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Home My WebLink About220-003Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 03/17/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230317 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU L-57 50029236090000 218072 3/7/2023 READ CaliperSurvey SRU 23-33 50133101630000 161019 2/16/2023 AK E-LINE Jet Cut CLU-9 50133205440000 204161 2/24/2023 HALLIBURTON PPROF CLU-15 50133206870000 220003 2/26/2023 HALLIBURTON PPROF END 1-11 50029221070000 190157 2/19/2023 HALLIBURTON MFC END 1-11 50029221070000 190157 2/25/2023 HALLIBURTON PLUG-PERF KU 14X-06 50133203420000 181092 3/1/2023 HALLIBURTON LDL Please include current contact information if different from above. CLU-15 50133206870000 220003 2/26/2023 HALLIBURTON PPROF 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: 06/14/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL CLU 15 (PTD 220-003) PERF 04/25/2022 PERF 05/06/2022 Please include current contact information if different from above. PTD:220-003 T36701 T36700 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.17 10:24:05 -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: 5/09/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL CLU 15 (PTD 220-003) Perf 4/16/2022 Please include current contact information if different from above. PTD:220-003 T36579 Kayla Junke Digitally signed by Kayla Junke Date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a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y Samantha Carlisle at 2:52 pm, Apr 11, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH 6)' 3HUIRUDWH '65 %-0 GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.04.12 13:48:59 -08'00' RBDMS SJC 041422 tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗>hηϭϱ ĂƚĞ͗ϰͬϳͬϮϬϮϮ tĞůůEĂŵĞ͗>hηϭϱW/EƵŵďĞƌ͗ϱϬͲϭϯϯͲϮϬϲϴϳͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗&ůŽǁŝŶŐ'ĂƐtĞůů>ĞŐ͗Eͬ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ƉƌŝůϮϭ͕ϮϬϮϮZŝŐ͗ͲůŝŶĞ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌϳϳϳͲϴϯϬϱWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϮϬͲϬϬϯ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿϳϳϳͲϴϰϬϱ;KͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;Ϳ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶZƵƉĞƌƚ;ϵϬϳͿϳϳϳͲϴϱϬϯ;KͿ;ϵϬϳͿϯϬϭͲϭϳϯϲ;Ϳ &EƵŵďĞƌ͗ Current Bottom Hole Pressure: 3,396 psi @ 7,337’ TVD Based on A-15 RFT data of LB 3B sand on 4/2020 Maximum Expected BHP: 3,396 psi @ 7,337’ TVD Based on A-15 RFT data of LB 3B sand on 4/2020 Maximum Potential Surface Pressure: ~2,662 psi @ 7,337’ TVD Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) ƌŝĞĨtĞůů^ƵŵŵĂƌǇ >hηϭϱŝƐĂŐĂƐǁĞůůĚƌŝůůĞĚŝŶϮϬϮϬƚĂƌŐĞƚŝŶŐŐĂƐƐĂŶĚƐŝŶƚŚĞĞůƵŐĂĨŽƌŵĂƚŝŽŶĂƚĂŶŶĞƌǇůŽŽƉhŶŝƚ͘dŚĞǁĞůů ŚĂƐďĞĞŶŽŶůŝŶĞƐŝŶĐĞϮϬϮϬƉƌŽĚƵĐŝŶŐĨƌŽŵƚŚĞĞůƵŐĂƐĂŶĚƐ͘ dŚĞƉƵƌƉŽƐĞŽĨƚŚŝƐǁŽƌŬͬƐƵŶĚƌǇŝƐƚŽĂĚĚƉĞƌĨŽƌĂƚŝŽŶƐŝŶƚŚĞůŽǁĞƌĂŶĚƵƉƉĞƌďĞůƵŐĂƐĂŶĚƐ͘dŚĞƚŽƉƉƌŽƉŽƐĞĚ ƉĞƌĨŝŶƚŚŝƐĂƉƉůŝĐĂƚŝŽŶŝƐϭϴϳ͛dsĨƌŽŵƚŚĞďŽƚƚŽŵŽĨ/E'^^ƚŽƌĂŐĞWŽŽů͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ xƵƌƌĞŶƚdͬ/ͬKсϭϵϲͬϭϲϬͬϬ xƵƌƌĞŶƚĨůŽǁƌĂƚĞŽĨϭ͘ϰŵƐŵĐĨĚĂŶĚϰďǁƉĚ xϰͲϭͬϮ͟DŽŶŽďŽƌĞĐŽŵƉůĞƚŝŽŶ x/E'^WŽŽůďŽƚƚŽŵʹϳ͕ϲϰϭ͛;ϱ͕ϭϳϳ͛dsͿ x^>dĂŐĚĞƉƚŚʹϵ͕ϴϲϮ͛;ϰͬϰͬϮϬϮϮͿ Ͳ>ŝŶĞWƌŽĐĞĚƵƌĞ ϭ͘D/ZhĞͲůŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ Ϯ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬ>Žǁͬϯ͕ϱϬϬƉƐŝ,ŝŐŚ ϯ͘WhZ/,tͬƉĞƌĨŐƵŶƐ͘WĞƌĨŽƌĂƚĞĞĂĐŚŝŶƚĞƌǀĂůǁŝƚŚϲƚŽϭϮ^W&ϲϬĚĞŐƌĞĞƉŚĂƐŝŶŐ,ŐƵŶƐ ϰ͘WƌŽƉŽƐĞĚWĞƌĨŽƌĂƚĞĚ/ŶƚĞƌǀĂůƐ͗ WŽŽůEĂŵĞ ^ĂŶĚDdŽƉDŽƚƚŽŵ dŽƚĂů &ŽŽƚĂŐĞ ;DͿ dsdŽƉdsŽƚƚŽŵ ĞůƵŐĂ'ĂƐhϯцϳ͕ϴϯϯΖцϳ͕ϴϰϬΖϳΖцϱ͕ϯϲϰ͛цϱ͕ϯϳϭ͛ ĞůƵŐĂ'ĂƐhϰDŝĚцϳ͕ϴϲϮ͛цϳ͕ϴϲϱ͛ϯцϱ͕ϯϵϯ͛цϱϯϵϱ͛ ĞůƵŐĂ'ĂƐhϰ>ŽǁĞƌцϳ͕ϴϳϮцϳ͕ϴϳϵϳ͛цϱ͕ϰϬϮ͛цϱ͕ϰϬϵ͛ ĞůƵŐĂ'ĂƐhϰцϳ͕ϵϬϰΖцϳ͕ϵϭϰΖϭϬΖцϱ͕ϰϯϯ͛цϱ͕ϰϰϯ͛ ĞůƵŐĂ'ĂƐDϳцϴ͕ϵϴϴΖцϵ͕ϬϬϴΖϮϬΖцϲ͕ϰϴϯ͛цϲ͕ϱϬϮ͛ ĞůƵŐĂ'ĂƐ>ϭцϵ͕ϭϳϳΖцϵ͕ϭϴϮΖϱΖцϲ͕ϲϲϲ͛цϲ͕ϲϳϭ͛ ĞůƵŐĂ'ĂƐ>ϭцϵ͕ϮϬϳ͛цϵ͕ϮϭϬ͛ϯ͛цϲ͕ϲϵϱ͛цϲ͕ϲϵϴ͛ ĞůƵŐĂ'ĂƐ>ϭ>цϵ͕ϮϴϮΖцϵ͕ϮϴϴΖϲΖцϲ͕ϳϲϴ͛цϲ͕ϳϳϰ͛ &LQJVD SRRO LV FHPHQWHG EHKLQG WKH FDVLQJ 3HUIV ZLOO EH EHORZ WKH FDVLQJ VKRH LQ WKH EMP /E'^WŽŽůďŽƚƚŽŵʹϳ͕ϲϰϭ͛;ϱ͕ϭϳϳ͛dsͿ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗>hηϭϱ ĂƚĞ͗ϰͬϳͬϮϬϮϮ ĞůƵŐĂ'ĂƐ>ϭ&>цϵ͕ϯϰϮΖцϵ͕ϯϱϭΖϵΖцϲ͕ϴϮϲ͛цϲ͕ϴϯϰ͛ ĞůƵŐĂ'ĂƐ>Ϯцϵ͕ϰϭϱΖцϵ͕ϰϭϵΖϰΖцϲ͕ϴϵϲ͛цϲ͕ϵϬϬ͛ Ă͘3URSRVHGSHUIVDUHDOVRVKRZQRQWKHSURSRVHGVFKHPDWLFLQUHGIRQW E )LQDO3HUIVWLHLQVKHHWZLOOEHSURYLGHGLQWKHILHOGIRUH[DFWSHUILQWHUYDOV F &RUUHODWHXVLQJ2SHQ+ROH&RUUHODWLRQ/RJSURYLGHGE\*HRORJLVW6HQGWKHFRUUHODWLRQSDVV WRWKH2SHUDWLRQV(QJLQHHU5HVHUYRLU(QJLQHHU&KULV.DQ\HUDQG*HRORJLVW'DQLHO <DQFH\IRUFRQILUPDWLRQ d. Use Gamma/CCL to correlate H ,QVWDOO&U\VWDOJDXJHVRUYHULI\37VDUHRSHQWR6&$'$EHIRUHSHUIRUDWLQJ5HFRUGWXELQJ SUHVVXUHVEHIRUHDQGDIWHUHDFKSHUIRUDWLQJUXQDWPLQPLQDQGPLQLQWHUYDOVSRVW VKRW I 7KHVHVDQGVDUHJRYHUQHGE\&RQVHUYDWLRQ2UGHU$ J 6DQGLQWHUYDOVPD\EHJURXSHGRUVKRWRQHDWDWLPHDQGIORZWHVWHGWRWKHV\VWHPSHUWKH 2(GLUHFWLRQ ϱ͘WKK, ϲ͘ZĞͲůŝŶĞ ϳ͘dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶƚŽƚĞƐƚ ͲůŝŶĞWƌŽĐĞĚƵƌĞ;ŽŶƚŝŶŐĞŶĐǇͿ͗/ĨĂŶǇǌŽŶĞƉƌŽĚƵĐĞƐƐĂŶĚĂŶĚͬŽƌǁĂƚĞƌ͘ ϭ͘D/ZhͲůŝŶĞ͕WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬ>Žǁͬϯ͕ϬϬϬƉƐŝ,ŝŐŚ Ϯ͘Z/,ĂŶĚƐĞƚϰͲϭͬϮ͟/W;ŽƌƚƵďŝŶŐƉĂƚĐŚͿ͘^ĞƚĂƚĚĞƉƚŚƐƉĞĐŝĨŝĞĚďǇŶŐŝŶĞĞƌ͘ ϯ͘Zh^ůŝĐŬůŝŶĞ͘^ǁĂďĨůƵŝĚĚŽǁŶƚŽĚĞƉƚŚĂƉƉƌŽǀĞĚďǇŶŐŝŶĞĞƌ͘ Ă͘/ĨŶĞĐĞƐƐĂƌǇZ/,ǁŝƚŚďĂŝůĞƌĂƐƐĞŵďůǇ͘ƵŵƉďĂŝůĐĞŵĞŶƚŽŶ/W͘ ϰ͘WKK,͕ZDK ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ƵƌƌĞŶƚtĞůů^ĐŚĞŵĂƚŝĐ Ϯ͘WƌŽƉŽƐĞĚtĞůů^ĐŚĞŵĂƚŝĐ &RQVHUYDWLRQ2UGHU$ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ:ϬϲͲϭϰͲϮϬ ^,Dd/ ĂŶŶĞƌǇ>ŽŽƉhŶŝƚ tĞůů͗>hηϭϱ Wd͗ϮϮϬͲϬϬϯ W/η͗ϱϬͲϭϯϯͲϮϬϲϴϳͲϬϬͲϬϬ ^/E'd/> ^ŝǌĞdǇƉĞtƚͬ'ƌĂĚĞͬŽŶŶ/dŽƉƚŵ ϭϲΗŽŶĚƵĐƚŽƌϭϬϵͬyͲϱϲͬtĞůĚϭϱ͟^ƵƌĨϭϮϬ͛ ϭϬͲϯͬϰ͟^ƵƌĨĂĐĞϰϱ͘ϱͬ>ͲϴϬͬtϵ͘ϵϱϬ͟^ƵƌĨϮ͕ϭϰϰ͛ ϳͲϱͬϴΗ/ŶƚĞƌŵĞĚŝĂƚĞϮϵ͘ϳͬ>ͲϴϬͬtϲ͘ϴϳϱ͟^ƵƌĨϳ͕ϳϵϬ͛ ϰͲϭͬϮΗWƌŽĚƵĐƚŝŽŶϭϮ͘ϲͬ>ͲϴϬͬtϯ͘ϵϱϴ͟^ƵƌĨϭϬ͕ϱϬϮ͛ :t>Zzd/> EŽĞƉƚŚ /ƚĞŵ ϭϲ͕ϰϭϲ͛ϰͲϭͬϮ͟^ǁĞůůWĂĐŬĞƌ KWE,K>ͬDEdd/> ϭϬͲϯͬϰ͟>ʹϯϳϱƐǆdʹϮϳϱƐǆϯϱďďůƐƌĞƚƵƌŶĞĚƚŽƐƵƌĨĂĐĞ͘/ŶũĞĐƚĞĚĨŝ ŶĞĐĞŵ ŝŶĂŶŶƵůƵƐϭϯϱƐǆĚŽƚŽƚŝĚĂůǁĂƐŚŽƵƚ͘ ϳͲϱͬϴΗ ĞŵĞŶƚŝŶϵͲϳͬϴ͟,ŽůĞ͘WƵŵƉĞĚϱϴϱ^ǆ͘;ϮϮϱďďůƐ͘ϭϮƉƉŐĐůĂƐƐ ĨŽůůŽǁĞĚďǇϮϰϱ^ǆ͘;ϱϯďďůƐ͘Ϳϭϱ͘ϯƉƉŐůĂƐƐ͘dKΛϯ͕ϲϳϱ͘ ϰͬϭϲͬϮϬ ϰͲϭͬϮΗ>ͲϮϱϬƐǆdʹϴϱƐǆŝŶϲͲϯͬϰ͟ŚŽůĞƐƚdKϲϰϭϰ͛D WZ&KZd/KEd/> ^ĂŶĚdŽƉDƚŵDdŽƉdsƚŵds&ƚĂƚĞŽŵŵĞŶƚƐ >ϭ&ϵ͕ϯϮϵ͛ϵ͕ϯϯϱ͛ϲ͕ϴϭϯΖϲ͕ϴϭϵΖϲΖϱͬϮϳͬϮϬϮͲϳͬϴ͟ >ϭ'ϵ͕ϯϴϵΖϵ͕ϰϬϲΖϲ͕ϴϳϭΖϲ͕ϴϴϳΖϭϳΖϱͬϮϳͬϮϬϮͲϳͬϴ͟ >Ϯϵ͕ϱϭϬΖϵ͕ϱϯϬΖϲ͕ϵϵϱΖϳ͕ϬϬϴΖϮϬΖϱͬϮϳͬϮϬϮͲϳͬϴ͟ >ϯϵ͕ϳϳϴΖϵ͕ϳϴϳΖϳ͕ϮϰϴΖϳ͕ϮϱϳΖϵΖϱͬϭϯͬϮϬϮͲϳͬϴ͟ >ϯϵ͕ϴϯϲΖϵ͕ϴϱϬΖϳ͕ϯϬϱΖϳ͕ϯϭϴΖϭϰΖϱͬϭϯͬϮϬϮͲϳͬϴ͟ >ϯϵ͕ϴϲϬΖϵ͕ϴϴϲΖϳ͕ϯϮϴΖϳ͕ϯϱϰΖϮϲΖϱͬϭϯͬϮϬϮͲϳͬϴ͟ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ,ϬϰͬϬϳͬϮϮ WZKWK^ ĂŶŶĞƌǇ>ŽŽƉhŶŝƚ tĞůů͗>hηϭϱ Wd͗ϮϮϬͲϬϬϯ W/η͗ϱϬͲϭϯϯͲϮϬϲϴϳͲϬϬͲϬϬ ^/E'd/> ^ŝǌĞdǇƉĞtƚͬ'ƌĂĚĞͬŽŶŶ/dŽƉƚŵ ϭϲΗŽŶĚƵĐƚŽƌϭϬϵͬyͲϱϲͬtĞůĚϭϱ͟^ƵƌĨϭϮϬ͛ ϭϬͲϯͬϰ͟^ƵƌĨĂĐĞϰϱ͘ϱͬ>ͲϴϬͬtϵ͘ϵϱϬ͟^ƵƌĨϮ͕ϭϰϰ͛ ϳͲϱͬϴΗ/ŶƚĞƌŵĞĚŝĂƚĞϮϵ͘ϳͬ>ͲϴϬͬtϲ͘ϴϳϱ͟^ƵƌĨϳ͕ϳϵϬ͛ ϰͲϭͬϮΗWƌŽĚƵĐƚŝŽŶϭϮ͘ϲͬ>ͲϴϬͬtϯ͘ϵϱϴ͟^ƵƌĨϭϬ͕ϱϬϮ͛ :t>Zzd/> EŽĞƉƚŚ/ƚĞŵ ϭϲ͕ϰϭϲ͛ϰͲϭͬϮ͟^ǁĞůůWĂĐŬĞƌ KWE,K>ͬDEdd/> ϭϬͲϯͬϰ͟>ʹϯϳϱƐǆdʹϮϳϱƐǆϯϱďďůƐƌĞƚƵƌŶĞĚƚŽƐƵƌĨĂĐĞ͘/ŶũĞĐƚĞĚĨŝŶĞĐĞŵ ŝŶĂŶŶƵůƵƐϭϯϱƐǆĚŽƚŽƚŝĚĂůǁĂƐŚŽƵƚ͘ ϳͲϱͬϴΗ ĞŵĞŶƚŝŶϵͲϳͬϴ͟,ŽůĞ͘WƵŵƉĞĚϱϴϱ^ǆ͘;ϮϮϱďďůƐ͘ϭϮƉƉŐĐůĂƐƐ ĨŽůůŽǁĞĚďǇϮϰϱ^ǆ͘;ϱϯďďůƐ͘Ϳϭϱ͘ϯƉƉŐůĂƐƐ͘dKΛϯ͕ϲϳϱ͘ ϰͬϭϲͬϮϬ ϰͲϭͬϮΗ>ͲϮϱϬƐǆdʹϴϱƐǆŝŶϲͲϯͬϰ͟ŚŽůĞdKϲϵϬϰ͛DϱͬϱͬϮϬ WZ&KZd/KEd/> ^ĂŶĚdŽƉDƚŵDdŽƉdsƚŵds&ƚĂƚĞŽŵŵĞŶƚƐ hϯцϳ͕ϴϯϯΖцϳ͕ϴϰϬΖцϱ͕ϯϲϰ͛цϱ͕ϯϳϭ͛ϳΖdWƌŽƉŽƐĞĚ hϰDŝĚцϳ͕ϴϲϮ͛цϳ͕ϴϲϱ͛цϱ͕ϯϵϯ͛цϱϯϵϱ͛ϯdWƌŽƉŽƐĞĚ hϰ>ŽǁĞƌцϳ͕ϴϳϮцϳ͕ϴϳϵцϱ͕ϰϬϮ͛цϱ͕ϰϬϵ͛ϳ͛dWƌŽƉŽƐĞĚ hϰцϳ͕ϵϬϰΖцϳ͕ϵϭϰΖцϱ͕ϰϯϯ͛цϱ͕ϰϰϯ͛ϭϬΖdWƌŽƉŽƐĞĚ Dϳ>ŽǁĞƌцϴ͕ϵϴϴΖцϵ͕ϬϬϴΖцϲ͕ϰϴϯ͛цϲ͕ϱϬϮ͛ϮϬΖdWƌŽƉŽƐĞĚ >ϭцϵ͕ϭϳϳΖцϵ͕ϭϴϮΖцϲ͕ϲϲϲ͛цϲ͕ϲϳϭ͛ϱΖdWƌŽƉŽƐĞĚ >ϭцϵ͕ϮϬϳ͛цϵ͕ϮϭϬ͛цϲ͕ϲϵϱ͛цϲ͕ϲϵϴ͛ϯ͛dWƌŽƉŽƐĞĚ >ϭ>цϵ͕ϮϴϮΖцϵ͕ϮϴϴΖцϲ͕ϳϲϴ͛цϲ͕ϳϳϰ͛ϲΖdWƌŽƉŽƐĞĚ >ϭ&ϵ͕ϯϮϵ͛ϵ͕ϯϯϱ͛ϲ͕ϴϭϯΖϲ͕ϴϭϵΖϲΖϱͬϮϳͬϮϬϮͲϳͬϴ͟ >ϭ&>цϵ͕ϯϰϮΖцϵ͕ϯϱϭΖцϲ͕ϴϮϲ͛цϲ͕ϴϯϰ͛ϵΖdWƌŽƉŽƐĞĚ >ϭ'ϵ͕ϯϴϵΖϵ͕ϰϬϲΖϲ͕ϴϳϭΖϲ͕ϴϴϳΖϭϳΖϱͬϮϳͬϮϬϮͲϳͬϴ͟ >Ϯцϵ͕ϰϭϱΖцϵ͕ϰϭϵΖцϲ͕ϴϵϲ͛цϲ͕ϵϬϬ͛ϰΖdWƌŽƉŽƐĞĚ >Ϯϵ͕ϱϭϬΖϵ͕ϱϯϬΖϲ͕ϵϵϱΖϳ͕ϬϬϴΖϮϬΖϱͬϮϳͬϮϬϮͲϳͬϴ͟ >ϯϵ͕ϳϳϴΖϵ͕ϳϴϳΖϳ͕ϮϰϴΖϳ͕ϮϱϳΖϵΖϱͬϭϯͬϮϬϮͲϳͬϴ͟ >ϯϵ͕ϴϯϲΖϵ͕ϴϱϬΖϳ͕ϯϬϱΖϳ͕ϯϭϴΖϭϰΖϱͬϭϯͬϮϬϮͲϳͬϴ͟ >ϯϵ͕ϴϲϬΖϵ͕ϴϴϲΖϳ͕ϯϮϴΖϳ͕ϯϱϰΖϮϲΖϱͬϭϯͬϮϬϮͲϳͬϴ͟ &HPHQW TXDOLW\ LV SRRU WKURXJK PRVW RI WKH OLQHU EMP 3URSRVHGSHUIVDUHPRUH WKDQ 79'EHORZWKH EDVHRIWKHJDVVWRUDJHSRRO 6)' 79' 6)' 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 and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company CLU 05RD 501332047401 215160 6/15/2021 SET PLUG Yellowjacket CLU-06RD 501332049201 220074 1/26/2021 PERF Yellowjacket CLU-06RD 501332049201 220074 1/28/2021 GPT Yellowjacket CLU 14 501332068400 219078 7/23/2020 SET PLUG/PERF Yellowjacket CLU-15 501332068700 220003 5/27/2020 PERF Yellowjacket Please include current contact information if different from above. 06/28/2021 eceived By: 37' (6HW By Abby Bell at 11:55 am, Jun 28, 2021 1a. Test:Initial Annual Special 1b. Type Test:Stabilized Non Stabilized Multipoint Constant Time Isochronal Other: 2. Operator Name:5. Date Completed:11.Permit to Drill Number: 3. Address:6. Date TD Reached:12.API Number: 4a. Location of Well (Governmental Section):7. KB Elevation above MSL (feet): 13.Well Name and Number: Surface: Top of Productive Horizon:8. Plug Back Depth(MD+TVD): 14.Field/Pool(s): Total Depth:9. Total Depth (MD + TVD): 4b. Location of Well (State Base Plane Coordinates NAD 27):10.Land Use Permit:15.Property Designation: Private Fee, Surface: x-y-Zone- 4 TPI:x-y-Zone- 4 16.Type of Completion (Describe): Total Depth: x-y-Zone- 4 17.Casing Size Weight per foot, lb. I.D. in inches Set at ft.19. Perforations:From 18.Tubing Size Weight per foot, lb. I.D. in inches Set at ft. 20.Packer set at ft:21.GOR cf/bbl: 22.API Liquid Hydrocardbons:23. Specific Gravity Flowing Fluid (G): 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure:24d. Barometric Pressure (Pa): Tubing Casing Fo psia @ Datum -7275 TVDSS psia 25.Length of Flow Channel (L): Vertical Depth (H):% N2:% H2S: 0 1.X 2.X 3.X 4.X 5.X 1. 2. 3. 4. 5. 1. 2. 3. 4. 5. for Separator Gas Gg for Flowing Fluid G z Gg: % CO2: Temp. Fo 10,502 To 9,778-9,787 9,836-9,850 9,869-9,886 April 19, 2020 N/A 10,511' MD / 7,959' TVD 9,329-9,335 9,389-9,406 9,510-9,530 10,418' MD / 7,868' TVD 53.0 2392000 2391727 ADL391791; 391792; 391790; 3246022 2539' FSL, 2464' FWL, Sec 4, T5N, R11W, SM, AK 4-1/2" Production String, Perforated CASING DATATUBING DATA Meter Run: Taps:Prover: 277440 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT Hilcorp Alaska, LLC 5/13/2020 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 220-003 Diff. Hw FLOW DATA 1630' FNL, 793' FEL, Sec 8, T5N, R11W, SM, AK 1905' FNL, 874' FEL, Sec 8, T5N, R11W, SM, AK 4-1/2"12.6 3.958 2396118280837 277525 No. Choke Orifice Size (in.) 6,416 119 1400 Temp. Fo Pressure psig 26. 0.06 0 Pressure psig Prover Line Size (in.) Flow Temp. Factor Ft Gravity Factor Fg Super Comp. Factor Fpv Duration of Flow Hr.X Basic Coefficient (24-Hour) Fb or Fp Pr Temperature T Tr No.hwPm Pressure Pm No. 50-133-20687-00-00 CLU 15 Cannery Loop Unit / Critical Pressure Critical Temperature Nodal__________ Beluga Gas Pool Rate of Flow Q1 Mcfd Temp. Fo Pressure psig Form 10-421 Rev. 7/2009 CONTINUED ON REVERSE SIDE Submit in DuplicateRBDMS HEW 12/2/2020 Pc Pc2 Pf Pf2 Pt2 Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Ps2 Pf2-Ps2 AOF (Mcfd)n Remarks: I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Date 10/01/20 AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd/ hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= 1/Z dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells , Interstate Oil Compact Commission, Oklahoma City, Oklahoma. No. Pt DEFINITIONS OF SYMBOLS 25. 1,992 Anthony McConkey, Reservoir Engineer CLU-15 is flowing from the Lower Beluga 2B, 1G, & 1F sands. The IPR curves were created using Multi-rate C & N. Test data from 10/1/2020 was used for matching the data. CLU-15 produces water and requires soap to remain unloaded. The lack of pressure/rate data points (only two were used) and static SIBHP was due to risk of loading up the well. The reservoir pressure [1400psi] was back-calculated from the best fit IPR curve given the data collected. 5. 1. 2. 3. 