.7# CDC M/U torques Casing OD Minimum Maximum Yield Torque 7-5/8" 14,000 ft-lbs 17,000 ft-lbs 20,900 ft-lbs Page 15 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Enema Company ll U. S. Steel Tubular Products UIX212:19-Ca PM 7.525" 29.70lb/ft (0.375" Wall) Lao U S-CDC MECHANICAL PROPERTIES Pipe un-Coe -- Minlmum Yield Strength 80.000 psi — Maximurn Yield Strength 95,00o psi -- Minimum Tenslle Strength 95,000 psl — DIMENSIONS pipe USS-CDCO Outside Diameter 7.825 B-500 in. - Wall Thickness 0.375 — In. — Inside Diameter 6.875 6.875 in - Standard Drift 6.750 6.750 In. — Alternate Drift in - Nominal Linear Weight. T&C 29.70 — lb/ft — Plain End Weight 29,06 Iblft SECTION AREA Pipe UU4DCO — Critical Area 8.541 6,541 sq. In. — Joint Efficiency 1 00.0 % - PERFORMANCE Pipe USS-CDCa — Minlmum Collapse Pressure 4,790 4.790 psl — External Pressure Leak Resistance 3r830 psi Minlrnum Internal Yield Pressure 6.880 6,880 psi — Minimum Pipe Body Yield Strength 6133.000 lb Joint Strength — 721,000 Ib — Compression Rating 433,000 its Reference Length — 1.6,184 ft — Maximum Uniaxial Bend Rating 30,5 dew100 ft MAKE-UP DATA Pipe USS-CDC — Make -Up Loss - 5.19 in. - Minimum Make -Up Torque 14,000 ft-lb Maximum Make -Up Torque - 17,000 ft-lb — Connection Yield Torque 20,900 ft-lb Page 16 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 MCorp Energy Company 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 17 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 MCorp Energy Company 13.0 Cement 7-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. • Pump 20 bbls of freshwater through all of Halliburton's equipment, taking returns to cuttings bin, prior to pumping any fluid downhole • How to handle cmt returns at surface. • Which pump will be utilized for displacement, and how fluid will be fed to displacement PUMP. • Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls spacer. Test surface cmt lines. 13.5 Pump remaining spacer volume. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume + 100% open hole excess. Job will consist of lead & tall, TOC brought to surface. Verified cement calcs - bjm Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (W) 12.0 ppg LEAD: 120' x .16239 bpf = 19.490 109.4 16" Conductor x 7-5/8" casing annulus: 12.0 ppg LEAD: (1769' - 120') x .03825 bpf x 126.15 708.3 9-7/8" OH x 7-5/8" Casing 2.0 = annulus: Total LEAD: 145.64 817.7 15.4 ppg TAIL: (2269'- 1769') x .03825 bpf x 38.25 214.8 9-7/8" OH x 7-5/8" Casing 2.0 = annulus: 15.4 ppg TAIL: 80 x .04592 bpf = 3.67 20.6 7-5/8" Shoe track: Total TAIL: 41.92 bbl 235.4 ft3 TOTAL CEMENT VOL: 187.56 bbl 1053.1 ft3 Page 18 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Energy Company Cement Slurry Design: Lead Slurry (1769' MD to surface) Tail Slurry (2269' to 1769' MD) System Extended Conventional Density 12 lb/gal 15.8 lb/gal Yield 2.40 ft3/sk 1.16 ft3/sk Mixed Water 14.25 gal/sk 5.04 gal/sk Mixed Fluid 14.25 gal/sk 5.04 gal/sk 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with spud mud. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 2269'- 80' = 2189' x .04592 bpf = 101 bbls 0 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.13 Do not overdisplace by more than shoe track volume. Total volume in shoe track is 3.6 bbls. • Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12 — 18 hours after CIP. • Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. Page 19 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 MCorp Energy Company 13.17 M/U pack -off running tool and pack -off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack -off running tool. Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the successor problems during the cement job Send final `As -Run" casing tally & casing and cement report to cdingerkhilcorp.com and Frank.Roach&hilcoM.com. This will be included with the EOW documentation that goes to the AOOOO Page 20 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Energy Company 14.0 BOP NX and Test 14.1 ND conductor riser. 14.2 N/U multi -bowl wellhead assy. Install 7-5/8" packoff P-seals. Test to 3000 psi. 14.3 N/U 11" x 5M BOP as follows: • BOP configuration from Top down: I I" x 5M annular BOP/11" x 5M double ram /I I" x 5M mud cross/11" x 5M single ram • Double ram should be dressed with 2-7/8" x 5" variable bore rams in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8" x 5" variable bore rams • N/U bell nipple, install flowline. • Install (2) manual valves & a check valve on kill side of mud cross. • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2" BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3500 psi for 515 min. Test annular to 250/2500 psi for 515 min. • Utilize both 4-1/2" and 2-7/8" test joints to beset up for production casing cleanout run. • Ensure to leave `B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.0 ppg 6% KCL PHPA mud system. If MW at surface TD was greater than 9.0 ppg, increase density of new mud to match 14.8 R/U mud loggers for production hole section. 14.9 Rack back as much 4-1/2" DP in derrick as possible to be used while drilling the hole section. Page 21 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 MCorp Energy Company 15.0 Drill 6-3/4" Hole Section 15.1 Pull test plug, run and set wear bushing 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TIH, conduct shallow hole test of MWD, and confirm all LWD functioning properly. 15.5 Ensure TF offset is measured accurately and entered correctly into the MWD software. 15.6 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.7 Workstring will be 4.5" 16.6# 5-135 CDS40. Ensure to have enough 4-1/2" DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. 15.8 6-3/4" hole section mud program summary: Weighting material to be used for the hole section will be barite, salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 6% KCL PHPA fresh water based drilling fluid. Properties: Mud Plastic MD Viscosity yield Point pH HPHT Weight Viscosity 2,269'- 8,603' 9.0 - 10.0 40-53 15-25 15-25 8.5-9.5 < 11.0 Page 22 Version 0 January, 2022 Hileorp Energy Compmy KALOTSA 8 Drilling Procedure Rev 0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water 0.905 bbl KCl 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) EZ MUD DP 0.75 ppb (initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC-L 1 ppb BARACARB 5/25/50 15 - 20 ppb (5 ppb of each) BAROID 41 as required for a 9.0 —10.0 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb maintain per dilution rate 15.9 TIH w/ 6-3/4" directional assy to TOC. Shallow test MWD and I" on trip in. Note depth TOC tagged on AM report. 15.10 R/U and test casing to 3500 psi / 30 min. Ensure to record volume / pressure and plot on FIT/LOT graph. AOGCC requirement is 50% of burst. 7-5/8" burst is 6890 psi / 2 = 3445 psi. 15.11 Drill out shoe track and 20' of new formation. 15.12 CBU and condition mud for FIT. 15.13 Conduct FIT. Target value Note: Offset field test data predicts frac gradient at the 7-518 " shoe to be between 12.5 — 21. 0 ppg EMW. A 16.5 ppg FIT results in a 15 bbl kick tolerance while drilling with the planned MW of 9.5 ppg and an assumed 0.5ppg kick intensity over anticipated pore pressure. 15.14 Drill 6-3/4" hole section to 8,603' MD / 7,161' TVD • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 250 - 350 gpm. Ensure shaker screens are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • Make wiper trips every 1000' unless hole conditions dictate otherwise. • On the fourth wiper trip (around 6,500' MD), trip back to the 7-5/8" shoe to split the hole section in half. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. • Take MWD surveys every 100' drilled. Surveys can be taken more frequently if deemed necessary. • Collect samples every 20'. 