4. Form 10-421 Revised 7/2009 Side 2 Digitally signed by Anthony McConkey DN: cn=Anthony McConkey, ou=Users Date: 2020.10.01 14:01:50 -08'00' Anthony McConkey Page 1Hilcorp Alaska, LLC. - untitled #################### # PVT INPUT DATA # #################### .................... . PVT INPUT DATA . .................... Reservoir Fluid Dry and Wet Gas Fluid Model Black Oil Separator Single-Stage Gas Gravity 0.563 (sp. gravity) Separator Pressure 150.00 (psig) Condensate Gas Ratio 0 (STB/MMscf) Condensate Gravity 52.00 (API) Water Gas Ratio 0 (STB/MMscf) Water Salinity 0 (ppm) Mole Percent H2S 0 (percent) Mole Percent CO2 0 (percent) Mole Percent N2 0 (percent) Gas Viscosity Correlation Lee et al PVT Matched No Use Tables No Page 2Hilcorp Alaska, LLC. - untitled ############################################### # BLACK OIL GAS PVT CORRELATIONS PARAMETERS # ###############################################Gas Viscosity Lee et al Carr et al Parameter 1 1 1 Parameter 2 0 0 Std deviation 0 0Z Factor Parameter 1 1 Parameter 2 0 Std deviation 0Gas FVF Parameter 1 1 Parameter 2 0 Std deviation 0 Page 3Hilcorp Alaska, LLC. - untitled ######################################## # INFLOW PERFORMANCE DATA (GAS WELL) # ######################################## Reservoir Model MultiRate C and n Reservoir Pressure 1399.68 (psig) Reservoir Temperature 119.00 (deg F) Water-Gas Ratio 0 (STB/MMscf) Condensate Gas Ratio 0 (STB/MMscf) Absolute Open Flow (AOF) 1.992 (MMscf/day) ++++++++++++++++++++++++++++++++++++++++++++++++++++++ + MULTIRATE TEST DATA AND DERIVED MODEL PARAMETERS + ++++++++++++++++++++++++++++++++++++++++++++++++++++++ Gas Rate Pressure (MMscf/day) (psig) ___________ ________ 1.349 828.79 1.905 299.79 C 0.0050862 (Mscf/day/psi2) n 0.88763 Page 4Hilcorp Alaska, LLC. - untitled +++++++++++++++++++++++++++++ + IPR Calculation Results + +++++++++++++++++++++++++++++ dP dP dP Sand Sand dP dP dP dP Total Total Completion Completion Control Control Perforation Damage Penetration Deviation Perforation Damage Penetration Rate Pressure Temperature Skin Skin Skin Skin Skin Skin Skin Skin Skin Skin Skin Skin Skin (MMscf/day) (psig) (deg F) (psi) (psi) (psi) (psi) (psi) (psi) (psi) ___________ ________ ___________ _____ _____ __________ __________ _______ _______ ___________ ______ ___________ _________ ________ 1e-5 1399.68 119.00 0 0 0 0 0 0 0 0 0 0 0 0 0 0.10488 1373.81 118.41 0 0 0 0 0 0 0 0 0 0 0 0 0 0.20974 1342.55 117.69 0 0 0 0 0 0 0 0 0 0 0 0 0 0.31461 1308.35 116.89 0 0 0 0 0 0 0 0 0 0 0 0 0 0.41948 1271.67 116.03 0 0 0 0 0 0 0 0 0 0 0 0 0 0.52435 1232.67 115.09 0 0 0 0 0 0 0 0 0 0 0 0 0 0.62921 1191.36 114.08 0 0 0 0 0 0 0 0 0 0 0 0 0 0.73408 1147.65 112.99 0 0 0 0 0 0 0 0 0 0 0 0 0 0.83895 1101.38 111.81 0 0 0 0 0 0 0 0 0 0 0 0 0 0.94381 1052.31 110.54 0 0 0 0 0 0 0 0 0 0 0 0 0 1.049 1000.13 109.14 0 0 0 0 0 0 0 0 0 0 0 0 0 1.154 944.39 106.13 0 0 0 0 0 0 0 0 0 0 0 0 0 1.258 884.50 102.56 0 0 0 0 0 0 0 0 0 0 0 0 0 1.363 819.62 98.58 0 0 0 0 0 0 0 0 0 0 0 0 0 1.468 748.52 94.08 0 0 0 0 0 0 0 0 0 0 0 0 0 1.573 669.33 88.89 0 0 0 0 0 0 0 0 0 0 0 0 0 1.678 578.86 82.74 0 0 0 0 0 0 0 0 0 0 0 0 0 1.783 470.91 75.13 0 0 0 0 0 0 0 0 0 0 0 0 0 1.888 329.45 64.83 0 0 0 0 0 0 0 0 0 0 0 0 0 1.992 1.10 43.55 0 0 0 0 0 0 0 0 0 0 0 0 0 Deviation Rate Skin (MMscf/day) ___________ _________ 1e-5 0 0.10488 0 0.20974 0 Page 5Hilcorp Alaska, LLC. - untitled 0.31461 0 0.41948 0 0.52435 0 0.62921 0 0.73408 0 0.83895 0 0.94381 0 1.049 0 1.154 0 1.258 0 1.363 0 1.468 0 1.573 0 1.678 0 1.783 0 1.888 0 1.992 0 Total Skin : 0 ( = Entered + Perforation + Damage + Deviation + Partial Penetration ) Completion Skin : 0 ( = Entered + Perforation + Damage + Sand Control ) Perforation Skin : 0 Damage Skin : 0 Penetration Skin : 0 Deviation Skin : 0 Sand Control Skin : 0 Calculated Non-Darcy Coefficent (Beta) : +++++++++++++++++++ + End of Report + +++++++++++++++++++ Gas Rate (MMscf/day)Pressure (psig)Temperature (deg F)0290580870116014504060801001201400 0.4 0.8 1.2 1.6 2IPR Pressure CurveIPR Temperature CurveMultiRate DataINFLOW PERFORMANCE DATA (GAS WELL)Inflow TypeSingle BranchCompletionCased HoleSand ControlNoneGas ConingReservoir ModelMultiRate C and nPerm(k) Reduction ModelNoReservoir Pressure1399.68(psig)Reservoir Temperature119(deg F)Water-Gas Ratio0(STB/MMscf)Condensate Gas Ratio0(STB/MMscf)CALCULATED DATAAOF :1.99248(MMscf/day)C :0.0050862(Mscf/day/psi2)n :0.88763MultiRate Point 1MultiRate Point 2Inflow (IPR) Plot David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchrage, AK 99503 Tele: 907 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE 9/2/2020 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL CLU 15 (PTD 220-003) CBL 05-MAY-2020 Please include current contact information if different from above. Received by the AOGCC 09/02/2020 PTD: 2200030 E-Set: 33730 Abby Bell 09/02/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/16/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL CLU 15 (220-003) Mudlog Data Please include current contact information if different from above. Received by the AOGCC 08/19/2020 PTD: 2200030 E-Set: 33670 Abby Bell 08/19/2020 From:Guhl, Meredith D (CED) To:Bell, Abby E (CED) Subject:CLU 15 Date:Wednesday, August 19, 2020 7:59:28 AM Attachments:RE EXTERNAL CLU 15 mudlog Geotap results sidewall core analysis.msg RE EXTERNAL CLU 15 mudlog Geotap results sidewall core analysis.msg Fwd EXTERNAL RE CLU 15 GEOTAP Report.msg Hi Abby, Can you please catalog the CLU 15 data that Hilcorp has provided? Mudlogs in the their own folder and the GeoTap report in a separate one. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. Received by the AOGCC 08/19/2020 PTD: 2200030 E-Set: 33669 Received and signed by Abby Bell on 08/19/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/17/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU M-44 (220-030) MPU M-44 & M-44 PB1 Received by the AOGCC 07/20/2020 PTD: 2200300 E-Set: 33577 Abby Bell 07/20/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/17/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU M-44 (220-030) MPU M-44 & M-44 PB1 Received by the AOGCC 07/20/2020 PTD: 2200300 E-Set: 33576 Abby Bell 07/20/2020 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20687-00-00Well Name/No. CANNERY LOOP UNIT 15Completion Status1-GASCompletion Date5/13/2020Permit to Drill2200030Operator Hilcorp Alaska, LLCMD10511TVD7959Current Status1-GAS8/21/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:CBLs 5-5-20, 4-15-20 / ROP, DGR, AGR, ABG, ADR, EWR MD & TVD, GeoTapNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScale0 0 2200030 CANNERY LOOP UNIT 15 LOG HEADERS33557LogLog Header ScansDF7/20/20207727 989 Electronic Data Set, Filename: CLU15 7.625 CBL 4-15-20.las33557EDDigital DataDF7/20/2020 Electronic File: CLU 15 7.625 CBL 4-15-20.pdf33557EDDigital DataDF7/20/2020118 10511 Electronic Data Set, Filename: CLU 15 LWD Final.las33558EDDigital DataDF7/20/202013 13 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 1.las33558EDDigital DataDF7/20/202021 21 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 10.las33558EDDigital DataDF7/20/202022 22 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 11.las33558EDDigital DataDF7/20/202023 23 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 12.las33558EDDigital DataDF7/20/20200 0 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 13.las33558EDDigital DataDF7/20/20200 0 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 14.las33558EDDigital DataDF7/20/20200 1 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 15.las33558EDDigital DataDF7/20/20201 1 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 16.las33558EDDigital DataDF7/20/20202 2 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 17.las33558EDDigital DataFriday, August 21, 2020AOGCCPage 1 of 10Supplied by OPSupplied by OPCLU 15 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20687-00-00Well Name/No. CANNERY LOOP UNIT 15Completion Status1-GASCompletion Date5/13/2020Permit to Drill2200030Operator Hilcorp Alaska, LLCMD10511TVD7959Current Status1-GAS8/21/2020UICNoDF7/20/20203 3 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 18.las33558EDDigital DataDF7/20/20203 3 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 19.las33558EDDigital DataDF7/20/202014 14 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 2.las33558EDDigital DataDF7/20/20204 4 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 20.las33558EDDigital DataDF7/20/20205 5 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 21.las33558EDDigital DataDF7/20/20205 6 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 22.las33558EDDigital DataDF7/20/20206 6 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 23.las33558EDDigital DataDF7/20/20206 6 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 24.las33558EDDigital DataDF7/20/20207 7 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 25.las33558EDDigital DataDF7/20/20207 7 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 26.las33558EDDigital DataDF7/20/20208 9 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 27.las33558EDDigital DataDF7/20/20209 9 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 28.las33558EDDigital DataDF7/20/202010 10 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 29.las33558EDDigital DataDF7/20/202014 15 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 3.las33558EDDigital DataDF7/20/202010 10 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 30.las33558EDDigital DataDF7/20/202011 11 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 31.las33558EDDigital DataDF7/20/202011 12 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 32.las33558EDDigital DataDF7/20/202012 13 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 33.las33558EDDigital DataFriday, August 21, 2020AOGCCPage 2 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20687-00-00Well Name/No. CANNERY LOOP UNIT 15Completion Status1-GASCompletion Date5/13/2020Permit to Drill2200030Operator Hilcorp Alaska, LLCMD10511TVD7959Current Status1-GAS8/21/2020UICNoDF7/20/202013 13 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 34.las33558EDDigital DataDF7/20/202014 14 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 35.las33558EDDigital DataDF7/20/202015 15 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 36.las33558EDDigital DataDF7/20/202015 15 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 37.las33558EDDigital DataDF7/20/202016 17 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 38.las33558EDDigital DataDF7/20/202017 18 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 39.las33558EDDigital DataDF7/20/202016 16 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 4.las33558EDDigital DataDF7/20/202018 18 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 40.las33558EDDigital DataDF7/20/202019 19 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 41.las33558EDDigital DataDF7/20/202020 20 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 42.las33558EDDigital DataDF7/20/202020 20 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 43.las33558EDDigital DataDF7/20/202021 21 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 44.las33558EDDigital DataDF7/20/202021 21 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 45.las33558EDDigital DataDF7/20/202022 22 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 46.las33558EDDigital DataDF7/20/202023 23 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 47.las33558EDDigital DataDF7/20/202023 23 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 48.las33558EDDigital DataDF7/20/202016 16 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 5.las33558EDDigital DataDF7/20/202017 17 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 6.las33558EDDigital DataFriday, August 21, 2020AOGCCPage 3 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20687-00-00Well Name/No. CANNERY LOOP UNIT 15Completion Status1-GASCompletion Date5/13/2020Permit to Drill2200030Operator Hilcorp Alaska, LLCMD10511TVD7959Current Status1-GAS8/21/2020UICNoDF7/20/202018 18 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 7.las33558EDDigital DataDF7/20/202019 19 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 8.las33558EDDigital DataDF7/20/202020 21 Electronic Data Set, Filename: CLU 15 Run 300 Geotap Test 9.las33558EDDigital DataDF7/20/2020 Electronic File: CLU 15 LWD Final MD.cgm33558EDDigital DataDF7/20/2020 Electronic File: CLU 15 LWD Final TVD.cgm33558EDDigital DataDF7/20/2020 Electronic File: CLU 15 R300 GeoTap Recorded Pressure Tests.cgm33558EDDigital DataDF7/20/2020 Electronic File: CLU 15 - Definitive Survey Report.pdf33558EDDigital DataDF7/20/2020 Electronic File: CLU 15_DSR.txt33558EDDigital DataDF7/20/2020 Electronic File: CLU 15_GIS.txt33558EDDigital DataDF7/20/2020 Electronic File: CLU 15 LWD Final MD.pdf33558EDDigital DataDF7/20/2020 Electronic File: CLU 15 LWD Final TVD.pdf33558EDDigital DataDF7/20/2020 Electronic File: CLU 15 R300 GeoTap Recorded Pressure Tests.pdf33558EDDigital DataDF7/20/2020 Electronic File: CLU 15 LWD Final MD.tif33558EDDigital DataDF7/20/2020 Electronic File: CLU 15 LWD Final TVD.tif33558EDDigital DataDF7/20/2020 Electronic File: CLU 15 R300 GeoTap Recorded Pressure Tests.tif33558EDDigital Data0 0 2200030 CANNERY LOOP UNIT 15 LOG HEADERS33558LogLog Header ScansC8/13/2020600 348 Electronic Data Set, Filename: CLU-15_CBL_05MAY20_FreePipe.las33654EDDigital DataC8/13/202010420 4792 Electronic Data Set, Filename: CLU-15_CBL_05MAY20_Main.las33654EDDigital DataC8/13/202010431 10113 Electronic Data Set, Filename: CLU-15_CBL_05MAY20_Repeat.las33654EDDigital DataC8/13/2020 Electronic File: CLU-15_CBL_05MAY20.pdf33654EDDigital DataC8/19/2020 Electronic File: CLU 15 GeoTap Report.pdf33669EDDigital DataC8/19/2020 Electronic File: CLU-15 Alaska GeoTap RT Summary Sheet.xlsx33669EDDigital DataFriday, August 21, 2020AOGCCPage 4 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20687-00-00Well Name/No. CANNERY LOOP UNIT 15Completion Status1-GASCompletion Date5/13/2020Permit to Drill2200030Operator Hilcorp Alaska, LLCMD10511TVD7959Current Status1-GAS8/21/2020UICNo0 0 2200030 CANNERY LOOP UNIT 15 LOG HEADERS33669LogLog Header Scans0 0 2200030 CANNERY LOOP UNIT 15 LOG HEADERS33670LogLog Header ScansC8/19/20201 10600 Electronic Data Set, Filename: CLU-15.las33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Geolog AM Report 04-15-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Geolog AM Report 04-16-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Geolog AM Report 04-17-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Geolog AM Report 04-18-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Geolog AM Report 04-19-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Geolog AM Report 04-20-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Geolog AM Report 04-21-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Geolog AM Report 04-22-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Geolog AM Report 04-23-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Nabors AM Report 04-02-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Nabors AM Report 04-03-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Nabors AM Report 04-04-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Nabors AM Report 04-05-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Nabors AM Report 04-06-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Nabors AM Report 04-07-2020.pdf33670EDDigital DataFriday, August 21, 2020AOGCCPage 5 of 10CLU-15.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20687-00-00Well Name/No. CANNERY LOOP UNIT 15Completion Status1-GASCompletion Date5/13/2020Permit to Drill2200030Operator Hilcorp Alaska, LLCMD10511TVD7959Current Status1-GAS8/21/2020UICNoC8/19/2020 Electronic File: Hilcorp CLU 15 Nabors AM Report 04-08-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Nabors AM Report 04-09-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Nabors AM Report 04-10-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Nabors AM Report 04-11-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Nabors AM Report 04-12-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: Hilcorp CLU 15 Nabors AM Report 04-13-2020.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU-15 Final Well Report.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in Drilling Dynamics Log MD.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in Drilling Dynamics Log TVD.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in Formation Log MD.pd33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in Formation Log TVD.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in Gas Ratio Log MD.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in Gas Ratio Log TVD.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in LWD Combo Log MD.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in LWD Combo Log TVD.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - Drilling Dynamics Log MD.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - Drilling Dynamics Log TVD.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in Drilling Dynamics Log MD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in Drilling Dynamics Log TVD.tif33670EDDigital DataFriday, August 21, 2020AOGCCPage 6 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20687-00-00Well Name/No. CANNERY LOOP UNIT 15Completion Status1-GASCompletion Date5/13/2020Permit to Drill2200030Operator Hilcorp Alaska, LLCMD10511TVD7959Current Status1-GAS8/21/2020UICNoC8/19/2020 Electronic File: CLU 15 - 5in Formation Log MD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in Formation Log TVD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in Gas Ratio Log MD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in Gas Ratio Log TVD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in LWD Combo Log MD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - 5in LWD Combo Log TVD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - Drilling Dynamics Log MD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - Drilling Dynamics Log TVD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - Formation Log MD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - Formation Log TVD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - Gas Ratio Log MD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - Gas Ratio Log TVD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - LWD Combo Log MD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU 15 - LWD Combo Log TVD.tif33670EDDigital DataC8/19/2020 Electronic File: CLU_15.dbf33670EDDigital DataC8/19/2020 Electronic File: clu_15.hdr33670EDDigital DataC8/19/2020 Electronic File: CLU_15.mdx33670EDDigital DataC8/19/2020 Electronic File: clu_15r.dbf33670EDDigital DataC8/19/2020 Electronic File: clu_15r.mdx33670EDDigital DataC8/19/2020 Electronic File: CLU_15_SCL.DBF33670EDDigital DataC8/19/2020 Electronic File: CLU_15_SCL.hdr33670EDDigital DataC8/19/2020 Electronic File: CLU_15_SCL.mdx33670EDDigital DataC8/19/2020 Electronic File: CLU_15_tvd.dbf33670EDDigital DataC8/19/2020 Electronic File: CLU_15_tvd.mdx33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 1 7504-7416.pdf33670EDDigital DataFriday, August 21, 2020AOGCCPage 7 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20687-00-00Well Name/No. CANNERY LOOP UNIT 15Completion Status1-GASCompletion Date5/13/2020Permit to Drill2200030Operator Hilcorp Alaska, LLCMD10511TVD7959Current Status1-GAS8/21/2020UICNoC8/19/2020 Electronic File: CLU 15 Gas Show Report 10 8142-8154.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 11 8178-8197.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 12 8230-8255.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 13 8330-8352.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 14 8377-8420.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 15 8568-8606.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 16 8652-8680.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 17 8738-8760.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 18 8797-8840.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 19 8884-8927.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 2 7453-7490.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 20 9320-9380.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 21 9385-9425.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 22 9489-9542.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 23 9578-9602.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 24 9710-9730.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 25 9759-9800.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 26 9825-9885.pdf33670EDDigital DataFriday, August 21, 2020AOGCCPage 8 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20687-00-00Well Name/No. CANNERY LOOP UNIT 15Completion Status1-GASCompletion Date5/13/2020Permit to Drill2200030Operator Hilcorp Alaska, LLCMD10511TVD7959Current Status1-GAS8/21/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDC8/19/2020 Electronic File: CLU 15 Gas Show Report 27 9902-9930.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 28 10125-10148.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 29 10210-10245.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 3 7500-7525.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 30 10305-10358.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 31 10360-10415.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 32 10438-10453.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 33 10472-10492.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 4 7579-7621.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 5 7625-7670.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 6 7730-7741.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 7 7875-7885.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 8 7962-7980.pdf33670EDDigital DataC8/19/2020 Electronic File: CLU 15 Gas Show Report 9 8082-8100.pdf33670EDDigital Data7/6/20202160 105111746CuttingsFriday, August 21, 2020AOGCCPage 9 of 10 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-133-20687-00-00Well Name/No. CANNERY LOOP UNIT 15Completion Status1-GASCompletion Date5/13/2020Permit to Drill2200030Operator Hilcorp Alaska, LLCMD10511TVD7959Current Status1-GAS8/21/2020UICNoCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date: 5/13/2020Release Date:1/22/2020Friday, August 21, 2020AOGCCPage 10 of 10M. Guhl8/21/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/16/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL CLU 15 (220-003) Mudlog Data Please include current contact information if different from above. Received by the AOGCC 08/19/2020 PTD: 2200030 E-Set: 33670 Abby Bell 08/19/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/16/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL CLU 15 (220-003) ELOGS Please include current contact information if different from above. Received by the AOGCC 07/20/2020 PTD: 2200030 E-Set: 33558 Abby Bell 07/20/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/17/2020 To: Department of Natural Resources Resource Evaluation 550 W. 7th Ave. Ste#1100 Anchorage, AK 99501 DATA TRANSMITTAL CLU 15 (220-003) CBL Please include current contact information if different from above. Received by the AOGCC 07/20/2020 PTD: 2200030 E-set: 33557 Abby Bell 07/20/2020 HJvnrj3.%14Imkm_ I.I.0 DATE 7/06/2020 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 WELL ; BOX INTERVAL CLU 15 BOX 1 OF 6 2160' — 3720' CLU 15 BOX 2 OF 6 3720' — 5400' CLU 15 BOX 3 OF 6 5400' — 6900' CLU 15 BOX 4 OF 6 6900'— 8550' CLU 15 BOX 5 OF 6 8550'— 10050' CLU 15 BOX 6 OF 6 10050'— 10511' Please include current contact information if different from above. )Tq(0 RECEIVED JUL 0 6 2020 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received Date: �� /vl /vc� 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2.Operator Name:6.Date Comp., Susp., or 14.Permit to Drill Number / Sundry: Aband.: 3. Address: 7.Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: Top of Productive Interval: 9.Ref Elevations: KB: 17.Field / Pool(s): GL: 35' BF: 35' 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-56 138' 10-3/4" L-80 1,697' 7-5/8" L-80 5,322' 4-1/2" L-80 7,950' 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 Rate292 April 19, 2020 April 1, 2020 Private Fee, ADL391791, ADL391792, ADL 391790, ADL324602 LOCI 78-156 N/A N/AN/A N/A 10,511' MD / 7,959' TVD CBLs 5-5-20, 4-15-20 / ROP, DGR, AGR, ABG, ADR, EWR MD & TVD, GeoTap Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 002623 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/A2623 Flowing **Please see attached schematic for perforation details** 0 Water-Bbl: PRODUCTION TEST 5/14/2020 Date of Test: 0 6/4/2020 24 Flow Tubing 0 109# 45.5# 138' Surface 7,790' Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 29.7# 10,502' Surface Surface DEPTH SET (MD) N/A PACKER SET (MD/TVD) Surface CASING WT. PER FT.GRADE 12.6# 277525 277440 TOP SETTING DEPTH MD Surface SETTING DEPTH TVD 2391727 BOTTOM TOP 9-7/8" 35 bbls Surface 13-1/2" HOLE SIZE AMOUNT PULLED 50-133-20687-00-00 CLU 15 280837 2396118 1630' FNL, 793' FEL, Sec 8, T5N, R11W, SM, AK CEMENTING RECORD 2392000 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 5/13/2020 2539' FSL, 2464' FWL, Sec 4, T5N, R11W, SM, AK 1905' FNL, 874' FEL, Sec 8, T5N, R11W, SM, AK 220-003 / 320-178 Cannery Loop Unit / Beluga Gas Pool 53' 10,418' MD / 7,868' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas Conductor Surface 2,144' L - 375 sx / T - 275 sx Driven L - 585 sx / T - 245 sx Surface N/AN/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, L - 250 sx / T - 85 sx6-3/4" TUBING RECORD WINJ SPLUG Other Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 9:51 am, Jun 15, 2020 RBDMS HEW 6/16/2020 Completion Date 5/13/2020 HEW Gas DLB 06/16/2020 DSR-6/16/2020gls 6/24/20 G Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval LB 1F 9,329' 6,813' 5818 3555 7639 5175 8330 5846 9097 6588 9291 6776 9369 6852 9456 6936 9483 6962 9743 7215 9814 7283 9853 7321 10341 7793 Tyonek 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). LB 3A LB 3B Tyonek 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. LB 3 Formation at total depth: Low Beluga Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report. 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 LB 2B Permafrost - Top LB 1F UP Beluga Mid Beluga ST A3 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 inc lination 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 LB 1G LB 2A Geotap results to be submitted post lab analysis. Permafrost - Base 29.GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS No NoSidewall Cores:Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.06.14 11:37:56 -08'00' Monty M Myers _____________________________________________________________________________________ Updated by CJD 06-14-20 SCHEMATIC Cannery Loop Unit Well: CLU #15 PTD: 220-003 API#: 50-133-20687-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor 109 / X-56 / Weld 15” Surf 120’ 10-3/4” Surface 45.5 /L-80 / DWC 9.950” Surf 2,144’ 7-5/8" Intermediate 29.7 / L-80 / DWC 6.875” Surf 7,790’ 4-1/2" Production 12.6 / L-80 / DWC 3.958” Surf 10,502’ JEWELRY DETAIL No Depth Item 1 6,416’ 4-1/2” Swell Packer OPEN HOLE / CEMENT DETAIL 10-3/4” L – 375 sx T – 275 sx 35 bbls returned to surface. Injected finecem in annulus 135 sx do to tidal washout. 7-5/8" Cement in 9-7/8” Hole . Pumped 585 Sx. (225 bbls. 12 ppg class A followed by 245 Sx. (53 bbls. ) 15.3 ppg Class A. TOC @ 3,675. 