15.15 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8" shoe. Page 23 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 MCorp Energy Company 15.16 TOH with the drilling assy, standing back drill pipe. 15.17 LD BHA 15.18 2-7/8" x 5-1/2" VBRs previously installed in BOP stack and tested with 4-1/2" test joint. Page 24 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 MCorp Energy Company 16.0 Run 4-1/2" Production Liner 16.1. R/U Weatherford 4-1/2" casing running equipment. • Ensure 4-1/2" DWC/C-HT x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill liner while running. • Ensure all liner has been drifted prior to running. • Be sure to count the total # of joints before running. • Keep hole covered while R/U liner tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. Continue M/U & thread locking shoe track assy consisting of: • (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). • (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). • (1) Joint with Baker landing collar bucked on pin end & threadlocked. • Solid body centralizers will be pre -installed on shoe joint, FC joint, and landing collar joint. • Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe and float collar. • Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 4-1/2" production liner • Fill liner while running using fill up line on rig floor. • Use "API Modified" thread compound. Dope pin end only w/ paint brush. • Install solid body centralizers on every joint across zones of interest, TBD after LWD. • Install solid body centralizers on every other joint to 7-5/8" shoe. Leave the centralizers free floating. 16.5. Continue running 4-1 /2" production liner 4-1/2" 12.6# DWC/C-HT M/U torques Casing OD Minimum Maximum Yield Torque 4-1/2" 5,800 ft-lbs 6,500 ft-lbs 9,240 ft-lbs Page 25 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Energy Company Connection Data Sheet 01) fin.) WEIGHT albs ft) WALL tin.l GRADE DRIFT (in.) RBW% CVHHEC71ON 4,500 Nwninal; 12.60 DWI L-B0 3.833 r}75 DVV C.HT Plain End; 12.26 Nominal OD 4,500 In. Connectlon Type Semt-Prey um T&G Nominal IC 3,9" In. Connectlon OC {nom} 5.000 In. Nominal Area 3,600 sq,In, Connectlon ID glom) 3,956 Jn, Grade Type AN 5CT Makeup Loss 3 938 In. Mln. Yield 5liength so ksl Coupling Length 7.875 In. Max. Yield strength 95 ksl Wlcal Cross Section 3.600 sq.In. Min, Tensile St"th 95 ksl Tension ElIkkney 100.0% of Pape Yield Strength 286 Klb Compression Elfraency 100.0% of pipe Uglmale Strenglh 342 klb i Internal Pressure EiMdency 104,4°ro of pipe Mln, Internal Yield 0,430 psl External Pfesrure EffYclency 100.0% of pipe Ciol* a 7.500 p6l TORQUE Min. Make-up Torque 5,800 fi.lbrr, ONNECTION PERFORMANCESr Yield Slrenptrl 288 Klb Parting Load 342 KIb Oplr MaKo-up Torque 6,t50 it Ins Compression Rating 288 klb Max, Make-up Torque 6,500 q Ebs Min Internal Yletd 8,434 Psl Min Shoulder Torque 580 ft Itns Exlefnal Pressure Rerdslance 7,500 psl Max. Shouldef Torque 4,840 ft rbs Maximum Unlaxial eend Raling $1 5 '1100 ft Max, Della Turn 0 204 Turns Ref Siring Length w 1.6 Der;iign Factor 14,290 ft Max Operational Torque Maximum Torsional Valoe IMTVI 8,400 9,240 ft Ibe ft Ibs For detailed information on perfomiance properties, Few 14 DWG canneotian Data Hates on following pagals). Connection specifications wilhin the control of YAM USA were correct as of the date prinled Specifications are subject to channgge withoul notice, Certain conneclion specifications are dependent on the mechanical properties of the pipe. Mechanical properties of mill proprieta ry pipe grades were obleined from mill publications and are subject to ohan9o. Propertied of m ill proprietary grades shcurd be confirmed wilh the Mill Users are advised to obtain cvnent connection specifications and verify pipe mechanical properties for each application All information is pvided by VAM U SA or its affiliates at user's 6oie riek, without liability for loss, damaga or injury resu Iting from lice use thereof; and on an'AS IS basin withaul warranty or representation of any kind. whether express or implied, including without limitation any warranty of merchantability, ftass for purpose or completeness This document and ls Its oontenare subject to the n9c without notice, In no event shall VAM USA or its aRillalea be re5p4nsibie for any indired, special, incidenlal, punitive. exemplary or consequential lone or damage (including without lirnitahm. lvse of use, toss of bargain. lass of revenue. profit or anticipated profll However caused or arising, and whether such losses or damages were fwesseable or YAM U SA ar its affiliates was advised of the passibility or such damages. 0311112021 2:28 PM IW&49 USA Page 26 Version 0 January, 2022 Hilcorp Energy Company 16.6. 16.7. 16.8. 16.9. KALOTSA 8 Drilling Procedure Rev 0 Run in hole w/ 4-1/2" liner to the 7-5/8" casing shoe. Fill the liner with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. Obtain slack off weight, PU weight, rotating weight, and torque of the liner. Circulate 2X bottoms up at shoe, ease liner thru shoe. 16.10. Continue to RIH w/ liner no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set liner slowly in and out of slips. 16.12. PU 4-1/2" X 7-5/8" Baker liner hanger/LTP assembly. RIH 1 stand and circulate one liner volume to clear string. Obtain slack off weight, PU weight, rotating weight, and torque parameters of the liner. 16.13. Continue running in hole at slow speeds to avoid surging well. Target 20 ft/min and adjust slower as hole conditions dictate. 16.14. Monitor PUW & SOW. Circulate BU if needed. Highlight zones of interest before running past, ex: coals 16.15. Swedge up and wash last stand to bottom. P/U 2-5' off bottom. Note slack -off and pick-up weights. 16.16. Stage pump rates up slowly to circulating rate. Circ and condition mud with liner on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean (whichever is longer). Reduce the low -end rheology of the drilling fluid by adding water and thinners. 16.17. Rotate and reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 27 Version 0 January, 2022 Hilcorp Energy Company 17.0 Cement 4-1/2" Production Liner KALOTSA 8 Drilling Procedure Rev 0 17.1. Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. • Pump 20 bbls of freshwater through all of Halliburton's equipment, taking returns to cuttings bin, prior to pumping any fluid downhole • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement PUMP. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to rotate and reciprocate the liner during cmt operations until hole gets sticky 17.3. Pump 5 bbls spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining spacer. 17.6. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 40% OH excess. Verified cement calcs - bjm Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) 12.0 ppg LEAD: 7-5/8" csg x 4-1/2" drillpipe annulus: 200' x .02624 bpf — 5.25 29.5 12.0 ppg LEAD: 7-5/8" csg x 4-1/2" liner annulus: 200' x .02624 bpf = 5.25 29.5 12.0 ppg LEAD: 6-3/4" OH x 4-1/2" annulus: (8103' — 2269') x .02459 bpf x 1.4 = 200.84 1127.6 Total LEAD: 211.34 bbl 1186.6 ft3 15.4 ppg TAIL: 6-3/4" OH x 4-1/2" annulus: (8603'- 8103') x .02459 bpf x 1.4 = 17.21 96.6 15.4 ppg TAIL: 4-1/2" Shoe track: 80 x .01522 bpf = 1.22 6.8 Total TAIL: 18.43 bbl 103.4 ft3 TOTAL CEMENT VOL: 229.77 bbl 1290.0 ft3 Page 28 Version 0 January, 2022 Hilcorp Energy Company Cement Slurry Design: KALOTSA 8 Drilling Procedure Rev 0 Lead Slurry (8103' MD to 2269' MD) Tail Slurry (8603' to 8103' MD) System Extended Conventional Density 12 lb/gal 15.3 lb/gal Yield 2.4 ft3/sk 1.24 ft3/sk Mixed Water 14.09 gal/sk 5.58 gal/sk Mixed Fluid 14.09 gal/sk 5.58 gal/sk 17.7. Drop drillpipe dart and displace with drilling mud. If hole conditions allow — continue rotating and reciprocating liner throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 17.8. Displace cement at max rate of 5 bbl/min. Reduce pump rate to 2-3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re -zeroed at this point. 17.9. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.10. Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger (ensure pressure is above nominal setting pressure, but below pusher tool activation pressure). Hold pressure for 3-5 minutes. 