4/16/20 4-1/2" L- 250 sx T – 85 sx in 6-3/4” hole Est TOC 6414’ MD PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVD Ft Date Comments LB 1F 9,329’ 9,335’ 6,813' 6,819' 6' 5/27/20 2-7/8” LB 1G 9,389' 9,406' 6,871' 6,887' 17' 5/27/20 2-7/8” LB 2B 9,510' 9,530' 6,995' 7,008' 20' 5/27/20 2-7/8” LB 3 9,778' 9,787' 7,248' 7,257' 9' 5/13/20 2-7/8” LB 3A 9,836' 9,850' 7,305' 7,318' 14' 5/13/20 2-7/8” LB 3B 9,860' 9,886' 7,328' 7,354' 26' 5/13/20 2-7/8” FIT to 12.9 ppg Sterling C 7400-7580 ft Activity Date Ops Summary 3/27/2020 Nipple Up adaptor flange and master valve, install flange and tree cap, secure wellhead, continue cleaning pits and flushing lines, remove top drive from rig floor 3/28/2020 Continue demob. and cleaning pits and lines prep modules for trucks and cranes vac truck had one cup oil spill to frozen pad from truck scrubber and chip up two cups of gravel notifications made to Matt Hogge.;Day crew out early and keep night crew late. Scope dn derrick. trucks and cranes on location continue prep modules and cleaning remove skate, rig mats, handy berm. prep l/dn derrick Remove wind walls and stage rig equipment.;L/dn derrick, continue removing wind walls, Iron roughneck, centrifuge, three pit modules , install bops in transport cradle remove both mud pumps.;Pull out gen skid, and top drive HPU, Remove derrick and load on trailer, pull off draworks skid, Pull sub and pony subs off well, Load and ship mats, set felt and liner on CLU-15, set starting mats on CLU-15 continue shipping mats f/ BCU-04.;Continue shipping and setting mats on CLU-15, Clean and clear location load trailers f/ shipping f/ BCU t/ CLU. 3/29/2020 Continue shipping equipment f/ BCU-04 t/ CLU-15, finish setting rig mats, trucks on location moving sub and pony subs to location, spot pony subs over well, spot in cranes, spot sub over well, set draworks skid on sub, set derrick on sub, set dog house water tank, raise dog house, set pit module #1.;Spot pump skid, spot in pit module #2 and pump#2, hook up mud lines, raise pit roofs, crane set iron roughneck and centrifuge, set choke house w/ crane, set generator module and top drive HPU, spot in boiler house, set camps, spot in change shack and generator, R/U rig interconnects.;Spot in camps and transformer, spot change shack and generator, continue hooking up interconnects on rig, prep derrick to scope, hook up mud lines and steam lines, change bad valves in pits and water tank, pull electrical lines to modules, continue shipping and receiving loads f/ BCU, hook up lines;for pason system, Hook up choke house lines, dress mud pumps w/ new 5 1/2'' liners and swabs, build docks in front of camps, trucks will be out @ 0700 hrs to spot catwalk and gas buster. 3/30/2020 Continue rigging up rig components, R/U and commission Iron roughneck, R/U Camera system, spool up drilling line on drum, prep derrick to scope, R/U top drive hydraulic lines, hook up stand pipe manifold, R/U koomey lines, Set mats for catwalk and spot catwalk, R/U torque tube;set wind walls with crane, R/U choke manifold to pits Perform derrick inspection, Scope Derrick spot in upright water tank.;Install roof over centrifuge, change out pit valves on mud tanks, continue rigging up pason system, Install T bar on torque tube, continue dressing mud pumps, spot gas buster and install vent on top, raise gas buster, install cylinder covers on rams f/ derrick.;R/U and P/U top drive in cradle, Hook up top drive to blocks and remove shipping cradle, install new goose neck on top drive hook up hydraulic lines and Kelly hose, change out suction rubbers in mud pits, hang tarps around rig mud pits cellar and rig floor, Function test top drive.;Install saver sub, install clamp over connection, continue hooking up rig components.;Rig up bails and elevators, adjust load collar, clean diverter bolts, install test plug in wellhead, continue dressing mud pumps, take on water to boiler, Fire up boiler, get up to pressure, begin running steam around rig, fix steam leaks thaw frozen lines, rig service.;N/U diverter, install DSA, riser spool and T, prep annular, continue rigging up rig components. 3/31/2020 N/U diverter Assembly, DSA, Spool, T Spool, Annular and riser, install knife valve.;N/U diverter line with braces tighten bolts, change out winch on rig floor, for man rider winch, Install bell nipple and flow line, cross chain stack, work on hydraulic lines to annular and knife valve, inspecting suction valves in pits transfer water around through pits.;Continue Rigging up, run wires f/ gen 3, R/U all service shacks, canrig and sperry, continue working on rig acceptance checklist, remove shipping blocks f/ centrifuge, function test, screened up shakers, take on load of spud mud to pits, jack up rig and shim sub to get choke house off pit roof.;Function test diverter, work bag to get out all air in lines, loading pipe racks w/ DP.;Continue working on rig acceptance check list, continue loading pipe and strapping, perform diverter test, trouble shoot knife valve closing slow, 34 sec for knife and 38 sec for annular, change hose configuration retested functioned properly, prep to P/U DP Kelly hose not riding correct change;orientation of hose and test run through derrick. 4/1/2020 Continue orient Kelly hose and test run through derrick. Prep rig floor to p/up dp and remove rubber less test plug and install wear ring.;P/up rabbit and strap 4-1/2" S-135 CDS -40 16.6# DP Commission TDS, Tong and IR torque gauges against each other on first make up (TDS @ 21,000ft/lb / tongs 21,500ft/lbs / IR -20,500 FT/LB Test COM and rack back an Commission monkey board.;House clean and organize complete rig and location & work on steam heater in cellar.;Resume p/up rabbit and strap dp and rack back same.;Function test 21-1/4" 2M diverter system w/ one 16" knife valve witnessed by Mr. Bob Noble w/ AOGCC OK.;Resume p/up rabbit and strap dp and rack back same.;Assist Total safety w/ testing gas alarms H@S sensor failed in cellar and continued r/up Pipe skate controls and and drillers rig floor P/A system.;Resume p/up rabbit and strap dp and rack back same while Total safety went to town and got parts installed and retested Good.;Held pre Spud with all hands.;P/U HWDP and Jars M/U stand in derrick.;Load BHA on catwalk, P/U Directional BHA. Bit Motor and cross overs 1 stand of HWDP.;Found 4'' Ball valves on conductor leaking, changed out, filled stack with mud to test lines, stack leaking hammer up flanges.;Test surface equipment to 3200 psi f/ 5 min good test, RIH tag bottom 101'.;Drill ahead f/ 101' t/ 219' 400 gpm 350 psi 40 rpm 5k WOB to make room f/ remaining BHA.;POOH Stand back HWDP.;M/U Directional BHA as per DD/MWD, RIH t/ 219'.;Drill Ahead f/ 219' t/ 303' 400 gpm 668 psi 40 rpm 1200 ft/lbs of tq on 800 ft/lbs off surveys still dirty, consult sperry town decision made to pull out of the hole and pull a scribe off the motor to verify direction.;POOH f/ 303' t/ 243' Racking back HWDP in derrick. n (LAT/LONG): evation (RKB): 50-133-20687-00-00API #: Well Name: Field: County/State: CLU 15 Cannery Loop Hilcorp Energy Company Composite Report Kenai, Alaska Contractor AFE #: AFE $: Job Name:2010186D CLU 15 Drilling Spud Date: ygp ;Function test 21-1/4" 2M diverter system w/ one 16" Diverter test g knife valve witnessed by Mr. Bob Noble w/ AOGCC gg gpp g gp , perform diverter test, trouble shoot knife valve closing slow, 34 sec for knife and 38 sec for annular, N/U diverter Assembly, 4/2/2020 RIH F/ 51' T/297' carry scribe to 297'.;Kick off and directional Drill 13-1/2" hole as per WP -05 4/100 F/297' T/356'.;POOH F/356' T/271' racking back HWDP. PU Jars out of derrick and found sharp threads on pin end of HWDP stand #2 . Rack back HWDP stand #2 on DS. RIH F/271' T/356'.;Directional drill 13-1/2" hole as per WP#5 and DD F/356' T/608'.;Work and reciprocate pipe while crews change out. DD running projections for current well path. PU WT 48K, SO WT 48K.;Continue 100% slide drill as per DD F/608' T/1220' @ 400 gpm @ 1091 psi w/ up/dn/rot 50/50/50k.;Continue Drilling ahead sliding and building angle f/ 1220' t/ 1813' 450 gpm 1050 psi 40 rpm 5.8k tq on bottom 4.5k torque off 60k PUW 50k SOW 54k ROT.;Continue Directionally Drilling ahead as per DD/MWD f/ 1813' t/ TD@ 2151' 550 gpm 1600 psi 40 RPM 6.5k tq on 4.8k tq off 62k PUW 51k SOW 55 ROT, Distance to Plan 9.37' 8.67' High 3.56' Left.;Circulate bottoms up 550 gpm 1580 psi 40 rpm 4.5k Tq off bottom.;POOH f/ 2151' t/ 1902' started pulling tight 40k over pull, Pumped out to 1796' pulling tight packing off, Back reaming out working through tight spots and dog legs 10k tq and packing off @1551'.;Hauled 347bbls solids to KGFG&I Cumulative 347 bbls Hauled 543 bbls fluid to KGF G&I Cumulative 583 bbls Daily Metal 0lbs Cumulative Metal 0 lbs 4/3/2020 Continue Pooh back reaming and working through tight spots and dog legs and swabbing issues when straight pulled f/ 1551' t/ 732'.;Pooh on elevators rack back same f/ 732' 420'.;Complete rig service and Un- shim sub and monitor static well @ 4-5 bph loss rate.;Rih f/ 420' t/ 1902' wiping tight spots clean. tight at f/ 1446' - t/ 1535' , 1827' 1844'- 1876' ,& 1902'.;Kelly up and wash and ream tight spot f/ 1964' t/ 2024' rih t/ 2039' wash and ream t/ TD @ 2152' @ 496 psi @ 298 gpm and 9.2 MW.;Circ btm/up staging up rate and pump Flagged high vis sweep around Back 25 bbls early w/ no increases in cuttings @ 1675 psi @ 550 gpm w/ 9.2 MW and +- 10 BPH loss rate while pumping and flow chk w/ 4-5 bph static loss rate.;Pooh on elevators w/ no issues f/ 2152' t/ 175'.;Rack back flex collars L/ D 8'' Flex Collars, unload pulser on TM, Milk motor break bit, L/D 3 stands of DP f/ derrick bad boxes/pins.;Change hyd fitting on top drive, adjust T bar on torque tube, Clear floor.;R/U Weatherford Casing equipment, clear and load racks w/ 10 3/4'' Casing, pull wear ring, loss rate .6 bph while static.;PJSM Run 10 3/4'' Casing and installing centralizers as per detail, filling every jt topping off every 5, baker locked first 3 jts, checked floats held, torquing DWC t/ 39000 ft/lbs @ 1263'.;Hauled 135bbls solids to KGFG&I Cumulative 482 bbls Hauled 305 bbls fluid to KGF G&I Cumulative 888 bbls Daily Metal 0lbs Cumulative Metal 0 lbs Losses to hole 108 bbls Total losses to hole 108 bbls 4/4/2020 Continue Run 10 3/4'' Casing and installing centralizers as per detail, filling every jt topping off every 5, torquing DWC t/ 39000 ft/lbs F/ 1263' t/ 2113' w/ no issues P/up and M/up Hanger jt and Landing jt and land out w/ shoe @ 2143'.;Establish reciprocation appears hanger hanging up on annular in up stroke limit reciprocation t/ +- 13' stage up flow rate t/ 5 bpm @ 200 psi up wt @ 82k, dn wt @ 50k Circ and cond mud and circ a btm /up while staging and r/up cmt equipment.;PJSM and crew change land out r/up cmt head and lines flush lines to cutting tank and brk circ 3 bbls dn hole w/ cmt unit and test 300L/3000H ok, followed by 50 bbl spacer @ 10.5 ppg drop btm plug and mix and pump 160 bbls of 12.0 ppg lead cmt @ 4.6 bpm followed by 60 bbls 15.8 ppg tail cmt;and drop top plug howco displaced at 6 bpm w/ 9.3 ppg mud and bumped plug 7 bbls early t/ 1030 psi 500 psi over FCP bled off .9 of bbl and floats held . CIP at 15:35 hrs. Reciprocated pipe 13' throughout job @ 20 bbls into displacement lost returns and slowed rate t/ 2 bpm and regained circ;and pipe became sticky and attempted to land out but was 6" shy attempt to work hanger out of profile to set slips t/ 280k w/ no movement. Discussed options w/ Clint and Town lost 31.6 bbls during job and got back spacer and 35 bbls cmt.;Wash out bag and riser, blow dn lines and equipment. and r/dn cmt equipment.;Nip/ dn diverter assembly, clean cellar and suck out with vac truck, water flowing past hanger keep vac truck sucking it out 15 bph.;R/U welder and begin cutting off 16'' starting head, remove DSA and pull valves off Conductor, welder cut 10 3/4'' removed starting flange and hanger, dress pipe to accommodate new wellhead, fab and build cap f/ 16''x10 3/4'' to isolate fresh water flow and center pipe, weld on new 2'' outlet on;16'' conductor, dry fit tree on 10 3/4''.;Hauled 77bbls solids to KGFG&I Cumulative 559 bbls Hauled 583 bbls fluid to KGF G&I Cumulative 1471 bbls Daily Metal 0lbs Cumulative Metal 0 lbs Losses to hole 31.6 bbls Total losses to hole 139.6 bbls 4/5/2020 Weld out 10-3/4" well head as per NOS well head hand and wrap well head for slow cool down. No pressure build up on 16" x 10-3/4" annulus chg out 1000 psi gauge t/ 300 psi gauge and monitor same w/ no pressure build up.;Continue Monitor well head cool dn and 16" X 10-3/4" annulus preform rig maintenance organize location and conexes and load up trailers w/ unneeded equipment, Continue build 9.0 ppg 6% KCL EZ mud WBM system. R/up choke lines and gas buster, and kill lines. over flowed hopper est 1-2 bbl spill.;To secondary containment recovered w/ vac trk and reclaimed same asking Tool pusher for disciplinary action still no pressure build up and 300 psi gauge but 1/2 hr spot chk shows flowing @ 1.6 bph.;Crew chg, continue monitor pressure and flow on 16" X 10-3/4" annulus, Continue install kill line to Mezz deck. Spot crane fold up cat walk and hang bopes on trolley beams hook up koomey lines and open up ram doors chg out both sets of VBR rams f/ rentals t/ Hilcorp owned new rams did not fit.;Proper (doors would not close) remove new rams and rebuilt one set of rentals.;Chg out choke HCR shim and level TDS, load drill pipe on cat walk, chg out fitting on tds for extend.;Check temperature of wellhead 64 degrees, pull off insulation and wrapping, call wellhead hands out, test weld w/ nitrogen t/ 2000 psi f/ 10 min good test, install