17.11. Slack off total liner weight plus 30k to confirm hanger is set. 17.12. Do not overdisplace by more than '/2 shoe track. Shoe track volume is 1.2 bbls. 17.13. Continue pressuring up to activate LTP pusher tool and set packer with running tool in compression. 17.14. Pressure up to 4,500 psi to neutralize the pusher tool and release the running tool (HRD-E) from the liner. 17.15. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.16. P/U past free -travel verify setting tool is released, confirmed by loss of liner weight. 17.17. Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS nipple. Bump up pressure as req'd to maintain 500 psi DP pressure while moving pipe until the Page 29 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Energy Company pressure drops rapidly, indicating pack -off is above the sealing area (ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 17.18. Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 17.19. Pick up to the high -rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re -tag the liner top, and circulate the well clean. Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 17.20. RD cementers and flush equipment. POOH, LDDP and running tool. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 17.21. If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise) torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 17.22. NOTE: Some hole conditions may require movement of the drillpipe to "work" the torque down to the setting tool. 17.23. After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set -down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. 17.24. WOC minimum of 12 hours, test liner to 3000 psi and chart for 30 minutes. Page 30 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 MCorp Energy Company Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • Note if liner is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns during job. If intermittent, note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Send final "As -Run " liner tally & liner and cement report to cdinger e,hilcorp. com and Frank.Roach@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 31 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 MCorp Energy Company 18.0 4-1/2" Liner Tieback Polish Run and Cleanout Run 18.1. PU liner tieback polish mill assy per Baker rep and RIH on drillpipe. 18.2. RIH to top of liner assembly and establish parameters. Polish tieback receptacle per Baker procedure. 18.3. POOH, and LD polish mill. 18.4. M/U casing clean out assy complete with casing scraper assys for each size casing in the hole. • 3-1/2" bit or mill • Casing scraper & brush for 4-1/2" 12.6# tubulars • +/- 7100' 2-7/8" PH-6 workstring. • Casing scraper & brush for 7-5/8" 29.7# casing • 4-1/2" DP to surface. 18.5. TIH & clean out well to landing collar (+/- 8,523' MD). • Circulate as needed on trip in if string begins to take weight. • Circulate hi-vis sweeps as necessary to carry debris out of wellbore. • Ensure 3-1/2" bit is worked down to the landing collar. • Space out the cleanout BHA so that the 3-1/2" bit reaches the 4-1/2" landing collar when crossover/7-5/8" casing scraper is +/- 30' above the 4-1/2" liner top. 18.6. After wellbore has been cleaned out satisfactorily using mud, test casing to 3,000 psi / 30 min. Ensure to chart record casing test. 18.7. Displace drilling fluid in wellbore with a hi-vis pill followed by 6% KCl completion fluid. Continue displacing until clean completion fluid returning to surface. 18.8. POOH, LDDP and workstring. Clean and clear rig floor in preparation for running tieback. 19.0 4-1/2" Tieback Run 19.1 PU 4-1/2" tieback assembly and RIH with 4-1/2" 12.6# L-80 DWC/C-HT casing. 19.2 No-go tieback seal assembly in liner PBR and mark pipe. PU pup joint(s) if necessary to space out tieback seals in PBR. 19.3 PU hanger and land string in hanger bowl. Note distance of seals from no-go. Page 32 Version 0 January, 2022 Hilcorp Energy Company 19.4 19.5 19.6 20.0 KALOTSA 8 Drilling Procedure Rev 0 Install packoff and test hanger void. Test 4-1/2" liner and tieback to 3,000 psi / 30 min and chart for 30 minutes. Test 7-5/8" x 4-1/2" annulus to 2,500 psi / 30 min and chart for 30 minutes. 20.1 Install BPV in wellhead 20.2 N/D BOPE 20.3 N/U dry -hole tree and test 20.4 RDMO Hilcorp Rig # 169 Page 33 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 MCorp Energy Company 21.0 BOP Schematic Page 34 Version 0 January, 2022 MCorp Energy Company KALOTSA 8 Drilling Procedure Rev 0 22.0 Wellhead Schematic 3 igSm FE,Hv& Y.6% WnK SSM. MPWH{ :: rm 3{+SSti7fF. wf YS'HydnJic .4y r'brN Fr.�, C-J—o f; 263r.43rm. YY 5 2-2 y69e S5A ..- Y63fa3+. 3f� yV Page 35 Version 0 January, 2022 Hilcorp Enema Company 23.0 Days Vs Depth 0 1,000 z,33D 3,000 ft z 4,000 Q; 5,000 2 6,000 7,000 8,000 9,000 Page 36 KALOTSA 8 Drilling Procedure Rev 0 10 15 0 Days Version 0 January, 2022 �4 Hilcorp Enema Company A i rh surface Casing fOE4_34 Beluga 44 Beluga 52 Beluga e0 Beluga 90A Beluga 120 T-12 T-65 T-83 TD (T-110) KALOTSA 8 Drilling Procedure Rev 0 kkjl 14-r.6 IIEC 169 18 126.6 Drill a 8,603 MD (7,161' TVD) grass roots well from the Kalotsa pad at Ninilchik Field (Paxton/KalotsalSusan Dionne Structure) primarily targeting Tyonek and Beluga sands. Kalotsa 8 is a rate and reserves acceleration well. We are planning on intersecting a majority of the Beluga and Tyonek sands at essentially the top of the Pax -Dionne structure. The goal is to see if there are any remaning reserves left in the Middle to Deep Tyonek formations while still setting us up to perforate the Beluga sands at a later date in a structurally advantageous location. LITHOLOGY Slltstano sandstone sandstone sandstone sandstone sandstone sandstone sandstone sandstone siltstone EXPECTED UD TVD TVDSS EASTfNG Est. FLUID L� Fn (FT)NORTHING Pressure depleted gas a, ._ 1,654.E _1 11] .: � ` 547 713.00 depletedg8s 2,564 1,790.8 -1646 2,233,649.90 208,293.50 653.00 depleted gas 3.111 2,072.2 -1928 2,233,953.90 207,940.90 602.00 gas Ad 3.978 2,661.1 -2516 2,234,483.60 207,606.60 gasqm 4,120 2,781.6 -2637 2,234,549.00 207,570.40 depleted gas 4,737 3,356.3 -3212 2.234,746,80 207,482.10 683.00 deplefed gas 5,036 4,635.3 -4491 2,234,974,40 207,443,40 661.00 depleted gas 7,855 6,425.4 -6281 2.235,291,70 207,390.20 983.00 depleted gas B,171 6,736.3 -6592 2,235,346.80 207,380.90 643.00 depleted gas 7,161.0 I-7016 2,235,421.65 207,36B.07 1606.1l 100 FT Gradient 0.431__ 0.365 0.291 0.460 0.459 0204. 0.147 0.153 0,095 0.224 Surface to TD, samples collected at 20' intervals. Two sets of dry cut cuttings, chrornatograph. Cuttinst descriptions provided at no greater than 100' intervals. Sperry GRIRES surface casing string Sperry LW D Triple Combo production string. Page 37 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Energy Company 25.0 Anticipated Drilling Hazards 9-7/8" Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 5001bs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP between 25 — 45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole -cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of —50 - —60 lbs/100ft2 to combat this issue. Maintain low flow rates for the initial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 — 30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 38 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Energy Company 6-3/4" Hole Section: Lost Circulation: Losses beyond seepage have not been observed recently (2020, 3-well Ninilchik campaign). Similarly to the 2020 wells, Kalotsa 8 does cross through expected depleted gas zones. Maintain awareness for potential losses and ensure gain/loss alarms are set. Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Given the volume of losses experienced in KU 42-12 when drilling through Pool 6, ensure all LCM inventory is fully stocked before drilling out surface casing. Hole Cleaning: Maintain rheology w/ viscosifier as necessary. Sweep hole w/ 20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP between 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6% KCl in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt -type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: 112S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 39 Version 0 January, 2022 MCorp Energy Company 26.0 Hilcorp Rig 169 Layout Pagc 40 Version 0 KALOTSA 8 Drilling Procedure Rev 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Energy Company 27.0 FIT/LOT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1 /4 to 1 /2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre -determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre -determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 41 Version 0 January, 2022 MCorp Energy Company 28.0 Choke Manifold Schematic Page 42 Version 0 KALOTSA 8 Drilling Procedure Rev 0 January, 2022 MCorp Energy Company KALOTSA 8 Drilling Procedure Rev 0 29.0 Casing Design Information Calculation & Casing Design Factors Hole Size 9-718" Hole Size 6-314" Hole Size Drilling Mode MASP: MASP- DATE: 0111412022 WELL: Kalotsa 8 FIELD: Ninilchik DESIGN BY: Frank Roach Design Criteria: Mud Density: 9.0 ppg Mud Density: 9.5 ppg Mud Density: 997 psi (see attached MASP determination & calculation) Production Mode MASP: 997 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0,45 psilft) and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing CD 7-518" 4-112" Top (MD) 0 0 Top (TVD) 0 0 Bottom (MD) 2,269 8,603 Bottom (TVD) 1,655 7,161 Length 2,269 8,603 Weight (ppf) 29.7 12A Grade L-30 L-80 Connection DWC1C DWC1C-HT Weight w/o Bouyancy Factor (Ibs) 67.369 108,398 Tension at Top of Section (lbs) 175.787 108,398 Min strength Tension (1000 Ibs) 683 288 Worst Case Safety Factor (Tension) 3.89 2,66 Collapse Pressure at battorn (Psi) 745 3,222 Collapse Resistance w/o tension (Psi) 4.790 7,500 Worst Case Safety Factor (Collapse) 6.43 2.33 MASP (psi) 557 997 Minimum Yield (psi) 1 6.890 1 8,430 Worst case safety factor (Burst) 1 12.38 1 8." Page 43 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 THICOTP Energy Company 30.0 6-3/4" Hole Section MASP ifMaximum Anticipated Surface Pressure Calculation t-[;1onr 6-3/4" Hale Section WELL: Kalotsa 8 FIELD: Ninikhik MD TVD Planned Tap: 2,269 1,655 PlannedTD: 9,603 7,161 Anticipated formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Beluga 44 1790.8 653 depleted gas 7.01 0.365 Beluga 52 2072.2 602 depleted gas 5.59 0.291 Beluga 80 2661A 1225 gas 9.85 0.460 Beluga 90A 2781.6 1276 gas 8.82 0.459 Beluga 120 3356.3 683 depleted gas 3.91 0.204 T-12 4635.3 681 depleted gas 2.83 0.147 T-65 6425.4 983 depleted gas 2.94 0.153 T-83 6736.3 643 depleted gas 1.84 0.095 TD (T-110) 7161.0 1606 depleted gas 4.31 0.224 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date Paxton 8 9.0 - 11.0 1,500 8,038 2014 Paxton 9 9.0 - 9.4 1,391 3,503 2014 Kalotsa 5 9.0 -9.3 1,071 2,082 2020 Paxton 10 9.0 -9.5 1,391 3,979 2020 Kalotsa 7 8.9 - 9.4 1 1,395 1 8,385 1 2020 Assumptions: 1. Fracture gradient at shoe (1595' TVD) is estimated at >16.0 ppg based on sonic data and offset LOT data. 2. Maximum planned mud density for the 6-3/4" hole section is 9.5 ppg. 3. Calculations assume "Unknown" reservoir contains 100% gas (worst case). 4. Calculations assume worst case event is 100,94 evacuation of wellbore to gas_ Fracture Pressure at 7-5/8" shoe considering a full column of gas from shoe to aurfare: TVD Frac Grad 1655 It X 0.860 psi/ft 1423 psi 1423(psi) - i0.1(psi/ft)'1655(ft)]= 1258 psi Surface MASP from pore pressure during production mode (Complete evacuation togas) 2782 It X 0.459 psi/ft 1276 psi Downhole 1275(psi) - [0.1(psi/ft}l' 2782 (ft)]= 997 psi MASP from pore pressure at TD during production made {Complete evacuation to gas) 7161 It li 0.224 psi/ft 1606 psi Downhole 1606{psi) - [0.1(psi/ft)` 7161 (ft)]= 890 psi Summary: 1. MASP while drilling 6.3/4" production hole is governed by pore pressure In the Beluga 90A with entire wellbore evacuated to gas Page 44 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 Hilcorp Energy Company 31.0 Spider Plot (Governmental Sections KALGTSAI 13141.4�, �% ♦ l 4 DIONNE 6 13HW t Kalotsa 8_HHL \ 1 • l } x\ 4 1 KALOTSA 2 eHLP, % ADL359242 rrr4• �� � L } ti • �,y1�q 4BHLji *• ti t rr 0 \• ylf 4 • X PAXTON 8 SHL� c° ~��� • ••` VOTSA5 B IL _�_ °0 1�1 rrr 4 f • rrr ,�• • �t • j PXTON 10 B — f • NINILCHIK r SU01 S014W ti\,r Q rr *,; S001 S013W,/' If 1 • • Kalotsa 8_TPH r •• ►� * • it ° 0 0 — Kalotsa R_ti1 [ G061505 Kalotsa Pad f r i f a< Legend i i 0 Kalotsa S_SHL f rr X Kalotsa 8_TPH _ r ► + i<aiotsa 8_BHL r Jf • Other Surface Well Locations. a Other Bottom Hole Locations i •' ADL384372 -- f -- Well Paths F""] Private Leases ff r Oil and Gas Unit Boundary 0 SU4 1 AC Kalotsa 8 Feet WADS Alaska Stela Plane Zone 4. NA027 IIHi•rrp 41u.ka.l.IA: Map Date, 1IM2022 Page 45 Version 0 January, 2022 KALOTSA 8 Drilling Procedure Rev 0 THICOTP Energy Company 32.0 660' Radius for SSSV N xawtsa 8 5 HL 1 inrh= 2001ea1 a 74477 Pogo 97Fe Nirrllchlk Unit FNI wR�� ms�i 656 tt Suner from Well Sartace Hole Local ion u iop ypp M wo Page 46 Version 0 January, 2022 THICOTP Energy Company 33.0 Surface Plat (As -Built NAD2 539' FWL I 373' FWL , L KALOTSA 8 Drilling Procedure Rev 0 SKALOTSA #4 (DKALOTSA #3 OI{ALOTSA 92 ---- ------ 4PkALOTS4 47 GKALOTSA #6 SKALOTSA #5 ----------------- KALOTSA #3 I KALCTSA PAR ++i GOV`TLOT 3 J S7, T1S, R33W, SM AK i 51�57 513 151-8 S7 T15 R13W (NTS) S18T15 R13W {NT5j co' nl �� SCALE O 'ni _t•� t.r f -NECr h4Y1@IPN H I LCORP ALAS KA, LLC DATE M„p„e F39 DRAM BY Jon KALOTSA PAD WELL ASOUILT WALE +-,m SURFACE LOCATION rnaecr Ko-. mro,o —G-WIFEMW,1TES—e - HOOK ka WIN yd" M 77 kE.Uih FAK IMR�3Mf 11 LM.kTIdJ SECTIOw 7� � rA T��1J4• WEET EMU"'y °'�"'' cw IIjieorp AIaaka, LLC oF: SEWAR0 MERIpIAN, ALASKA Page 47 Version 0 January, 2022 Hilcorp Energy Company •0b ■• *** ASBUILT THIS SURVEY KALOTSA 8 Drilling Procedure Rev 0 ASP ZA NAD&MCOR59G1EFOCK200S ALSBUILT SURFACE LOCATION Tm E WELL Ir NAM LATITUISE NAD83 LONGITUDE NAD93 NORTHING NAD83 EASTING fWL NGVD29 ELEV KALOTSA 41 N Rr 06' 12.722" W 15i' 35' 32A61" 2233233-14' 134966148' 22W 446' 1.2&5 KALOTSA 42 N Sr Q6' 13.U26" W lAr 35' 32.W 2233263.52' 1349a7m6' 2131' 452, 12&S IC OTSA w3 N 64' 06' 13.336" W 151' 35' 32,225" 2231295.19' 1349876.99' 2262' 458' 126.5 KAL07SA," N W 06' 13.570" W 151' 35' 31.736" 22333;3,38' 1349900.S6' 2281' 49T' 126.5 KAL073A M5 N 60' 06' 11,942' W 151' 35' 33.124" 2233154.89' 13A9822.92' 2120' 407' 126.5 KALOTSA N5 N 60' 06' 12.29+4" w 151' 35' 32.641" 2231189.91' 1349853-32' 215V 437' 12Q4 KALOTSA x7 N 60' 06' 11.746" W 151' 3S' 30.6n' 2231233-41' 1349956AI' 2201'�377' S39 126.5 K�4�DT5A Ir8 N ro' ae' 11-531" Yv 151' 35 33.897- 2233113.99' 13-19787.78' 2078' 1 126.6 *** *r• A5RUILT TH15 SURVEY ASP 24 NA D27 {CORPSCON 6.0-11 ASBUILT SURFACE LOCATION TAM WELL0 NA027 LAMDE NA027 LONGITUDE NA027 NORTHING NA027 EA5TING KALOTSANI N 60' 06' 14.861" W 151' 3S' Z4.501" 2233A73.90' 209844.1V KALOTSA Q N 6Q'O6' 15.16S' W 151' 35' 24.385' 2233UM.67' 2D9850.75' KALOTSA #3 N 60' 06' 15.475' W 151' 35' 24, 261' 2233S35.94' 209857.66' M01SA04 N or 06' 15.659' W 151' 3S' 23.8D6' 223355ALOV 209831.14' KAL075A X5 N 6p" 06' 14.381" W 151' 3S' 25,264" 223M5-6T 209$03.59' KALOTSA 86 N 60' 06' 14.433" W 151" 35' 24.G91" 2233430.61' 209833.9R' KALpTSA �r7 N GU" 06' 14.885" W 151' 35' 22,669" 2233474.16' 109937.Og' KALOT$A 1f6 N 6D' D6' 13.670' W 151' 35' 25.937' 2233354,75' M768,.4ir' R MOTES rr........ ..