wing valves in cellar, install spacer spools on wellhead.;N/U BOP Stack and flow box install riser and flow line, tighten bolts, Make up hole fill line, Check flow rate on 16'' x10 3/4'' Annulus 0 pressure flowing 10 bph.;Hauled 77bbls solids to KGFG&I Cumulative 559 bbls Hauled 240 bbls fluid to KGF G&I Cumulative 1711 bbls Daily Metal 0lbs Cumulative Metal 0 lbs Losses to hole 31.6 bbls Total losses to hole 139.6 bbls No pressure build up on 16" x 10-3/4" annulus 33 y t 1/2 hr spot chk shows flowing @ 1.6 bph.;C g@ p issues f/ 2152' t/ 175'. Water flow up OOA Continue Run 10 3/4'' Casing and installing centralizers as per detail, cement 10 3/4" csg gp g followed by 50 bbl spacer @ 10.5 ppg drop btm plug and mix and pump 160 bbls of 12.0 ppg lead cmt @ 4.6 bpm followed by 60 y p @ ppg p p g p p ppg @ py bbls 15.8 ppg tail cmt;and drop top plug howco displaced at 6 bpm w/ 9.3 ppg mud and bumped plug 7 bbls early t/ 1030 psi 500 psi over FCP bled off .9 ppg p p p g of bbl and floats held . CIP at 15:35 hrs. gp g p g welder cut 10 3/4'' removed starting flange and hanger, y ;Pooh on elevators w/ no pyp lost 31.6 bbls during job and got back spacer and 35 bbls cmt. ;R/U Weatherford Casing equipment, 4/6/2020 Finish nip/up and function test (ok) Pull test plug that was Protecting hole during nipple up and inspect same ok P/up M/up 4-1/2" test jt and set test plug and r/up test equipment flow rate on 16'' x10 3/4'' Annulus 0 pressure flowing .97 bph @ 11:00 am Low tide and acquire good shell test.;Call out state Man, Crew chg and start Bop test witnessed by AOGCC inspector Mr. Jeff Jones test bop as per regulations 250L/3500H 5/5 min. Had one F/P Kill manual valve bled air and serviced valve re test ok, Choke manual valve fail, continued test btm VBR failed continued w/ draw dn test;ok and Blind test ok.;Change out Inside Manual Choke valve, and re build btm VBRs weld gussets on well head fit grating around spacer spool and safe out cellar.;Install test jt and fill stack and choke with water, retest and notify state man R/D test equipment, set wear ring.;R/U and tests casing to 3000 psi f/ 30 min on chart R/D test equipment Blow down lines, check flow on 16'' x 10 3/4'' Annulus .94 bph before casing test .63 bph after casing test.;R/U to P/U pipe, P/U DP RIH 25 stands, POOH standing back DP in derrick, perform Injectivity test on 16'' x 10 3/4'' annulus w/ test pump 1 bbl in 4 min 300 psi max pressure no pressure on line when broke apart.;Hauled 4.5 bbls solids to KGFG&I Cumulative 563.5 bbls Hauled 40.5 bbls fluid to KGF G&I Cumulative 1751.5 bbls Daily Metal 0lbs Cumulative Metal 0 lbs Losses to hole 0 bbls Total losses to hole 139.6 bbls 4/7/2020 Continue POOH standing back DP in derrick from 1400' to surface, total 25 stands.;RIH p/up rabbiting and strapping 4-1/2" cds-40 dp total 50 jnts to 1550'.;POOH standing back DP in derrick from 1550' to surface, total 25 stands.;Clear rig floor, installed mousehole.;PU and MU directional BHA #2 (9.875” Kymera bit jetted w/1x12, 2x13's and 3x14's, mud motor, DM, DGR, PWD, ADR, ALD, ILS, CTN and TM collars.).;Plug in and upload MWD, shallow pulse test (OK), held PJSM, block access to rig floor and load sources.;Run remaining BHA (NM Flex DC's, HWDP and jars for total BHA length of 744.82'.;PU single in hole 30 jnts CDS-40 DP to 1672' and filled pipe.;At 1672' removed Kelly hose from topdrive to install gooseneck extension. Extension had wrong fitting on one end, re-installed Kelly hose to topdrive, RU and tested surface lines from pumps to topdrive at 2261 psi. Sent extension in for modification/change of union.;Cont ease in hole on DP from derrick, from 1672' to 2077' and tagged up (top of FC at +/- 2099').;Commence drilling cement, plugs, shoe track and 20' new formation from 2077' to 2171'. WOB 4 to 10K, 479 to 516 GPM-1428 to 1707 psi, 30 to 40 rpm-6500 to 7900 ft/lbs on bott torque, displace to 6% kcl mud while drilling.;Circulate and condition mud f/ FIT 9.1 ppg in and out.;R/U and perform FIT t/ 12.91 ppg EMW 340 psi @ 1712 tvd.;Drill ahead as per DD/MWD and WP6 f/ 2171' t/ 2666' 505 gpm 1155 psi 60 rpm 6.4k tq on 5.8k tq off 9.1ppg MW 9.6 ppg ECD PUW 52k SOW 38k ROT 44k, Distance f/ plan 6.93' 5.71 high 3.92 left.;Hauled 202.5 bbls solids to KGFG&I Cumulative 766 bbls Hauled 237.5 bbls fluid to KGF G&I Cumulative 1989 bbls Daily Metal 0lbs Cumulative Metal 0 lbs Losses to hole 0 bbls Total losses to hole 139.6 bbl 4/8/2020 Cont directional drilling 9.875" intermediate hole from 2666' to 3161'. Rot wob 5K, 363 gpm-788 psi, 80 rpm-7300 ft/lbs on bott torque, 129 ft/hr ROP. Sliding wob 10 to 14K, 378 gpm-900 psi, 118 to 280 psi diff, 130 to 170 ft/hr ROP, MW 9.3/vis 48, ECD’s at 9.7 ppg, BGG 10 units. At 3161’ ', Made;numerous attempts to screen up to 170's from 120's on shakers. Could not get desired 500 gpm's even with 140's. Running centrifuge (discharge at 8.9 ppg) and water on at 40 bph.;At 3161' obtained survey, then pumped a 20 bbl hi-vis nutplug sweep around. Sweep back on time with no increase in cuttings. Last survey has us 9’ high and 6’ left of the line.;Pulled 17 stand wiper trip on elevators with no issue from 3161' to 2102'. Up wt 64K. Calculated hole fill = 6.9 bbls, actual hole fill = 6.1 bbls. Kept well on trip tank for rig service.;Serviced rig and topdrive, cont running water at 40 bph and mixing, trying to build enough volume to utilize sand trap under shakers, and reduce MW. Changed to 2 x 120 and 2 x 140 screens each on all three shakers. Loss rate at 1/2 bph during rig service.;TIH on elevators from 2102' to 3101'. Down wt 44K. Filled pipe and washed last stand to bottom at 3161'. No issue TIH.;Resumed directional drilling from 3161' to 3409', Rot wob 7K, 425 gpm-1075 psi, 80 rpm-7770 ft/lbs on bott torque, 200 ft/hr ROP. Sliding wob 10 to 14K, 429 gpm-1069 psi, 110 psi diff, 230 ft/hr ROP, MW 9.2/vis 53, ECD’s at 9.4 ppg, BGG 9 units.;Cont directional drilling from 3409' to 4093' 425 gpm 1150 psi 80 rpm 9k tq on bottom 8.5k tq off, 200 fph avg ROP sliding f/ direction, 7-15k WOB 68k PUW 40k SOW 52k ROT 9.5 ECD 9.2 MW.;Circulate bottoms up at full drilling rate 400 gpm 925 psi, shoot survey and take slow pump rates.;Short trip f/ 4093' t/ 3097' No hole issues calculated 7.4 actual 7.2.;Service rig and top drive.;RIH f/ 4093' t/ 4215' 405 gpm 1100 psi 80 rpm 9k tq on 8.5k tq off 68k PUW 40k SOW 54k ROT still sliding for direction, MW 9.2 ppg, ECD 9.56 ppg, Distance to plan 22.23' 3.68' High 22.02' Left.;Hauled 127 bbls solids to KGFG&I Cumulative 893 bbls Hauled 484 bbls fluid to KGF G&I Cumulative 2473 bbls Daily Metal 10lbs Cumulative Metal 10 lbs Losses to hole 0 bbls Total losses to hole 139.6 bbl 4/9/2020 Cont directional drilling Intermediate section from 4093’ to 4710'. Rotating wob 5 to 15K, 408 gpm-1234 psi, 75 rpm-8800 ft/lbs on bott torque, 75 to 200 ft/hr ROP. Sliding wob 10K, 405 gpm-1224 psi, 190 psi diff, 220 ft/hr ROP. MW 9.3/vis 55, ECD’s at 9.5 ppg, BGG 13 units.;Assembly still building in rotation. Had to mad pass slides. Received 3 loads casing, racked and tallied same, Halliburton on location and offloaded first batch lead cement in silo. Shipped diverter equipment to pad 34-31 at KGF.;Cont directional drilling Intermediate section from 4710' to 5084'. Rotating wob 5 to 15K, 410 gpm-1225 psi, 80 rpm-9700 ft/lbs on bott torque, 130 to 200 ft/hr ROP. Reduced ROP in rotary to 130 ft/hr and assembly dropped 2°/100'. Increased to 150 ft/hr, doing much better.;Received 2 more trailers of casing, racked same (total 189 jnts including shoe track). Received second batch lead cement (total of 585 sx at 12.0 ppg).;CBU at 415 gpm-1109 psi, 80 rpm-8800 to 10,509 ft/lbs off bott torque. Flow check.;Pulled 17 stand wiper trip from 5084' to 4051' No Hole issues hole took correct fill.;Service rig and draw works static loss rate while rig servicing 1.5 bph.;RIH f/ 4051' t/ 5021' Wash and ream last stand to bottom no hole issues.;Drilling Ahead f/ 5084' t/ 5329' 430 gpm 1430 psi 80 rpm 10k tq on 8.5k tq off, 80k PUW 45k SOW 60K ROT 9.2ppg MW 9.6 ECD Sliding f/ direction, Swab went out on mud pump #1.;Change swab and liner on pump #1 circulate with #2 208 gpm 400 psi.;Resume Drilling Ahead f/ 5329' t/5638' 430 gpm 1300 psi 80 rpm 10.5k tq on 9.8k tq off 82k PUW 50k SOW 62k ROT MW 9.2 ppg ECD 9.56 ppg EMW, Distance to plan 19.60' High 4.19' Left 19.15' Sliding and dropping angle, Madd Passing slide intervals.;Hauled 153 bbls solids to KGFG&I Cumulative 1046 bbls Hauled 412 bbls fluid to KGF G&I Cumulative 2885 bbls Daily Metal 0lbs Cumulative Metal 10 lbs Losses to hole 0 bbls Total losses to hole 139.6 bbl Cont directional drilling Intermediate section from 4093’ to 4710'. pgp perform Injectivity test on 16'' x 10 3/4'' annulus w/ test pump ;Commence drilling cement,g plugs, shoe track and 20' new formation from 2077' to 2171'. () pg g gpp flow rate on 16'' x10 3/4'' Annulus 0 pressure flowing .97 bph Cont directional drilling 9.875" intermediate hole from 2666' to 3161'. pp ;R/U and perform FIT t/ 12.91 ppg EMW 340 psi @ FIT 12.9 ppg 4/10/2020 Cont drilling intermediate section from 5638’ to 6049', dropping from 60° Inc and turning from 222° Azi. Rotating wob 6K, 426 gpm-1445 psi, 80 rpm-11,124 ft/lbs on bott torque, 200 ft/hr ROP. Sliding wob 3 to 11K, 424 gpm-1408 psi, 170 psi diff, 80 to 200 ft/hr ROP. MW 9.2/vis 56.;ECD’s at 9.4 ppg, BGG 15 units, max gas 20 units. Received last 9 joints of casing/shoe track and landing joint/hanger. Racked, tallied and drifted same. Have all three shakers dressed with 140 screens.;Cont drilling intermediate section from 6049' to 6193', still dropping and turning as planned. Rotating wob 8K, 429 gpm-1500 psi, 80 rpm-11,800 ft/lbs on bott torque, 150 ft/hr ROP. Sliding wob 7K, 430 gpm-1500 psi, 220 psi diff, 110 ft/hr ROP. MW 9.3/vis 50, ECD’s at 9.5 ppg.;BGG 8 units, max gas 36. Heating upright water tank for upcoming cement job. Sent AOGCC notice of upcoming casing run and cementing. Conductor gauge still reading zero psi.;CBU 1 1/2 times at 428 gpm-1285 psi, 80 rpm-12,013 ft/lbs off bott torque. Flow check = fluid dropping slowly in wellbore.;Pulled up hole 17 stands from 6193' to 5142' on elevators, no issues. Calculated hole fill = 7.7 bbls, actual hole fill = 8.4 bbls.;Service rig and topdrive. Well on trip tank, static loss rate at 2.24 bph.;RIH from 5142' to 6130', MU last stand, filled pipe, washed/reamed stand to bottom. Worked through tight spots @ 5629' and 5755'.;Drilling ahead f/ 6193' t/ 6813' 428 gpm 1600 psi 80 RPM 12-14k tq 8-12k WOB PUW 106k SOW 52k ROT 68k 9.2 ppg MW ECD 9.68 ppg, Distance to plan 26.73' high 3.02' left 26.56' Pumping sweeps every 500' Sliding for direction and Madd Passing slides.;Hauled 98 bbls solids to KGFG&I Cumulative 1144 bbls Hauled 232 bbls fluid to KGF G&I Cumulative 3117 bbls Daily Metal 0lbs Cumulative Metal 10 lbs Losses to hole 0 bbls Total losses to hole 139.6 bbl 4/11/2020 Cont directional drilling Intermediate section from 6813’ to 7144'. Sliding wob 8 to 10K, 426 gpm-1760 psi, 200 to 330 psi diff, 120 to 150 ft/hr ROP. Rotating wob 5 to 9K, 428 gpm-1605 psi, 80 rpm-14,760 ft/lbs on bott torque, 175 ft/hr ROP, MW 9.3/vis 56, ECD’s at 9.7 ppg.;BGG 11 units, max gas 111 units. Received 70 hollow vane centralizers.;Cont directional drilling Intermediate section from 7144' to 7432'. Rotating wob 8K, 430 gpm-1642 psi, 75 rpm- 16,400 ft/lbs on bott torque, 15,600 ft/lbs off bott torque, 150 ft/hr ROP. Sliding wob 7K, 429 gpm-1734 psi, 250 psi diff, 90 to 100 ft/hr ROP, MW 9.3/vis 52.;ECD’s at 9.6 ppg, BGG 5 units, max gas 147 units. Added two drums lube to suction pit to help with torque. Pumped 20 bbl sweep at 7208' while drilling stand down, then circulated sweep OOH. Came back 700 strokes early, 25% increase in cuttings. Received 15 bow spring centralizers.;Cont directional drilling Intermediate section from 7432' to 7434' and had a swab leaking. Circulated on one pump while C/O swab.;Continue Drilling Ahead f/ 7434' t/ TD @ 7800' 425 gpm 1580 psi 80 rpm 14-16k tq on 15k tq off MW 9.3 ppg ECD 9.65 PUW 146k SOW 60 ROT 84 Distance to plan 12.73' High 5.02' Left 11.70'.;Pump hi vis sweep around 425 gpm 1550 psi, back on time with no increase in cuttings return.;POOH f/ 7800' t/ 5262' No hole issues hole taking correct fill.;Hauled 107 bbls solids to KGFG&I Cumulative 1251 bbls Hauled 508 bbls fluid to KGF G&I Cumulative 3625 bbls Daily Metal 0lbs Cumulative Metal 10 lbs Losses to hole 0 bbls Total losses to hole 139.6 bbl 4/12/2020 Cont pulling up hole on elevators from 5262’ (up wt 88K) to 2104’ (up wt 55K), just inside surface casing with no issue. Calculated total hole fill for entire trip = 43.7 bbls, actual total hole fill = 50.5 bbls.;Serviced rig and topdrive. Cut and slipped drill line while C/O o-ring on topdrive service loop connection and float valve. Hole taking 2 bph while on trip tank.;TIH from 2104’ and started having issue with float function again. C/O relay and had no further issues. Set down 3 times 20K at 5983’ (slide), MU topdrive, filled pipe, washed/reamed down to 5994’, 405 gpm-1529 psi, 40 rpm no issue, set down 3 times 20K at 6108’ (slide), MU topdrive, filled pipe,;washed/reamed down to 6117’, 