}�..... A. FI�LLL 1 • &kSiS OF +iORgpNTAL: AlAS14A STATE PLANE ZONE 4 � NAM6RVEY FEET DI0 9 (8N�223037. ) (E: f 5UMZa 7Z ELEV 139.79) 2- OASIS OF ELEVATIONS: NGS V82 F'Ia Tro¢M {NGVO 29) 283.59 FEET Ilk 3. SEOTtOH LII'1E5 DERIVED FROM PDUND SURVEY IXMULMFNTS woo T yy , HILCORP ALASKA• LLC t wwm Cel�dtiy inc reuvN ri yw KALOTSA PAD WELL ASBUILT seAa ,ti,m SUIRPACE LOCATION Matti aa mow■ l�wMw • rww`p 1 MR4S1146TEiian m Mo lacy o aoK.0 rano+w4,:.tru - SECTION 7, T1 S. R13W -IT CWL i.ale,x,l�uc,.l.fsnEEYi+ Ililri�rl� :11�R�La, �,1,C SE ARDMERIDIAN.ALASKA �r Page 48 Version 0 January, 2022 HALLIBURTON Sperry Drilling Services HALLIBURTDN IM Hilcorp Alaska, LLC REFERENCE INFORMATION Calculation Method: Minimum Curvature Co-ordinate (N/E) Reference: Well Kalotsa 8, True North Sperry Drilling Error System: ISCWSA Vertical (TVD) Reference: As -Built RKB @ 144.60usft (HEC 169) Scan Method: Closest Approach 3D Measured Depth Reference: As -Built RKB @ 144.60usft (HEC 169) Error Surface: Ellipsoid SPnn-fin n- k- K.;.,;m,, �- Warning Method: Error Ratio SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 2 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 Start Dir 42/100': 200' MD, 2007VD 3 500.00 12.00 276.00 497.81 3.27 -31.13 4.00 276.00 25.95 4 1000.00 32.00 276.00 959.05 22.75 -216.46 4.00 0.00 180.44 Start Dir 4.51/100' : 1000' MD, 959.057VD 5 1767.81 66.52 278.14 1452.65 96.13 -784.67 4.50 3.47 662.88 End Dir : 1767.81' MD, 1452.65' TVD 6 2120.06 66.52 278.14 1593.01 141.89 -1104.49 0.00 0.00 937.29 Start Dir 41/100' : 2120.06' MD, 1593.017VD 7 3170.27 58.00 325.00 2103.60 595.39 -1871.34 4.00 112.39 1816.24 Kalotsa 8 wp05 tgtl Start Dir 32/100' : 3170.27' MD, 2103.67VD 8 4797.48 10.18 349.08 3415.89 1347.92 -2321.95 3.00 174.50 2645.14 End Dir : 4797.48' MD, 3415.89' TVD 9 8602.55 10.18 349.08 7161.00 2008.54 -2449.45 0.00 0.00 3167.45 Total Depth: 8602.55' MD, 7161' TVD 0 Start Dir 42/100' : 200' MD, 200-TVD WELL DETAILS: Kalotsa 8 126.60 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2233354.75 209768.46 60 ° 6' 13.670 N 151 ° 35' 25.937 W SURVEY PROGRAM 500 Start Dir 4.52/100' : 1000' MD, 959.05'TVD 1�0 950- Date: 2022-01-17T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 18.00 2269.00 Kalotsa 8 wp08 (Kalotsa 8) 3_MWD+IFRI+MS+Sag 2269.00 8602.55 Kalotsa 8 wp08 (Kalotsa 8) 3_MWD+IFRI+MS+Sag End Dir . 1767.81 MD, 1452.65 TVD 0�0 Start Dir 42/100' : 2120.06' MD, 1593.017VD 1425 N _ _ 7 5/8" Casing_ _ - - OZ Start Dir 32/100' : 3170.27' MD, 21 1900 O Beluga 44 �O / 0 LO rn a a� m P H 61 71 Beluga 52 Beluga 80 Beluga 90A Beluga 120 T-12 O � OHO Kalotsa 8 wp05 tgtl TVDPath TVDssPath 1790.78 1646.18 2072.18 1927.58 2661.08 2516.48 2781.56 2636.96 3356.25 3211.65 4635.27 4490.67 6425.41 6280.81 6736.32 6591.72 7160.95 7016.35 MDPath Formation 2563.67 Beluga 44 3110.98 Beluga 52 3978.06 Beluga 80 4119.90 Beluga 90A 4736.72 Beluga 120 6036.38 T-12 7855.18 T-65 8171.07 T-83 8602.50 TD (T-110) p00 CASING DETAILS TVD TVDSS 1655.00 1510.40 MD Size Name 2269.10 7-5/8 7 5/8" Casing 7161.00 7016.40 8602.55 4-1/2 4 1/2" Casing 45p0 project: Ninilchik Unit End Dir : 4797.48' MD, 3415.89' T Site: Kalotsa Well: Kalotsa 8 5000 Wellbore: Kalotsa 8 Design: Kalotsa 8 wpO8 5500 6500 7000 7500 T-65 $000 Total Depth :8602.55' MD, 7161' TVD T-83 / TD (T-110) 4 1/2" Casing 8500 - 603 - - - - - Kalotsa 8 wp08 0 475 950 1425 1900 2375 2850 3325 3800 4275 4750 5225 5700 6175 6650 Vertical Section at 310.00o (950 usft/in) HALLIBURTON REFERENCE INFORMATION Project: Ninilchik Unit Co-ordinate (N/E) Reference: Well Kalotsa 8, True North Site: Kalotsa Vertical (TVD) Reference: As -Built RKB @ 144.60usft (HEC 169) sper,y o,llting Measured Depth Reference: As -Built RKB @ 144.60usft (HEC 169) Well: Kalotsa 8 Calculation Method: Minimum Curvature Wellbore: Kalotsa 8 Plan: Kalotsa 8 wp08 WELL DETAILS: Kalotsa 8 2133 Kalotsa 8 wp08 126.60 +N/-S +E/-W Northing Fasting Latitude Longitude 4 1/2" Casing \ 0.00 0.00 2233354.75 209768.46 60' 6' 13.670 N 151 ° 35' 25.937 W 16-1 100 — — — 6150 Total Depth: 8602.55' MD, 7161' TVD CASING DETAILS 6500 TVD TVDSS MD Size Name 1867 6250 1655.00 1510.40 2269.10 7-5/8 7 5/8" Casing 6000 7161.00 7016.40 8602.55 4-1/2 4 1/2" Casing 5150 5500 5250 5000 1600 4"150 4500 End Dir : 4797.48' MD, 3415.89' TVD 4250 4000 3'150 500 1333 3750 0 3�0 1067 y0 Start Dir 31/100' : 3170.27' MD, 2103.67VD / 0 O / 800 / titig� / / / Start Dir 41/100' : 2120.06' MD, 1593.01TVD 533 p End Dir : 1767.81' MD, 1452.65' TVD Kalotsa 8 wp05 tgt / / Start Dir 4.50/]00' : 1000' MD, 959.051TVD 267 ti� / / Start Dir 41/100' : 200' MD, 200TVD / N / 7 5/8" Casing CC/ h n 0 -267 -2933 -2667 -2400 -2133 -1867 -1600 -1333 -1067 -800 -533 -267 0 267 533 800 West( -)/East(+) (400 usft/in) HALLIBURTON Standard Proposal Report Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Ninilchik Unit Site: Kalotsa Well: Kalotsa 8 Wellbore: Kalotsa 8 Design: Kalotsa 8 wp08 Local Co-ordinate Reference: Well Kalotsa 8 TVD Reference: As -Built RKB @ 144.60usft (HEC 169) MD Reference: As -Built RKB @ 144.60usft (HEC 169) North Reference: True Survey Calculation Method: Minimum Curvature Project Ninilchik Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kalotsa _ Site Position: Northing: ,233,473.90usft Latitude: 60° 6' 14.861 N From: Map Easting: 209,844.16usft Longitude: 151° 35' 24.501 W Position Uncertainty: 0.50 usft Slot Radius: 13-3/16" Grid Convergence: -1.38 ° Well Kalotsa 8 _ Well Position +N/-S 0.00 usft Northing: 2,233,354.75 usft Latitude: 60° 6' 13.670 N +E/-W 0.00 usft Easting: 209,768.46 usft Longitude: 151° 35' 25.937 W Position Uncertainty 0.50 usft Wellhead Elevation: usft Ground Level: 126.60 usft Wellbore Kalotsa 8 Magnetics Model Name Sample Date Declination • Field Strength (°) (nT) BGGM2021 3/17/2022 14.09 72.90 54,816.71862925 Design Kalotsa 8 wp08 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 310.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°I100usft) (°/100usft) (°) 18.00 0.00 0.00 18.00 -126.60 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 55.40 0.00 0.00 0.00 0.00 0.00 0.00 500.00 12.00 276.00 497.81 353.21 3.27 -31.13 4.00 4.00 0.00 276.00 1,000.00 32.00 276.00 959.05 814.45 22.75 -216.46 4.00 4.00 0.00 0.00 1,767.81 66.52 278.14 1,452.65 1,308.05 96.13 -784.67 4.50 4.50 0.28 3.47 2,120.06 66.52 278.14 1,593.01 1,448.41 141.89 -1,104.49 0.00 0.00 0.00 0.00 3,170.27 58.00 325.00 2,103.60 1,959.00 595.39 -1,871.34 4.00 -0.81 4.46 112.39 4,797.48 10.18 349.08 3,415.89 3,271.29 1,347.92 -2,321.95 3.00 -2.94 1.48 174.50 8,602.55 10.18 349.08 7,161.00 • 7,016.40 2,008.54 -2,449.45 0.00 0.00 0.00 0.00 111712022 6:26:57PM Page 2 COMPASS 5000.15 Build 91E HALLIBURTON Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Kalotsa 8 Company: Hilcorp Alaska, LLC TVD Reference: As -Built RKB @ 144.60usft (HEC 169) Project: Ninilchik Unit MD Reference: As -Built RKB @ 144.60usft (HEC 169) Site: Kalotsa North Reference: True Well: Kalotsa 8 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 8 Design: Kalotsa 8 wp08 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -126.60 18.00 0.00 0.00 18.00 -126.60 0.00 0.00 2,233,354.75 209,768.46 0.00 0.00 100.00 0.00 0.00 100.00 -44.60 0.00 0.00 2,233,354.75 209,768.46 0.00 0.00 200.00 0.00 0.00 200.00 55.40 0.00 0.00 2,233,354.75 209,768.46 0.00 0.00 Start Dir 41/100' : 200' MD, 200'TVD 300.00 4.00 276.00 299.92 155.32 0.36 -3.47 2,233,355.20 209,765.00 4.00 2.89 400.00 8.00 276.00 399.35 254.75 1.46 -13.86 2,233,356.54 209,754.64 4.00 11.56 500.00 12.00 276.00 497.81 353.21 3.27 -31.13 2,233,358.77 209,737.42 4.00 25.95 600.00 16.00 276.00 594.82 450.22 5.80 -55.18 2,233,361.88 209,713.43 4.00 46.00 700.00 20.00 276.00 689.91 545.31 9.03 -85.91 2,233,365.84 209,682.79 4.00 71.62 800.00 24.00 276.00 782.61 638.01 12.94 -123.16 2,233,370.65 209,645.65 4.00 102.67 900.00 28.00 276.00 872.47 727.87 17.53 -166.75 2,233,376.28 209,602.18 4.00 139.00 1,000.00 32.00 276.00 959.05 814.45 22.75 -216.46 2,233,382.70 209,552.61 4.00 180.44 Start Dir 4.5°/100' : 1000' MD, 959.05'TVD 1,100.00 36.49 276.46 1,041.69 897.09 28.87 -272.39 2,233,390.16 209,496.85 4.50 227.22 1,200.00 40.99 276.83 1,119.67 975.07 36.11 -334.53 2,233,398.90 209,434.90 4.50 279.48 1,300.00 45.48 277.13 1,192.51 1,047.91 44.44 -402.50 2,233,408.87 209,367.15 4.50 336.90 1,400.00 49.98 277.40 1,259.76 1,115.16 53.81 -475.89 2,233,419.99 209,294.01 4.50 399.14 1,500.00 