405 gpm-1529 psi, 40 rpm no issue, set down 20K at 6316’-6330’ and 6350’ (coal going into sand) but worked through on elevators, set down 3 times at 7480’ (middle of large coal), MU topdrive, filled pipe, washed/reamed down to 7544’ with no issue,;set down 20K 3 times at 7705’ (in sand, possible fill), MU topdrive, filled pipe, washed/reamed last two stands to bottom at 7800’, 413 gpm- 1497 psi, 40 rpm-13,700 to 15,600 ft/lbs off bott torque . Calculated displacement for entire trip = 108.7 bbls, actual displacement = 99.7 bbls.;Increased pump rate as we could to 450 gpm-1665 psi, 80 rpm-16,870 ft/lbs off bott torque. Decided to CBU 1 time to unload hole due to high ECD's (10 ppg). At bottoms up hole unloaded pretty good and a max of 183 units that dropped off fairly quick. Once shakers cleaned up,;pumped a 20 bbl hi-vis nut plug sweep around. Had 10% increase in cuttings with sweep to surface. Sweep came back 21 bbls early. ECD's down to 9.6 ppg at shut down. Flow check = slight fluid drop in wellbore over 10 minutes. NOTE: Conductor annulus gauge reading 145 psi, 4 hrs prior to high tide.;POOH on elevators from 7800' to 744', initial up wt 140K.;Stand back and L/D BHA unload sources, download MWD, Finish L/D BHA, Break bit Graded a 2,2, HC,N,F,I,ER,TD - 2,2,CT,S,X,I,NR,TD Clear floor.;Pull wear ring set test plug and change rams t/ 7 5/8'' solid body, R/U to test rams t/ 250/3500 psi f/ 5 min.;Hauled 66 bbls solids to KGFG&I Cumulative 1317 bbls Hauled 184 bbls fluid to KGF G&I Cumulative 3809 bbls Daily Metal 0lbs Cumulative Metal 10 lbs Losses to hole 72 bbls Total losses to hole 211.6 bbl 16 x 10 3/4" annulus = 145 psi at 19:00 hrs 144 psi at 05:45 hrs pg swab.;Continue Drilling Ahead f/ 7434' t/ TD @ g 7800' 42 Cont directional drilling Intermediate section from 6813’ to 7144'. TD int casing at 7800 ft 4/13/2020 Buttoned up upper ram doors after swapping from variables to 7 5/8” rams. Installed test joint, flooded surface lines and stack, tested annular at 250/2500 for 5 min each, tested upper rams at 250/3500 5 min each, good tests and charted same. Removed and LD test joint and plug.;RU Weatherford casing equipment, dummy ran hanger and landing joint and LD those down, staged centralizers, RU fill up hose on rig floor. Held PJSM with rig crew and Weatherford.;PU and MU 2 joint shoe track, BakerLok'd all connections. Filled and checked floats (good). Cont to PU single in hole with 7 5/8" L-80 DWC/C 29.7# casing, filling on the fly, topping off every 10 joints, using optimum MU torque of 23,400 ft/lbs. Stopped at 2119’, just above surface casing shoe,;MU circ swedge and topdrive, CBU 1 time staging up to 218 gpm-23 psi. Cont PU single in open hole from 2143', dwn wt 44K. Stopped at 4987', MU circ swedge and topdrive, CBU 1 time staging up to 254 gpm-124 psi. Cont single in hole from 4987' to 7735', ran a total of 94 centralizers. MU;26' landing joint/hanger, circ swedge and topdrive with wellhead Rep. Washed to bottom and landed hanger in wellhead, placing bottom of casing shoe at 7790.10' (top of FC at 7703.87').;Stage pump rate up to 264 gpm-403 psi while installing bail extensions, fold in gullwing piperacks and lay out liner for cementers. Spotted Halliburton cementers while circ and cond for cementing, M/U Cement head and lines to pump cement and wash up to cuttings box, Circulate through head and lines;while having PJSM.;Halliburton loaded lines with 5 bbls water and checked for leaks. Halliburton pressure tested lines at 1500 low 4000 high, good tests. Halliburton pumped 40 bbls 10.5 ppg Spacer at 4.5 bpm, 405 psi and shut down. Halliburton dropped bottom plug and pumped 225 bbls (585 sx) 12 ppg Class A lead cement;at 5 bpm 150 psi, followed by 53 bbls (245 sx) 15.3 ppg Class A tail cement at 5 bpm 250 psi. Halliburton dropped top plug, then displaced with 350 bbls 9.3 ppg 6% KCL Mud at 6 to 7 bpm 145 to 1475 psi. Slowed to 3 bpm with 30 bbl to go. Did bump the plug 350 bbls into displacement (calculated 354;bbls), held 1693 psi (FCP of 1200 psi) for 3 minutes, bled off and floats held. Bled back 2.5 bbls to truck. Had no Spacer returns to surface and no lead cement to surface. Added LCM to both lead and tail cement at ¼ ppb. Mix water temp 74 deg. Pumped 25% excess on both lead and tail. Lost 30.5 bbls;during displacement. Did not reciprocate pipe due to tight tolerance between hanger OD and ID of BOP stack. CIP at 05:00, 4-14-20. Washed up and RD Halliburton from rig floor. 4/14/2020 Drained BOP stack, removed landing joint, MU packoff assembly on landing joint, greased seals, RIH and landed same on top of hanger. RILD's, injected packing, tested void at 500 psi low for 5 min, 5000 psi high for 10 min. Good tests. LD landing joint.;Held PJSM with rig crew and Halliburton cementers. MU high pressure hose and hardline to 2” annulus valve on conductor, Halliburton loaded lines with 2 bbls water and checked for leaks, then established injection rates at ½ bpm = 97 psi and 1 bpm = 107 psi, shut down and shut in with 2 bbls away.;Halliburton pressure tested lines at 1300 low 2487 high, good tests. Halliburton mixed batch of 10% Calcium Chloride and 13.5 ppg FineCem. Halliburton pumped 2 bbls Calcium Chloride at .7 bpm-75 psi up to 1 bpm-86 psi, followed with 2 bbls fresh water at 1 bpm-90 psi, followed with 16.5 bbls;(135 sx) of 13.5 ppg FineCem cement at 1 bpm. ICP of 90 psi, FCP of 168 psi. Chased cement with 1 bbl fresh water and shut in at annulus. Added a total of 25 lbs MicroBond to cement while mixing and pumping. Mix water temp 74 deg. CIP at 09:30, 4-14-20. Washed up, RD and released Halliburton.;Prior to starting the topjob, water flow from 2" conductor outlet was 4 bph, and this was 1 1/2 hours before high tide (09:30).;RD plumbing, high pressure hose from conductor and cellar box, rolled up liner cementers were parked on. Installed test plug in wellhead, C/O both upper and lower rams to Hilcorp owned variable rams. Buttoned up doors.;RU test equipment, flood stack and surface lines, purge air. Obtained shell test. Started bringing in 4 1/2" CDS-40 DP and racking same, cont hauling mud to G&I, returning with fresh water into pits 9 and 10.;Test all BOPE at 250/3500 for 5 min each, 250/2500 on annular, testing with 4 1/2" test joint. Started building first batch of new 6% KCL/Polymer mud.;R/D testing equip, blew down choke manifold & lines, cont. working on changing over MP 1&2 to 5" liners.;Pulled test plug, installed 9" wear ring, run in 4 LDS, pulled new RKB measurement-20.27'.;Checked 100 jt of 4.5" DP on racks for minimum of 7" on box ends, culled 2 jt. for short box ends, replaced & re-strapped.;P/U & M/U Johnny Wacker to first jt., cont. P/U & singling in hole w/ 4.5" DP T/315', finished mixing first batch of 6% KCL/polymer mud.;Held PTSM, crew change, cont. P/U & singling in hole w/ 4.5" DP F/315'-T/1852' (60 jt.), finished changing over to 5" liners in both MP's, began mixing second batch of 6% KCL/polymer mud.;POOH racked back 30 stds. on ODS in derrick, cleaned & cleared rig floor, cont. mixing second batch of 6% KCL/polymer mud.;Aired out both MP's, fluid packed stand pipe to test 4" valve on MP#1 that was thought to be leaking (tested ok), tested centrifuge (ok), checked pressures on MP pulsation dampeners, MP #1=450 psi MP #2=0 psi, re-charged pulsation dampener #2 to 500 psi and monitor pressure.;Had Alaska E-line on location 03:30 hrs, spotted & R/U E-line unit, P/U & M/U CCL, centralizer, CBL, centralizer, Gama, & centralizer, total length of tool=24.58';Started RIH w/ CBL tools, current depth of 2900', while cont. to mixing second batch of 6% KCL/polymer mud & work on housekeeping around rig.;Hauled 26 bbls solids to KGFG&I Cumulative 1383 bbls Hauled 939 bbls fluid to KGF G&I Cumulative 4868 bbls Daily Metal 0lbs Cumulative Metal 10 lbs Losses to hole 31 bbls Total losses to hole 290 bbl 4/15/2020 RIH with Ak-E line CBL string, tagged up on wiper plugs, on top of float collar at 7703’ WLM, which coincides with casing run tally. Logged up hole at 42 ft/hr, looks like good cement coverage over CINGSA storage sand, TOC at 3675’. POOH RD released Ak-E line.;RU and tested 7 5/8” intermediate casing at 3500 psi for 30 min on chart (good test), pumped in 4.8 bbls & bled back 4.6 bbls. Checked conductor annulus for any water flow, annulus was on vac, closed in and will check again tomorrow.;Serviced rig and topdrive while waiting for word from Drilling Manager and Geologist on CBL results. Removed standalone test pump from cellar, spotted Sperry GeoSpan unit in cellar. Approved by Drilling Manager to PU BHA #3 and RIH to drill ahead.;Held PJSM with Sperry Reps and rig crew, PU and MU 6.75" Kymera bit, mudmotor w/1.5° bend, RFO=294.61°, DM collar, GM collar, ADR collar, ALD collar, CTN collar, Geo-Tap collar, and TM collar. MU topdrive and shallow pulse tested at 200 and 270 gpm. Good test. Held PJSM and installed sources.;NOTE: MWD Rep uploaded MWD data with tool on ground, prior to PU, due to length of tools while hanging from blocks. MU NM stabilizer, NM flex DC's, XO, HWDP x 4 jnts , XO, jars, XO, HWDP x 11 jnts for total BHA length of 698.22';Slip and cut 325' of drill line. recalibrated block height.;Started P/U & singling in the hole w/ 4.5" DP F/701'-T/1995', P/U-44K S/O-42K.;Held PTSM, crew change, cont. P/U & singling in the hole w/ 4.5" DP F/1995'-T/2865', filled pipe, P/U a total of 70 jt. blew down TD. P/U-63K S/O-42K.;Cont. RIH out of derrick, filling pipe every 2500', F/2865'-T/5034', preformed pulse test on MWD tool (ok), blew down TD. P/U-92K S/O-45K.;Cont. RIH out of derrick F/5034'-T/7516', filled pipe, began washing down to top of FC, current depth of 7643'. P/U- 168K S/O-58K ROT-73K SPP-1272 psi GPM-207 RPM-40 TQ-13K.;Hauled 0 bbls solids to KGFG&I Cumulative 1383 bbls Hauled 0 bbls fluid to KGF G&I Cumulative 4868 bbls Daily Metal 0lbs Cumulative Metal 10 lbs Losses to hole 0 bbls Total losses to hole 290 bbl gj d Halliburton cementers.pg p pg gj g MU high pressure hose and hardline to 2” annulus valve on conductor, Halliburton loaded lines with 2 bbls water and checked for leaks, then establishedgp injection rates at ½ bpm = 97 psi and 1 bpm = 107 psi, shut down and shut in with 2 bbls away.; r swapping from variables to 7 5/8” rams. Installed test joint, flooded surface lines and stack, tested annular at 250/2500 g p Halliburton pumped 40 bbls 10.5 ppg Spacer at 4.5 bpm, 405 psi and shut down. Halliburton dropped bottom plug and pumped 225 gg pp ppgp p p pp p g p p bbls (585 sx) 12 ppg Class A lead cement;at 5 bpm 150 psi, followed by 53 bbls (245 sx) 15.3 ppg Class A tail cement at 5 bpm 250 psi. Halliburton ( ) ppg p p y ( ) ppg p p dropped top plug, then displaced with 350 bbls 9.3 ppg 6% KCL Mud at 6 to 7 bpm 145 to 1475 psi. Slowed to 3 bpm with 30 bbl to go. Did bump the plugopp p p g p ppg p p p gp 350 bbls into displacement (calculated 354;bbls), held 1693 psi (FCP of 1200 psi) for 3 minutes, bled off and floats held. Bled back 2.5 bbls to truck. RIH with Ak-E line CBL string, tagged up on wiper plugs, on top of float collar at 7703’ WLM, which coincides with casing run tally. g ggpp M/U Cement head and lines to pump cement CBL over 7 5/8" casing pump cement into OOA cement 7 5/8" csg MIT casing 3500 psi ggggg ;Test all BOPE at 250/3500 for 5 min each, 250/2500 on annular, testing with 4 1/2" test joint. Started 4/16/2020 Washed down from 7643' and tagged wiper plugs at 7699’. Drilled plugs, shoe track, rathole and 20’ new formation to 7820’. had a max of 44 units at bottoms up. Drilled at 257 gpm-1591 psi, 42 rpm-16,759 ft/lbs on bott torque.;CBU one time at 258 gpm-1600 psi, 43 rpm-15,400 ft/lbs off bott torque.;Parked string at 7811', RU spare test pump on kill line and drill string, flooded lines, closed upper rams, pumped 37.5 gallons to achieve 858 psi with 9.4 ppg mud, giving us an EMW of 12.5 ppg FIT, held 10 min and bled down to 812 psi. Good test. Bled back 36 gallons, RD test equipment,;opened rams and lined up to drill. Opened 2" valve on conductor, 16" x 10 3/4" annulus on slight vac, closed back in. Received 1st load of 4 1/2" casing, racked same.;Displaced well with 312 bbls 8.9 ppg mud, shipped out 312 bbls 9.4 ppg mud. 258 gpm-1280 psi, 31 rpm-17,792 ft/lbs off bott torque. Received 2nd load casing and racked same.;Directionally drilled 6 3/4" hole from 7820’ to 7888’. Rotating wob 7 to 8K, 258 gpm-1511 psi, 45 rpm-17,329 ft/lbs on bott torque, 100 ft/hr ROP, MW 9.0/vis 50, ECD’s at 9.8 ppg, BGG 31 units, max gas 40 units. Bumping lube up to 1.5% in active system due to high torque. Had numerous issues;getting detection with MWD tools. Cleaned pump suction screens, swapped pumps, swapped from "A" mode to "B" mode and able to obtain survey.;Cont drilling 6 3/4" hole from 7888' to 8076', rot wob 6-8K, 246 gpm-1476 psi, 75 rpm-17,600 ft/lbs on bott torque, 100 ft/hr ROP. Sliding wob 2 to 13K, 271 gpm-1522 psi, 144 psi diff, 44 to 130 ft/hr ROP. MW 9.1/vis 48, ECD's at 9.9 ppg, BGG 19 units, max gas 92 units. Had more issue with;detection of MWD tools. Swapped back over from "B" mode to "A" mode and obtained survey. Cont drilling ahead. Received 3rd load 4 1/2" casing.;Cont drilling 6 3/4" hole F/8039'-T/8260', got new SPR's, changed out MWD sensator on stand pipe in mezz deck on connection to help with tool detection along w/ continuing to clean suction/discharge screens on connections, and adding lube to help mitigate high TQ-17K,;Cont. slide/drilling 6 3/4" hole F/8260'-T/8326', pumped 20 bbl Hi-Vis sweep w/ walnut, cont. drilling ahead while pumping sweep around T/8388', finished pumping sweep around, sweep came back 11 bbls early w/ a 20% increase, P/U-150K S/O-70K ROT-93K GPM-260 RPM-80 SPP-1877;DIFF-271 on bottom TQ-17.4K off bottom TQ-21K, cont. to bring up lube percent on active system to 2%. Finished drifting, strapping, & tally first 120 jts of 4.5" 12.6 ppf DWC casing.;Held PTSM, crew change, cont. slide/drilling 6 3/4" hole F/8388'-T/8513', began bumping up lube concentration to 2.5% by volume due to high TQ holding after 2%, on bottom TQ-17.5K off bottom TQ-21K, seen significant decrease in TQ, on bottom TQ-15K off bottom TQ-13.5K, P/U-140K;S/O-75K ROT-95K GPM-255 RPM-76 SPP-1864 DIFF-286.;Cont. slide/drilling 6 3/4" hole F/8513'-T/8650', pumped 20 bbl Hi-Vis sweep w/ walnut, while cont. to drilling ahead, cont. bring lube up to 2.5%. P/U-152K S/O-76K ROT-96K GPM-258 RPM-73 SPP-1863 psi DIFF-305 on bottom TQ-13K off bottom TQ-12-14K.;Cont. slide/drilling 6 3/4" hole F/8650' to current depth of 8728', sweep came back 9 bbls early, w/ a 10% increase in cutting, cont. to bring up lube concentration to 2.5%. P/U-130K S/O-84K ROT-98K GPM-270 RPM-70 SPP-1835 psi DIFF-307 on bottom TQ-12K off bottom TQ-9K.;Distance to well plan: 13.59' 2.90' Low 13.28' Left Total K-revs=9.6;Hauled 25 bbls solids to KGFG&I Cumulative 1408 bbls Hauled 474 bbls fluid to KGF G&I Cumulative 5342 bbls Daily Metal 1 lbs Cumulative Metal 11 lbs Losses to hole 0 bbls Total losses to hole 290 bbl 4/17/2020 Directionally drilled 6 ¾” hole from 8728’ to 8883’, planned wiper trip depth. Rot wob 7 to 8K, 256 gpm-1830 psi, 75 rpm-9300 to 10,000 ft/lbs on bott torque, 111 ft/hr ROP, MW 9.2/vis 54, ECD's at 10.2 ppg, BGG 24 units, max gas 751 units.;Pumped a 20 bbl hi-vis nut plug sweep around with no increase in cuttings to surface, 270 gpm-1400 psi, 85 rpm-8500 to 8700 ft/lbs off bott torque. Obtained survey and SPR’s at 8883’, flow check = static.;Pulled up hole 2 stands on elevators, from 8883' to 8761', up wt 135K, then MU topdrive and mad passed from 8761' to 8011'. 264 gpm-1584 psi, 60 rpm-8100 ft/lbs backream torque. At 8011' up wt 104K. Finished rack, tally and drift of 4 1/2" casing (290 jnts total on location) Recieved rig fuel.;Blew down TD, serviced rig and topdrive, changed oil in DWKS.;Tied in Sperry Geo-Span unit to mud line and flow line, pressure tested lines (ok), circulated through Geo-span and functioned (ok), GPM-260 SPM-106 SPP-1345 psi Flow-18%, cleaned suction/discharge screens on MP's (clean).;TIH on elevators F/8010'- T/ 8883', washing last stand to bottom w/ no issues or fill and got calculated pipe displacement during trip.;Resumed directional drilling 6-3/4" hole F/8883'- T/8904', pumped 20 bbl Hi-Vis sweep w/ walnut while drilling ahead T/9008', sweep came back on time w/ no cutting increase, cont. maintaining 2% by volume of lube in mud system, On bottom TQ-10K Off bottom TQ-8K.;P/U-132K S/O-89K ROT-102K GPM-250 SPP-1881 psi Diff-350 RPM=80 WOB- 8K.;Held PTSM, crew change, cont. directional drilling 6-3/4" hole F/9008'-T/9128', P/U-136K S/O-90K ROT-103K GPM-258 SPP-1852 psi RPM-78 Diff- 314 WOB-8K MW-9.15 ppg On bottom TQ-10K Off bottom TQ-9K, cont to maintain 2% lube concentration in mud system.;Cont. directional drilling 6-3/4" hole F/9128'-T/9235', pumped 20 bbl Hi-Vis sweep w/ walnut while drilling ahead T/9246', sweep came back w/ no cutting increase P/U-135K S/O-89K ROT-104K GPM-252 SPP-1838 psi RPM-71 Diff-330 WOB-6-8K MW-9.2 ppg On bottom TQ-10K Off bottom TQ-9K.;Cont. directional drilling 6-3/4" hole F/9246' to current depth of 9353', cont. working on housekeeping around rig. P/U-139K S/O-90K ROT-104K GPM-264 SPP-1940 psi RPM-70 Diff-324 WOB-8-11K MW-9.2 ppg On bottom TQ-11-12K Off bottom TQ-9K.;Distance to plan: 9.41' 1.51' Low 9.28' Right K-Revs=17.2 Max Gas-746 units;Hauled 56 bbls solids to KGFG&I Cumulative 1464 bbls Hauled 224 bbls fluid to KGF G&I Cumulative 5566 bbls Daily Metal 0 lbs Cumulative Metal 11 lbs Losses to hole 0 bbls Total losses to hole 290 bbl . Drilled plugs, shoe track, rathole and 20’ new formation to 7820’. Directionally drilled 6 ¾” hole from 8728’ to 8883’, planned wiper trip depth. p pp g us an EMW of 12.5 ppg FIT, held 10 min and bled down to 812 psi. Good 4/18/2020 Directionally drilled 6 3/4" hole from 9353’ to 9683’. Rotating wob 8K, 252 gpm-1802 psi, 70 rpm-11,700 ft/lbs on bott torque, 90 to 130 ft/hr ROP. Sliding wob 7K, 253 gpm-1807 psi, 300 psi diff, 100 ft/hr ROP. MW 9.2/vis 50, ECD’s at 10.0 ppg, BGG 133 units, max gas 690 units. Pumped a sweep;while drilling ahead at 9505' with maybe 10% increase in cuttings. Tore out Weaver ISO fuel tank and containment, shipped ISO/trailer back to Weaver.;Directionally drilled 6 3/4" hole from 9683’ to 9871’, planned wiper trip depth. Rotating wob 8K, 265 gpm-1994 psi, 75 rpm-13,719 ft/lbs on bott torque, 90 to 130 ft/hr ROP. Sliding wob 4K, 265 gpm-1959 psi, 299 psi diff, 120 ft/hr ROP. MW 9.3/vis 48, ECD’s at 10.3 ppg, BGG 21 units,;max gas 1016 units. Received shoe track and swell packer, sent 3 joints to Halliburton shop in Sterling to get RA tags installed.;CBU and mad pass slide at 265 gpm- 1696 psi, 60 rpm-13,765 ft/lbs off bott torque. Obtained survey, SPR's and flow checked = static.;Pulled up hole from 9871', 17 stands on elevators to 8876' with no issues. Up wt 170K.;Serviced rig and topdrive, flushed centrifuge.;TIH on elevators F/8876'-T/9871' washing last std to bottom w/ no issues or fill.;Cont. directional drilling 6-3/4" F/9871'-T/9877", pumped 20 bbl Hi-Vis sweep while drilling ahead T/9868', encounter tight spot/high TQ @ 9968', sweep came back 18 bbl early w/ no increase in cuttings. On bottom TQ-22K Off bottom TQ-22K.;Racked back 1 std., circulate & rotated working pipe F/9873'- T/9934' to reduce TQ down to 14-16K, latched up std. out of derrick, washed & reamed F/9934'-T/9968'.;Resumed drilling F/9968'-T/9994', P/U-160K S/O- 92K ROT-115K GPM-265 SPP-1974 psi RPM-75 Diff-270 WOB-3K.;Pumped 20 bbl Hi-Vis/High wt. sweep while rotating & reciprocating pipe waiting for sweep to come back around.;Held PTSM, crew change, cont. circulating sweep out of hole, sweep came back 9 bbls early w/ no increase in cutting;Resumed directional drilling 6-3/4" F/9994'-T/10,018', pumped 20 bbl Low Vis=34/Low wt.=9.1 ppg sweep w/ walnut & condet @ 10,006', attempting to relieve BHA of any sticking clays on stabs while drilling ahead.;Sweep came back 10 bbls early w/ no increase in cuttings , On bottom TQ-12-13K Off bottom TQ-15-16K.;Cont. directional drilling 6-3/4" F/10,018'-T/10180', adding a vis cup of condet to pipe on connection and bring lube concentration back to 2& by volume. P/U-161K S/O-96K ROT-116K GPM-250 SPP-1484 psi RPM-67 Diff-326 WOB-8K. On bottom TQ-13.5K Off bottom TQ-12.2K.;Cont. directional drilling 6-3/4" F/10,180' to current depth of 10,273', P/U-161K S/O-96K ROT-116K GPM-250 SPP-1484 psi RPM-67 Diff-326 WOB-8K. On bottom TQ-13.5K Off bottom TQ-12.2K.;Distance to well plan: 5.64' 3.00' Low 4.77' High K-Revs-29.7;Hauled 45 bbls solids to KGFG&I Cumulative 1509 bbls Hauled 180 bbls fluid to KGF G&I Cumulative 5746 bbls Daily Metal 0 lbs Cumulative Metal 11 lbs Losses to hole 0 bbls Total losses to hole 290 bbl 4/19/2020 Drilled 6 3/4" production hole from 10,273’ to TD at 10,511’ md/7959' tvd. Rot wob 7K, 252 gpm-1846 psi, 65 rpm-15,000 ft/lbs on bott torque, 27 to 100 ft/hr ROP, MW 9.3/vis 54, ECD’s at 10.3 ppg, BGG 40 units, max gas 2396 units. Final survey has us 7.76' low and 4.38' left of the line.;Obtained survey, SPR’s then pumped a 20 bbl hi-vis, hi-wt, nutplug sweep around with 10% increase in cuttings at 243 gpm-1585 psi, 60 rpm-12,900 to 13,500 ft/lbs off bott torque. Up wt 172K, dwn wt 98K, rot wt 121K, ECD's at 10.2 ppg, BGG 70 units.;Mad pass logged bottom section to correlate Geo-Tap tool to MWD logs, oriented high side, worked out torque, parked bit at 10,492’ (sample depth of 10,385’) while circulating at 257 gpm-1565 psi, gas spiked at 1932 units just prior to bottoms up then dropped off quick. Racked back;two stands, PU Kelly joint, mad passed from 10,380’ to 10,340’, oriented high side, worked out torque, parked bit at 10,352’ (sample depth of 10,244’) while circulating at 257 gpm-1564 psi, gas spiked to 2144 units just prior to bottoms up then dropped off quick. LD Kelly joint, racked back 3 stands;mad passed from 10,174' to 10,142', oriented high side, worked out torque, parked bit at 10,133' (sample depth of 10,025') while circulating at 257 gpm-1433 psi, gas spiked at 3760 units just prior to bottoms up then dropped off over 10 minutes. Started dusting MW up from 9.4 to 9.6 while circ and;sampling. P/U working single. Sample #4 at 9869' we had a spike of 3729 units prior to bottoms up that dropped off over 10 minutes (MW in 9.6/out 9.4), Sample #5 mad passed F/10,035'-T/10,000', orientated tool face, set on sample depth @ 9842',;after bringing MW up to 9.6 ppg had a gas spike of 1179 unit @ 9842', proceeded to dust up MW to 9.7 ppg, back ground gas dropped back to 51 units. Sample #6 mad passed F/9858'-T/9923', orientated tool face, set on sample depth @ 9783'. Racked back 4 stds. Sample #7 mad passed F/9685'- T/9650',;orientated tool face, set on sample depth @ 9524'. Sample #8, pulled up hole, set string in tension and set on sample depth @ 9498'. Racked back 1 std. Sample #9 mad passed F/9605'-T/9498', orientated tool face, set on sample depth @ 9389'.;Sample #10 mad passed F/9502'-T/9482', orientated tool face, set on sample depth @ 9347'. Sample #11 pulled up hole, set on sample depth @ 9331'. Racked back 1 std. Sample #12 pulled up hole, set on sample depth @ 9285'. Racked back 2 std., P/U single.;Sample #13 mad passed F/9339'-T/9304', orientated tool face, set on sample depth @ 9347'. Racked back 1 std. Sample #14 pulled up hole, set on sample depth @ 9125'. Rack back 2 std. Sample #15 mad passed F/9125'-T/9100', orientated tool face, set on sample depth @ 9104'.;While mad passing- P/U-150K S/O-80 ROT-110 GPM-254 SPP-1350 psi RPM-50 K-Revs-34.4;Hauled 16 bbls solids to KGFG&I Cumulative 1525 bbls Hauled 64 bbls fluid to KGF G&I Cumulative 5810 bbls Daily Metal 1 lbs Cumulative Metal 12 lbs Losses to hole 0 bbls Total losses to hole 290 bbl 4/20/2020 Cont mad passing, orienting highside, working out torque and Geo-Tap sampling from 15th station at 8997’, up to 8678’ for 22nd station. Mad pass at 180 ft/hr, 257 gpm-1605 psi, 60 rpm-9222 ft/lbs off bott torque, MW 9.8/vis 47, ECD’s at 10.7 ppg, BGG 9 units, max gas 33 units.;Cont mad passing, orienting highside, working out torque and Geo-Tap sampling from 22nd station at 8678', up to 8295' for 28th station of 37. Mad pass at 180 ft/hr, 257 gpm-1605 psi, 60 rpm-9421 ft/lbs off bott torque, MW 9.7/vis 50, BGG 7 units, max gas 29 units.;Cont mad passing, orienting highside, working out torque and Geo-Tap sampling from 28th station at 8295', up to 7904' for 37th an final station. Mad pass at 180 ft/hr, 255 gpm-1577 psi, 58 rpm-8810 ft/lbs off bott torque, MW 9.75/vis 47, BGG 2 units, max gas 16 units.;Held PTSM, crew change, pulled into shoe F/7904'-T/7764', blew down TD.;Serviced rig- greased & inspected crown, blocks, TD, DW, iron roughneck, and linkage, checked fluid levels in floor & pump motors.;RIH F/7764'-T/10511', tagged up @ 10,397' & 10,480' w/ 15K set down (coals), Kelley up and washed down through w/ no issues, P/U E-Kelley and washed to bottom, had 8" of fill.;Started CBU, had gas spike @ 1623 stks=3271 units, at BU had max gas of 3309 units, circulated till gas dropped out, pumped 20 bbl Hi-Vis/weighted sweep, currently circulating sweep around. P/U-172K S/O-89K ROT-116K GPM-251 SPP-1675 psi RPM-60 TQ-12K.;Hauled 14 bbls solids to KGFG&I Cumulative 1539 bbls Hauled 64 bbls fluid to KGF G&I Cumulative 5874 bbls Daily Metal 0 lbs Cumulative Metal 12 lbs Losses to hole 0 bbls Total losses to hole 290 bbl Drilled 6 3/4" production hole from 10,273’ to TD at 10,511’ md/7959' tvd. TD well at 10511 ft 4/21/2020 Cont circulate hi-vis hi-weight sweep out of hole at 253 gpm-1684 psi, 70 rpm-9200 to 13,000 ft/lbs off bott torque. Sweep back on time with no increase in cuttings. Shut down and flow check = static.;Pulled up hole 5 stands on elevators from 10,511' to 10,206', then back to bottom to CBU. Up wt 165K, dwn wt 90K, no issues.;CBU one time at 260 gpm-1719 psi, 75 rpm-12,870 ft/lbs off bott torque. At bottoms up we had a max of 2468 units continue circ weight up t/ 9.9 ppg.;Pulled up hole 5 std f/ 10,511' t/ 10,204' then back to btm with no issues and correct disp.;Circ circ btm up w/ max gas of 50 units. GPM-251 SPP-1629 psi, RPM-73 TQ-12K Offline- Brought in OBM to pit#9 from tank farm at BCU-04RD, proceeded to centrifuge back from 12.7 ppg to 9.0 ppg.;Flow check (static).;POOH on elevators F/10,511-T/shoe, flow check (static), blew down TD, R/D HES Geo-span. Cal Dis= 18 bbls Act Dis= 18.6 bbls Diff=+.6.;Flow check (static), pumped slug, blew down TD.;Began POOH L/D 4.5" DP F/7825'-T/3179', vacuuming wiper ball through pipe, cleaning threads, & installing thread protectors. Marked & cull 2 bad jts. for galled threads. P/U-60K S/O-47K Offline continued centrifuging OBM.;Held PTSM, crew change, resumed POOH L/D 4.5" DP F/3179'-T/BHA #3 , vacuuming wiper ball through pipe, cleaning threads, & installing thread protectors. Finished centrifuging OBM to 8.9 ppg. Opened valves on conductor by 10-3/4" annulus (slight vac).;L/D BHA #3- HWDP, jars. currently L/D flex collars. Cal Disp.