54.47 277.63 1,321.00 1,176.40 64.15 -554.23 2,233,432.21 209,215.94 4.50 465.80 1,600.00 58.97 277.84 1,375.85 1,231.25 75.39 -637.05 2,233,445.45 209,133.41 4.50 536.47 1,700.00 63.47 278.02 1,423.99 1,279.39 87.49 -723.84 2,233,459.63 209,046.94 4.50 610.73 1,767.81 66.52 278.14 1,452.65 1,308.05 96.13 -784.67 2,233,469.73 208,986.33 4.50 662.88 End Dir : 1767.81' MD, 1452.65' TVD 1,800.00 66.52 278.14 1,465.48 1,320.88 100.31 -813.90 2,233,474.62 208,957.22 0.00 687.96 1,900.00 66.52 278.14 1,505.32 1,360.72 113.30 -904.69 2,233,489.79 208,866.76 0.00 765.86 2,000.00 66.52 278.14 1,545.17 1,400.57 126.29 -995.48 2,233,504.96 208,776.31 0.00 843.76 2,100.00 66.52 278.14 1,585.02 1,440.42 139.28 -1,086.28 2,233,520.13 208,685.85 0.00 921.67 2,120.06 66.52 278.14 1,593.01 1,448.41 141.89 -1,104.49 2,233,523.18 208,667.71 0.00 937.29 Start Dir 4°/100' : 2120.06' MD, 1593.017VD 2,200.00 65.33 281.40 1,625.63 1,481.03 154.26 -1,176.40 2,233,537.28 208,596.11 4.00 1,000.34 2,269.10 64.37 284.26 1,655.00 1,510.40 168.14 -1,237.38 2,233,552.62 208,535.49 4.00 1,055.97 7 5/8" Casing 2,300.00 63.95 285.55 1,668.47 1,523.87 175.29 -1,264.26 2,233,560.42 208,508.79 4.00 1,081.15 2,400.00 62.69 289.80 1,713.38 1,568.78 202.40 -1,349.37 2,233,589.56 208,424.35 4.00 1,163.78 2,500.00 61.57 294.14 1,760.14 1,615.54 235.45 -1,431.33 2,233,624.57 208,343.22 4.00 1,247.80 2,563.67 60.92 296.95 1,790.78 1,646.18 259.51 -1,481.69 2,233,649.84 208,293.45 4.00 1,301.85 Beluga 44 2,600.00 60.58 298.57 1,808.53 1,663.93 274.27 -1,509.73 2,233,665.28 208,265.77 4.00 1,332.82 2,700.00 59.74 303.08 1,858.31 1,713.71 318.69 -1,584.20 2,233,711.48 208,192.40 4.00 1,418.42 2,800.00 59.06 307.66 1,909.23 1,764.63 368.49 -1,654.37 2,233,762.95 208,123.45 4.00 1,504.18 2,900.00 58.54 312.30 1,961.05 1,816.45 423.42 -1,719.89 2,233,819.44 208,059.27 4.00 1,589.68 3,000.00 58.20 316.98 2,013.51 1,868.91 483.22 -1,780.45 2,233,880.67 208,000.16 4.00 1,674.51 3,100.00 58.02 321.69 2,066.36 1,921.76 547.59 -1,835.76 2,233,946.35 207,946.42 4.00 1,758.26 3,110.98 58.01 322.20 2,072.18 1,927.58 554.92 -1,841.50 2,233,953.82 207,940.85 4.00 1,767.37 Beluga 52 111712022 6:26:57PM Page 3 COMPASS 5000.15 Build 91E HALLIBURTON Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Kalotsa 8 Company: Hilcorp Alaska, LLC TVD Reference: As -Built RKB @ 144.60usft (HEC 169) Project: Ninilchik Unit MD Reference: As -Built RKB @ 144.60usft (HEC 169) Site: Kalotsa North Reference: True Well: Kalotsa 8 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 8 Design: Kalotsa 8 wp08 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) 1,959.00 3,170.27 58.00 325.00 2,103.60 1,959.00 595.39 -1,871.34 2,233,995.00 207,912.00 4.00 1,816.23 Start Dir 3*/100' : 3170.27' MD, 2103.6'TVD 3,200.00 57.11 325.10 2,119.55 1,974.95 615.95 -1,885.71 2,234,015.90 207,898.13 3.00 1,840.46 3,300.00 54.13 325.46 2,176.01 2,031.41 683.78 -1,932.71 2,234,084.84 207,852.77 3.00 1,920.07 3,400.00 51.14 325.85 2,236.69 2,092.09 749.39 -1,977.55 2,234,151.51 207,809.52 3.00 1,996.59 3,500.00 48.16 326.27 2,301.43 2,156.83 812.60 -2,020.11 2,234,215.73 207,768.50 3.00 2,069.82 3,600.00 45.18 326.73 2,370.04 2,225.44 873.24 -2,060.26 2,234,277.32 207,729.82 3.00 2,139.56 3,700.00 42.20 327.24 2,442.34 2,297.74 931.15 -2,097.90 2,234,336.12 207,693.58 3.00 2,205.62 3,800.00 39.22 327.81 2,518.14 2,373.54 986.17 -2,132.93 2,234,391.96 207,659.89 3.00 2,267.81 3,900.00 36.25 328.46 2,597.21 2,452.61 1,038.14 -2,165.24 2,234,444.69 207,628.84 3.00 2,325.97 3,978.06 33.93 329.04 2,661.08 2,516.48 1,076.49 -2,188.52 2,234,483.60 207,606.49 3.00 2,368.46 Beluga 80 4,000.00 33.28 329.22 2,679.35 2,534.75 1,086.92 -2,194.75 2,234,494.17 207,600.51 3.00 2,379.93 4,100.00 30.32 330.10 2,764.33 2,619.73 1,132.38 -2,221.38 2,234,540.25 207,574.98 3.00 2,429.55 4,119.90 29.73 330.29 2,781.56 2,636.96 1,141.01 -2,226.33 2,234,549.01 207,570.24 3.00 2,438.90 Beluga 90A 4,200.00 27.36 331.15 2,851.92 2,707.32 1,174.39 -2,245.06 2,234,582.82 207,552.32 3.00 2,474.70 4,300.00 24.41 332.43 2,941.88 2,797.28 1,212.84 -2,265.72 2,234,621.76 207,532.60 3.00 2,515.24 4,400.00 21.48 334.04 3,033.96 2,889.36 1,247.63 -2,283.30 2,234,656.96 207,515.86 3.00 2,551.07 4,500.00 18.56 336.13 3,127.91 2,983.31 1,278.65 -2,297.75 2,234,688.33 207,502.15 3.00 2,582.08 4,600.00 15.68 338.97 3,223.47 3,078.87 1,305.83 -2,309.05 2,234,715.77 207,491.52 3.00 2,608.21 4,700.00 12.85 343.02 3,320.38 3,175.78 1,329.09 -2,317.15 2,234,739.21 207,483.98 3.00 2,629.36 4,736.72 11.83 344.99 3,356.25 3,211.65 1,336.63 -2,319.32 2,234,746.80 207,481.99 3.00 2,635.87 Beluga 120 4,797.48 10.18 349.08 3,415.89 3,271.29 1,347.92 -2,321.95 2,234,758.16 207,479.63 3.00 2,645.14 End Dir : 4797.48' MD, 3415.89' TVD 4,800.00 10.18 349.08 3,418.37 3,273.77 1,348.36 -2,322.03 2,234,758.59 207,479.56 0.01 2,645.49 4,900.00 10.18 349.08 3,516.79 3,372.19 1,365.72 -2,325.38 2,234,776.03 207,476.63 0.00 2,659.22 5,000.00 10.18 349.08 3,615.22 3,470.62 1,383.08 -2,328.73 2,234,793.47 207,473.69 0.00 2,672.94 5,100.00 10.18 349.08 3,713.64 3,569.04 1,400.44 -2,332.09 2,234,810.91 207,470.76 0.00 2,686.67 5,200.00 10.18 349.08 3,812.07 3,667.47 1,417.81 -2,335.44 2,234,828.34 207,467.83 0.00 2,700.40 5,300.00 10.18 349.08 3,910.49 3,765.89 1,435.17 -2,338.79 2,234,845.78 207,464.90 0.00 2,714.12 5,400.00 10.18 349.08 4,008.91 3,864.31 1,452.53 -2,342.14 2,234,863.22 207,461.97 0.00 2,727.85 5,500.00 10.18 349.08 4,107.34 3,962.74 1,469.89 -2,345.49 2,234,880.65 207,459.03 0.00 2,741.58 5,600.00 10.18 349.08 4,205.76 4,061.16 1,487.25 -2,348.84 2,234,898.09 207,456.10 0.00 2,755.30 5,700.00 10.18 349.08 4,304.19 4,159.59 1,504.61 -2,352.19 2,234,915.53 207,453.17 0.00 2,769.03 5,800.00 10.18 349.08 4,402.61 4,258.01 1,521.97 -2,355.54 2,234,932.97 207,450.24 0.00 2,782.75 5,900.00 10.18 349.08 4,501.04 4,356.44 1,539.34 -2,358.89 2,234,950.40 207,447.31 0.00 2,796.48 6,000.00 10.18 349.08 4,599.46 4,454.86 1,556.70 -2,362.24 2,234,967.84 207,444.38 0.00 2,810.21 6,036.38 10.18 349.08 4,635.27 4,490.67 1,563.01 -2,363.46 2,234,974.18 207,443.31 0.00 2,815.20 T-12 6,100.00 10.18 349.08 4,697.88 4,553.28 1,574.06 -2,365.59 2,234,985.28 207,441.44 0.00 2,823.93 6,200.00 10.18 349.08 4,796.31 4,651.71 1,591.42 -2,368.94 2,235,002.71 207,438.51 0.00 2,837.66 6,300.00 10.18 349.08 4,894.73 4,750.13 1,608.78 -2,372.29 2,235,020.15 207,435.58 0.00 2,851.39 6,400.00 10.18 349.08 4,993.16 4,848.56 1,626.14 -2,375.65 2,235,037.59 207,432.65 0.00 2,865.11 111712022 6:26:57PM Page 4 COMPASS 5000.15 Build 91E HALLIBURTON Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Kalotsa 8 Company: Hilcorp Alaska, LLC TVD Reference: As -Built RKB @ 144.60usft (HEC 169) Project: Ninilchik Unit MD Reference: As -Built RKB @ 144.60usft (HEC 169) Site: Kalotsa North Reference: True Well: Kalotsa 8 Survey Calculation Method: Minimum Curvature Wellbore: Kalotsa 8 Design: Kalotsa 8 wp08 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +El-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 4,946.98 6,500.00 10.18 349.08 5,091.58 4,946.98 1,643.50 -2,379.00 2,235,055.02 207,429.72 0.00 2,878.84 6,600.00 10.18 349.08 5,190.01 5,045.41 1,660.87 -2,382.35 2,235,072.46 207,426.78 0.00 2,892.57 6,700.00 10.18 349.08 5,288.43 5,143.83 1,678.23 -2,385.70 2,235,089.90 207,423.85 0.00 2,906.29 6,800.00 10.18 349.08 5,386.85 5,242.25 1,695.59 -2,389.05 2,235,107.34 207,420.92 0.00 2,920.02 6,900.00 10.18 349.08 5,485.28 5,340.68 1,712.95 -2,392.40 2,235,124.77 207,417.99 0.00 2,933.75 7,000.00 10.18 349.08 5,583.70 5,439.10 1,730.31 -2,395.75 2,235,142.21 207,415.06 0.00 2,947.47 7,100.00 10.18 349.08 5,682.13 5,537.53 1,747.67 -2,399.10 2,235,159.65 207,412.12 0.00 2,961.20 7,200.00 10.18 349.08 5,780.55 5,635.95 1,765.04 -2,402.45 2,235,177.08 207,409.19 0.00 2,974.93 7,300.00 10.18 349.08 5,878.98 5,734.38 1,782.40 -2,405.80 2,235,194.52 207,406.26 0.00 2,988.65 7,400.00 10.18 349.08 5,977.40 5,832.80 1,799.76 -2,409.15 2,235,211.96 207,403.33 0.00 3,002.38 7,500.00 10.18 349.08 6,075.82 5,931.22 1,817.12 -2,412.50 2,235,229.40 207,400.40 0.00 3,016.11 7,600.00 10.18 349.08 6,174.25 6,029.65 1,834.48 -2,415.85 2,235,246.83 207,397.46 0.00 3,029.83 7,700.00 10.18 349.08 6,272.67 6,128.07 1,851.84 -2,419.21 2,235,264.27 207,394.53 0.00 3,043.56 7,800.00 10.18 349.08 6,371.10 6,226.50 1,869.20 -2,422.56 2,235,281.71 207,391.60 0.00 3,057.29 7,855.18 10.18 349.08 6,425.41 6,280.81 1,878.78 -2,424.40 2,235,291.33 207,389.98 0.00 3,064.86 T-65 7,900.00 10.18 349.08 6,469.52 6,324.92 1,886.57 -2,425.91 2,235,299.14 207,388.67 0.00 3,071.01 8,000.00 10.18 349.08 6,567.95 6,423.35 1,903.93 -2,429.26 2,235,316.58 207,385.74 0.00 3,084.74 8,100.00 10.18 349.08 6,666.37 6,521.77 1,921.29 -2,432.61 2,235,334.02 207,382.80 0.00 3,098.47 8,171.07 10.18 349.08 6,736.32 6,591.72 1,933.63 -2,434.99 2,235,346.41 207,380.72 0.00 3,108.22 T-83 8,200.00 10.18 349.08 6,764.80 6,620.20 1,938.65 -2,435.96 2,235,351.45 207,379.87 0.00 3,112.19 8,300.00 10.18 349.08 6,863.22 6,718.62 1,956.01 -2,439.31 2,235,368.89 207,376.94 0.00 3,125.92 8,400.00 10.18 349.08 6,961.64 6,817.04 1,973.37 -2,442.66 2,235,386.33 207,374.01 0.00 3,139.65 8,500.00 10.18 349.08 7,060.07 6,915.47 1,990.74 -2,446.01 2,235,403.77 207,371.08 0.00 3,153.37 8,600.00 10.18 349.08 7,158.49 7,013.89 2,008.10 -2,449.36 2,235,421.20 207,368.14 0.00 3,167.10 8,602.50 10.18 349.08 7,160.95 7,016.35 2,008.53 -2,449.45 2,235,421.64 207,368.07 0.00 3,167.44 TD (T-110) 8,602.55 10.18 349.08 7,161.00 7,016.40 2,008.54 -2,449.45 2,235,421.65 207,368.07 0.00 3,167.45 Total Depth: 8602.55' MD, 7161' TVD Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Kalotsa 8 wp05 tgtl 0.00 0.00 2,103.60 595.39-1,871.34 2,233,995.00 207,912.00 plan hits target center Circle (radius 100.00) 111712022 6:26:57PM Page 5 COMPASS 5000.15 Build 91E HALLIBURTON Standard Proposal Report Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Ninilchik Unit Site: Kalotsa Well: Kalotsa 8 Wellbore: Kalotsa 8 Design: Kalotsa 8 wp08 Casing Points Local Co-ordinate Reference: Well Kalotsa 8 TVD Reference: As -Built RKB @ 144.60usft (HEC 169) MD Reference: As -Built RKB @ 144.60usft (HEC 169) North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Depth Depth (usft) (usft) Name 2,269.10 1,655.00 7 5/8" Casing 8,602.55 7,161.00 4 1/2" Casing Casing Hole Diameter () Diameter ('.) MIW 7-5/8 9-7/8 4-1/2 6-3/4 Formations _ Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (1) (�) 8,602.50 7,160.95 TD (T-110) 0.00 7,855.18 6,425.41 T-65 4,736.72 3,356.25 Beluga 120 4,119.90 2,781.56 Beluga 90A 8,171.07 6,736.32 T-83 2,563.67 1,790.78 Beluga 44 3,110.98 2,072.18 Beluga 52 6,036.38 4,635.27 T-12 3,978.06 2,661.08 Beluga 80 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +E/-W (usft) (usft) (usft) (usft) Comment 200.00 200.00 0.00 0.00 Start Dir 40/100' : 200' MD, 200'TVD 1,000.00 959.05 22.75 -216.46 Start Dir 4.51/100' : 1000' MD, 959.05'TVD 1,767.81 1,452.65 96.13 -784.67 End Dir : 1767.81' MD, 1452.65' TVD 2,120.06 1,593.01 141.89 -1,104.49 Start Dir 41/100' : 2120.06' MD, 1593.017VD 3,170.27 2,103.60 595.39 -1,871.34 Start Dir 30/100' : 3170.27' MD, 2103.6'TVD 4,797.48 3,415.89 1,347.92 -2,321.95 End Dir : 4797.48' MD, 3415.89' TVD 8,602.55 7,161.00 2,008.54 -2,449.45 Total Depth: 8602.55' MD, 7161' TVD 111712022 6:26:57PM Page 6 COMPASS 5000.15 Build 91E Hilcorp Alaska, LLC Ninilchik Unit Kalotsa Kalotsa 8 Kalotsa 8 Kalotsa 8 wp08 Stnnrry Drilling Services Clearance Summary Anticollision Report 17 January, 2022 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: Kalotsa - Kalotsa 8 - Kalotsa 8 - Kalotsa 8 wp08 Well Coordinates: 2,233,354.75 N, 209,768.46 E (60° 06' 13.67" N, 151' 35' 25.94" W) Datum Height: As -Built RKB @ 144.60usft (HEC 169) Scan Range: 0.00 to 8,602.55 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.15 Build: 91E Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for Kalotsa 8 - Kalotsa 8 wp08 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: Kalotsa - Kalotsa 8 - Kalotsa 8 - Kalotsa 8 wp08 Scan Range: 0.00 to 8,602.55 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kalotsa Kalotsa 1 - Kalotsa 1 - Kalotsa 1 Kalotsa 1 - Kalotsa 1 - Kalotsa 1 Kalotsa 1 - Kalotsa 1 - Kalotsa 1 Kalotsa 2 - Kalotsa 2 - Kalotsa 2 Kalotsa 2 - Kalotsa 2 - Kalotsa 2 Kalotsa 2 - Kalotsa 2 - Kalotsa 2 Kalotsa 3 - Kalotsa 3 - Kalotsa 3 Kalotsa 3 - Kalotsa 3 - Kalotsa 3 Kalotsa 3 - Kalotsa 3 - Kalotsa 3 Kalotsa 4 - Kalotsa 4 - Kalotsa 4 Kalotsa 4 - Kalotsa 4 - Kalotsa 4 Kalotsa 4 - Kalotsa 4 - Kalotsa 4 Kalotsa 5 - Kalotsa 5 - Kalotsa 5 Kalotsa 5 - Kalotsa 5 - Kalotsa 5 Kalotsa 5 - Kalotsa 5 - Kalotsa 5 Kalotsa 6 - Kalotsa 6 - Kalotsa 6 Kalotsa 6 - Kalotsa 6 - Kalotsa 6 Kalotsa 6 - Kalotsa 6 - Kalotsa 6 Kalotsa 7 - Kalotsa 7 - Kalotsa 7 Kalotsa 7 - Kalotsa 7 - Kalotsa 7 Kalotsa 7 - Kalotsa 7 - Kalotsa 7 Paxton Paxton #4 - Paxton #4 - Paxton #4 Paxton #4 - Paxton #4 - Paxton #4 Paxton #4 - Paxton #4 - Paxton #4 Hilcorp Alaska, LLC Ninilchik Unit Separation Warning 202.69 140.97 202.69 139.06 202.70 74.072 Centre Distance Pass - 225.00 141.08 225.00 139.04 224.47 68.977 Ellipse Separation Pass - 8,602.55 565.04 8,602.55 491.85 8,252.13 7.720 Clearance Factor Pass - 18.00 171.02 18.00 169.79 18.00 139.111 Centre Distance Pass - 200.00 171.30 200.00 169.42 199.37 91.295 Ellipse Separation Pass - 775.00 240.34 775.00 234.61 758.29 41.908 Clearance Factor Pass - 18.00 201.96 18.00 200.73 18.00 164.278 Centre Distance Pass - 125.00 202.18 125.00 200.63 124.05 130.472 Ellipse Separation Pass - 900.00 343.18 900.00 336.31 822.50 49.957 Clearance Factor Pass - 200.56 229.03 200.56 227.14 200.49 121.420 Centre Distance Pass - 225.00 229.11 225.00 227.07 224.84 112.094 Ellipse Separation Pass - 4,550.00 390.88 4,550.00 339.74 4,264.50 7.644 Clearance Factor Pass - 232.06 52.65 232.06 49.98 232.66 19.747 Centre Distance Pass - 250.00 52.71 250.00 49.94 250.57 19.066 Ellipse Separation Pass - 825.00 74.12 825.00 66.83 819.40 10.167 Clearance Factor Pass - 215.04 99.52 215.04 96.95 215.41 38.685 Centre Distance Pass - 225.00 99.54 225.00 96.92 225.26 37.950 Ellipse Separation Pass - 725.00 161.88 725.00 155.76 714.37 26.422 Clearance Factor Pass - 18.00 206.63 18.00 204.90 18.00 119.496 Centre Distance Pass - 6,050.00 255.01 6,050.00 196.16 5,622.66 4.333 Ellipse Separation Pass - 6,150.00 262.76 6,150.00 200.96 5,711.62 4.252 Clearance Factor Pass - 2,271.10 256.32 2,271.10 208.25 4,313.72 5.333 Centre Distance Pass - 2,325.00 262.24 2,325.00 203.10 4,311.32 4.434 Ellipse Separation Pass - 2,400.00 288.57 2,400.00 217.80 4,310.98 4.078 Clearance Factor Pass - 17 January, 2022 - 18:28 Page 2 of 5 COMPASS Hilcorp Alaska, LLC HALLIBURTON Anticollision Report for Kalotsa 8 - Kalotsa 8 wp08 Survey tool program From To Survey/Plan (usft) (usft) 18.00 2,269.00 Kalotsa 8 wp08 2,269.00 8,602.55 Kalotsa 8 wp08 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey Tool 3_MWD+IFR1+MS+Sag 3_MWD+IFR1+MS+Sag Ninilchik Unit 17 January, 2022 - 18:28 Page 3 of 5 COMPASS Project: Ninilchik Unit REFERENCE INFORMATION WELL DETAILS:Kalotsa 8 NAD 1927 (NADCON CONUS) Alaska Zone 04 HALLIBUI�'f�R! Site: Kalotsa Co-ordinate (N/E) Reference: Well Kalotsa 8, True North B perry Orilltng Well: Kalotsa 8 Vertical (TVD) Reference: As -Built RKB @ 144.60usft (HEC 169) 126.60 Wellbore: Kalotsa 8 Measured Depth Reference: As -Built RKB @ 144.60usft (HEC 169) +N/-S +E/-W Northing Easting Latitude Longitude Calculation Method: Minimum Curvature 0.00 0.00 2233354.75 209768.46 60' 6' 13.670 N 151 o 35' 25.937 W Plan: Kalotsa 8 wp08 SURVEY PROGRAM GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Date: 2022-01-17T00:00:00 Validated: Yes Version: 18.00 To 8602.55 CASING DETAILS Depth From Depth To Survey/Plan Tool M 18.00 2269.00 Kalotsa 8 wp08 (Kalotsa 8) 3_MWD+IFRI+MS+Sag TVD TVDSS N D Size Name 2269.00 8602.55 Kalotsa 8 wp08 (Kalotsa 8) 3_MWD+IFRI+MS+Sag 1655.00 1510.40 2269.10 7-5/8 7 5/8" Casing 7161.00 7016.40 8602.55 4-1/2 4 1/2" Casing 180.00 a a � 50.00 s 0 0 0 ly cm20.00 o alta 1090.00 a) U) a) to (D60.00 0 0 c30.00 s 5 U 0.00 0 475 950 1425 1900 2375 2850 3325 3800 4275 4750 5225 5700 6175 6650 7125 7600 8075 8550 9025 Measured Depth (950 usft/in) 4.00 0 v 3.00 ro LL Collision Risk Procedure c 2.00 a Collision Avoidance Re ulre a1 No -Go Zone - Stop Drilling 1.00 NOERROR 0.00 1 $91 2 I' I 0 475 950 1425 1900 2375 2850 3325 3800 4275 4750 5225 5700 6175 6650 7125 7600 8075 8550 9025 Measured Depth (950 usft/in) Rig 147 and 169 Diverter Stackup 16" casii below c TRANSMITTAL LETTER CHECKLIST WELL NAME: Kalotsa 8 PTD: 222-003 Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: Ninilchik POOL: Beluga/Tyonek Gas Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both Pilot Hole well name ( PH) and API number (50- ) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Approval to produce/inject is contingent upon issuance of Exception a conservation order approving a spacing exception. ( ) as Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non- well ( ) until after ( ) Conventional has designed and implemented a water well testing program to provide Well baseline data on water quality and quantity. ( ) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by ( ) in the attached application, the following well logs are also required for this well: Well Logging Requirements 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. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool NINILCHIK, BELUGA-TYONEK GAS - 562503 Well Name: NINILCHIK UNIT KALOTSA 8 Program DFV Well bore seg ❑ PTD#: 2220030 Company Hilcorp Alaska, LLC Initial Class/Type DFV / PFND GeoArea 820 Unit 51432 On/Off Shore On Annular Disposal ❑ Administration 1 Permitfeeattached ----------------------------------------------NA---------------------------------------------------------------------------- 2 Leasenumberappropriate----------------------------------- - - - - -- Yes - - - - - -- Surface location -on Fee-ClRlproperty;topprodintervalandTDdnARL38-437-2----------------------- 3 Uniquewellnameandnumber--------------------------------------- Yes --------------------------------------------------------------------- - - - - -- 4 -Well located in a defined pool ---------------------------------------Yes-------NINILCHIK,BELUGA-TYONEK GAS _-562503,-governedby CO._701C--------------------------- 5 -Well located proper distance from drilling unitboundary- - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - CO 701C, Rule 3 yVe[I Spacing:-Asp[anned, this well conforms to-CQ 7010, Rule 3 (YVell Spacings - - - - - - - - - - - 6 -Well located proper distance from otherwells------------------------- - - - - -- Yes --------------------------------------------------------------------------- 7 Sufficient acreage available in drilling unit- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 Ifdevdated. iswellbore-platincluded------------------------------------ Yes --------------------------------------------------------------------- - - - - -- 9 Operator onlyaffecled-pam=---------------------------------------- Yes --------------------------------------------------------------------- - - - - -- 10 Operator has appropriate bond-inforce---------------------------------- Yes --------------------------------------------------------------------- - - - - -- 11 Permitcan be issued without conservation order- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 Permitcan be issued withoutadministrative-approval - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 13 Can permit be approved before 15-day wait - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - SFD 1/19/2022 14 -Well locatedwithinareaandstrata authQrizedby-Injection Order#(put10#incomments)(Forserv-NA---------------------------------------------------------------------------- 15 All wells -within 1/4mile area Qfreviewidentified(For service well only)-----------------NA---------------------------------------------------------------------------- 16 Pre -produced injector:- durationQfpre-production less tban3-months(Forservice-well only)-----NA---------------------------------------------------------------------------- 17 _Nonconven.-gasconforms-toAS31.05.030(1.1-.A).0.2.A-D)------------------------NA---------------------------------------------------------------------------- 18 Conductor string provided------------------------------------------ Yes --------------------------------------------------------------------- - - - - - - Engineering 19 Surface -casing prolectsaUknown USDWs-------------------------------- Yes --------------------------------------------------------------------------- 20 CMT_voladequate tocirculate Qn-conductor_& surf csg_________________________ Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 21 CMT_vol adequate to tie-in long -string to surf csg- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT_willcover all known productive horizons - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 23 Casing designs adequate -for C, T,_B & permafro-st - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate lankag_e-or reserve -pit-------------------------------------- Yes --------------------------------------------------------------------------- 25-If are-drill,has a 10-403_forabandonmentbeen approved - - - - - - - - - - - - - - - - - - - - - - - -NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 Adequate weUbore_separationproposed --------------------------------- Yes --------------------------------------------------------------------------- 27 If d[veder required, does it meet regulations- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 28 Drillingfluidprogramscbematic&equip_listadequate- - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - BJM1/24/2022 29 BOP1=s,dothey meet regulation -------------------------------------- Yes --------------------------------------------------------------------------- 30 BOPI=_press rating appropriate; testlQ (putpsig in -comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Pressure rated to 5000_psi, MPSP 1000_psi_(BOP test tQ 3500 psi) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 Choke_manifQldcomp6esw/APIRP-53(May 84)----------------------------- Yes --------------------------------------------------------------------------- 32 _Work willoccurwitboutop-erationshutdo_wn-------------------------- - - - - -- Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is_ presence -of H2Sgas probable ---------------------------------------No--------------------------------- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 34 _Mechanical condition of wells within AOR verified (For_service well -only) - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 35 Permitcan be issuedw/_ohydrogensulfiidemeasures-------------------- - - - - -- Yes-------H2Sisnotanticipatedbased on nearby wells.------------------------------------------ Geology 36 Data -presented Qn-p-otentia[ Qverpressure-zones- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Maximum expected reservoir pressure is-8.9 ppg I=MW; however, most sands encountered are -expected - - - - - - - - Appr Date 37 Seismic analysis of shallow -gas zones- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -NA- - - - - - - - to be depleted -to severely depleted. Production interval will be drilled -using 9.5 to-10,0-ppg mud. - - - - - - - - - - - - - SFD 1/19/2022 38 Seabed condition survey of -off -shore) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -NA- - - - - - - - Additional materials will be-onsite tQ build mudto 1 ppg more than the greatest anticipated mudwedght. - - - - - - - - - 39 Contact name/phone for -weekly- progress reports [exploratory-onlyl - - - - - - - - - - - - - - - - - - NA- - - - - - - - Lost circulation material will also be -available onsite. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date dts 1/25/2022 JLC 1/25/2022 JMP 1/25/22