- 57 bbls Act Disp.-57.2 bbls Diff Disp.-.2 bbls.;Hauled 102 bbls solids to KGFG&I Cumulative 1641 bbls Hauled 289 bbls fluid to KGF G&I Cumulative 6163 bbls Daily Metal 0 lbs Cumulative Metal 12 lbs Losses to hole 0 bbls Total losses to hole 290 bbl 4/22/2020 Continue and finish L/D BHA #3- Bit graded 1-1-WT-A-E-I-No-TD and 623 K-revs Cal Disp.-62.5 bbls Act Disp.-62.8 bbls Diff Disp.-.2 bbls.;Clear and clean floor;P/up wash tool Rih w/ 64 std out of derrick t/ 3967' w/ cal disp.;Cut and slip 70' drlg line while monitoring hole on trip tank and service rig w/ slight seepage losses service rig and crew chg.;Pumped slug, resumed POOH L/D 4.5" DP F/3967' -T/surface, vacuuming wiper ball through pipe, cleaning threads, & installing thread protectors. Cal Disp.-27.4 bbls Act Disp.-29.8 bbls Diff.- 2.4 bbls.;Cleared & cleaned rig floor, drained stack, BOLDS & pulled wear ring, P/U & test run 10-3/4" OD hanger, RKB-22', R/U Weatherford casing equip. Held PJSM w/ rig crew, Weatherford, & company Rep.;P/U & M/U 4.5" shoe track (Baker lock), tested floats (ok), cont. RIH w/ 4.5" 12.6 ppf DWC/C casing F/surface-T/2560', torquing to 6150 ft/lbs., filling on the fly and topping off every 10 jts. P/U-30K S/O-28K Cal Disp.-11.4 bbls Act Disp.-12.1 bbls Diff.- .7 bbls.;Held PTSM, crew change, cont. RIH w/ 4.5" 12.6 ppf DWC/C casing F/2560'-T/3909', M/U XO/TIW to string, CBU X2, max gas 4452 units, B/O XO/TIW, blew down TD, P/U-37K S/O-32K GPM-220 SPP-143 psi (run 3 RA marker jts. in string).;Cont. RIH w/ 4.5" 12.6 ppf DWC/C casing F/3909'-T/4777', P/U swell packer (OD 6.4"), installed a total of 86 solid body centralizers.;Cont. RIH w/ 4.5" 12.6 ppf DWC/C casing F/4777' to current depth 6397', filling on the fly & topping off every ten jts. P/U-50K S/O-37K Cal Disp.-28.5 bbls Act Disp.-28.8 bbls Diff.- .3 bbls;Hauled 0 bbls solids to KGFG&I Cumulative 1641 bbls Hauled 97 bbls fluid to KGF G&I Cumulative 6260 bbls Daily Metal 0 lbs Cumulative Metal 12 lbs Losses to hole 5 bbls Total losses to hole 295 bbl 4/23/2020 Cont. RIH w/ 4.5" 12.6 ppf DWC/C casing F/6397' t/7786' just inside shoe , filling on the fly & topping off every ten jts. P/U-61K S/O-45K.;CBU X2, max gas 4190 units @ 11.5 bbl pumped and 2nd spike @ btm/up 2871 units and 2nd btm/ @ 350 units , dn pump and blew down lines.;Exit shoe and RIOH p/up 4.5" 12.6 ppf DWC/C casing staging in f/7786' t/9130' , filling on the fly & topping off every ten jts. P/U-70K S/O-48K w/ no issues.;CBU X2, max gas 4827 units @ 138 bbl pumped and 2nd spike @ btm/up @ 5000+ units Max out system w/ 6% increase in flow but no gain and 2nd btm/up dn to 320 units , dn pump and blew down lines.;Resume RIOH p/up 4.5" 12.6 ppf DWC/C casing staging in f/9130' t/10,476' , filling on the fly & topping off every ten jts. w/ no issues P/U 70K S/O-57K P/up landing jt and work hanger through stack and land same w/ shoe @ 10,502' ok w/ cal disp = 48.1 and act disp = 49.8 bbls w/ 1.7 bbl gain.;Stage up rate t/ 5.5 bpm , max gas 4645 units @ 183 bbl pumped and 2nd btm/up dn t/ 235 units , dn pump. Held PJSM w/ rig crew, HES cmt, Peak, Baroid.;R/up cmt head and lines to landing jt.;Circulated water through cmt lines to cutting box to clear lines, P/T lines 800 low/4,000 high, lined up down hole, pumped 40 bbl 105 ppg tune spacer @ 4 bpm-370 psi, dropped bottom plug, pumped 103 bbls of class A 12 ppg lead cmt @ 5 bpm-315 psi, followed by 18.2 bbls of class A 15.3 ppg.;tail cmt @ 3.5 bpm-96 psi, dropped top plug, displaced w/ 6%KCL/polymer 10 ppg mud @ 6 bpm-910 psi. slowed pump to 3 bpm w/ 10 bbls to go, bumped plug @ 157 bbls into displacement (calculated 158.3 bbls). Held 1735 psi (FCP=1000 psi) for 2 min. Bled off and floats held, Bled back.;1.5 bbls to HES truck. No spacer or cmt observed at surface, lost 9.5 bbls during job, had 1/4 ppb of LCM in cmt, CIP @ 18:30 hrs. R/D and released HES. Off line racked, strapped, tally, and drifted 2-7/8" PH-6 work string.;Observed slight flow from landing jt, stabbed & M/U TIW & XO w/ gauge, monitored well for pressure, built to 60 psi, bled off pressure (no flow), started hauling off mud & cleaning pits.;Had NOV Rep Sam on location, B/O landing jt. M/U running tool & pack off, set pack, RILD's, pulled/ L/D landing jt. & running tool, P/U 2-7/8" test jt & M/U TWC to bottom, screwed TWC into hanger profile to test 2-7/8".;R/U testing equip., flooded BOP stack w/ water, purged air, functioned tested annular, upper & lower rams.;tested 2-7/8" on annular 250 psi Low/ 2500 psi high 5/5 min, Upper & lower rams- 250 psi Low/ 3500 psi high 5/5 min (ok). Gave Weatherford 2 hr. notice.;Held PTSM, crew change, R/D testing equip., B/O TWC & test jt. L/D same.;R/U 2-7/8" PH-6 Weatherford handling equip., held PJSM w/ crew and Weatherford Reps.;P/U & M/U BHA #4, 3-3/4" roller cone bit, scraper, & XO, started singling in hole F/surface-T/1227', mud started U- tubing out pipe, shut down & mixed slug. Built 300 bbls of 6% KCL brine in pits 9&10.;Broke circ., pumped 4 bbls down pipe, pipe came dry, cont. singling in hole w/ 2-7/8" work string, current depth of 1992'. Cont. working on cleaning pits & prepping rig for move. P/U-23K S/O-23K Cal Disp.-9.1 bbls Act Disp.-9.1 bbls.;Hauled 12 bbls solids to KGFG&I Cumulative 1653 bbls Hauled 423 bbls fluid to KGF G&I Cumulative 6683 bbls Daily Metal 0 lbs Cumulative Metal 12 lbs Losses to hole 9 bbls Total losses to hole 304 bbl for 2 min. Bled off and floats held, Bled back.;1.5 bbls to HES truck. No spacer or cmt observed at surface, lost 9.5 bbls during job, RIH with prod casing (4 1/2") pgjgg pumped 40 bbl 105 ppg tune spacer @ 4 bpm-370 psi, dropped bottom plug, pumped 103 bbls of class A 12 ppg lead gp pp ppgp@pppp pgpp ppg cmt @ 5 bpm-315 psi, followed by 18.2 bbls of class A 15.3 ppg.;tail cmt @ 3.5 bpm-96 psi, dropped top plug, displaced w/ 6%KCL/polymer 10 ppg mud @@ p p y ppg @ p p pp p p g p py ppg 6 bpm-910 psi. slowed pump to 3 bpm w/ 10 bbls to go, bumped plug @ 157 bbls into displacement (calculated 158.3 bbls). Held 1735 psi (FCP=1000 pp ppp gppg@ p ( ) cement 41/2" gg RIH w/ 4.5" 12.6 ppf DWC/C casing F/3909'-T/4777', P/U swell packer (OD 6.4"), installed a total of 86 solidp( j g) pp g body centralizers.;Cont. RIH w/ 4.5" 12.6 ppf DW C/C casing F/4777' to current depth 6397', p R/U Weatherford casing equip. H 4/24/2020 Continue P/up rih w/ 2-7/8" 7.9# P-110 PH-6 work string F/ 1992'. T/ 7256' Pump 4 bbl slug @ 2750', 4100 due to wet pipe flow over Cont. working on cleaning pits & prepping rig for move. P/U-52K S/O-32K Cal Disp.-18.4 bbls Act Disp.-22.5 bbls.;Continue P/up rih w/ 2-7/8" PH-6 work string f/ 7256' t/10,418' with in one foot of tally R/dn cmt silo, water tank & lines, mwd shack and equipment, mud loggers shack & load and prep equipment for move.;Make up circ head pin, attempted to circ., pumps kept stalling due to high pressure, R/U to reverse circ. attempted to pump again w/ no luck due to high pressure.;R/D reverse circ. equip., R/U to rack back 2-7/8" work string in derrick.;POOH racking back 2-7/8" work string F/10,418'-T/8691', while changing to 4.5" liners in MP #2.;M/U TIW and drive sub to stump, screw into TIW w/ TD, broke circ., while pulling string in upward motion using MP #2, staged pump up, ICP=1332 psi GPM-91 Flow-7%, pumped string volume of (45 bbls) staged pump up to GPM-135 SPP-2020 psi Flow-9%, @ STS= GPM-135 SPP-1719 psi Flow-9%.;Shut down pump, B/O circ. head pin, cont. TIH w/ 2-7/8" work string F/8691'-T/9725'. Getting calculated pipe displacement.;M/U circ. head pin, broke circ., w/ string in upward motion using MP #2, staged pump up, ICP=1167 psi GPM-91 Flow-7%, pumped string volume of (50 bbls) staged pump up to GPM-131 SPP-1954 psi Flow-9%, @ STS= GPM-131 SPP-1925 psi Flow-9%. P/U-48K S/O-35K.;Held PTSM, crew change, cont. TIH w/ 2-7/8" work string F/9725'-T/10,413'. Cal Disp.-1.8 bbls Act Disp.-2.4 bbls Diff-.6.;Broke circ. w/ string in upward motion using MP #2, staged pump up, ICP=1279 psi GPM-91 Flow-6%, pumped string volume of (54 bbls) staged pump up to GPM-135 SPP-2120 psi Flow-9%, @ STS= GPM-135 SPP-2125 psi Flow-9%.;Circ. STS X2 to balance out MW, P/U-70K S/O-32K.;Downed pump, R/U testing equip. flooded lines, purged air, preformed 4.5" casing test to 3500 psi for 30 min on chart (ok), pumped in 2.36 bbls bled back 2.3 bbls, R/D testing equip. & blew down lines.;Currently circ. while cutting MW back w/ centrifuge from 9.9 ppg., prepping to displace well over to 6% KCL brine. GPM-146 SPP-2540 psi Flow-9%.;Hauled 20 bbls solids to KGFG&I Cumulative 1673 bbls Hauled 305 bbls fluid to KGF G&I Cumulative 6988 bbls Daily Metal 0 lbs Cumulative Metal 12 lbs Losses to hole 0 bbls Total losses to hole 304 bbl 4/25/2020 Continue circ. cutting MW back w/ centrifuge t/ 9.5 ppg., prepping to displace well over to 6% KCL brine.;Reverse circ 20 bbl high vis sweep and chg well over t/ 6% KCL brine.;Pooh l/dn and servicing 2-7/8" PH-6 work string f/ 10,413' t/ surface, B/D & L/D BHA #4, continue clean pits , Prep equipment for move and Build move and stage loads, had hand spring cleaning at beaver creek, tested water well 34-31 @ KGF @ 85.7 bph.;Welder freed sea-can from pre-mix tank for modifications, changed both MP's over to 5.5" liners for next well. Called out NOS well head Rep Sam.;Held PTSM, crew change, R/D Weatherford equip, cleared & cleaned floor, installed BPV,;Washed up flow box, pumped through bleeders, pumps, stand pipe/ Kelly hose, kill lines, & choke w/ Barakleen/water, blew down TD, Kelly hose/stand pipe back to pumps, & choke back to pits.;Bleed down koomey, opened ram doors, pulled rams for inspection, buttoned up doors, removed flow line & unchained BOP stack. cont. cleaning in pits & prepping rig for move.;Disconnected HYD control lines from stack, installed trolley beams, pulled riser, disconnected floor drain hoses, pulled mouse hole, dropped catch pan, R/U bridge crane to P/U stack. Broke stack loose BOP/spool connection, P/U & trolley BOP out of sub, broke loose double spool,;called out NOS Rep Sam, P/U & B/O middle spool, currently cleaning void & prepping to N/U dry hole tree.;Hauled 28 bbls solids to KGFG&I Cumulative 1701 bbls Hauled 427 bbls fluid to KGF G&I Cumulative 7415 bbls Daily Metal 0 lbs Cumulative Metal 12 lbs Losses to hole 0 bbls Total losses to hole 304 bbl surface annulus = dead 4/26/2020 Finish cleaning prepping to install dry hole tree.;Tail in and set and N/U dry hole tree. test Void 500L 5 min and 5000H15 min good pull BPV install TWC and test tree t/ 250L and 5000H 5/5min good install tree cap and secure well.;Nip/Dn Choke Hcr and manual valves and choke kill lines remove shaker possum bellies r/dn rig floor equipment. R/dn tarps roofs spot crane.;Last report / release rig to rig move t/ KU -24-32 AFE# 2011534D during road restrictions @ 85% having to strip loads dn.;Hauled 0 bbls solids to KGFG&I Cumulative 1701 bbls Hauled 0 bbls fluid to KGF G&I Cumulative 7415 bbls Daily Metal 0 lbs Cumulative Metal 12 lbs Losses to hole 0 bbls Total losses to hole 304 bbl 16" X 10-3/4" = dead 10-3/4" X 7-5/8" = dead 7-5/8" X 4-1/2"= dead Continue P/up rih w/ 2-7/8" 7.9# P-110 PH-6 work string F/ 1992' p @ U testing equip. flooded lines, purged air,p preformed 4.5" casing test to 3500 psi for 30 min on c MIT casing to 3500 psi / 30 min Activity Date Ops Summary 5/5/2020 PTW and JSA. Spot equipment and rig up line wiper. TP - 0. Halliburton had go back and get the pit liner.,RIH w/Halliburton CBL tool and tag at 10,410'. Log between 50 to 60' per min from 10,410' to 5000'. Engineer said it look like good with spots of fair cement up to approx. 5000' and had bad cement there. Engineer said they would have the final log to us later tonight.,Rig down equipment and turn well back over to field. 5/6/2020 PTW, JSA with SLB coil , Cruz crane operator and Hilcorp Rep.,Rig up SLB coil unit, pump truck, N2 pump. Spot 2x iron racks, choke skid, lubricator box, and BOPE stand. Make up 1502 iron. Spot return tank. Rig up BOPE hydraulic hoses.,24 hr BOPE test witness notification sent 5/5/2020 @ 12:51 PM. Witness waived by Jim Regg via email on 5/5/2020 @ 13:07 . Start BOPE test. Test all rams and valves 250/4000 psi. Good PT.,Coil on hold until decision is made on results of final CBL log. We will not be running another CBL. Plan to blow well dry and pressure up in the AM. Locati on secure. 5/7/2020 PTW, SJA with SLB, Cruz and HAK rep.,Fire up SLB equip. Pick injector head and 10' lubricator. Spot Air Liquid transport next to N2 pump. Make up coil connector , 2x 1.75" OD stinger and 1.75" OD ball drop nozzle. Stab on well. PT stack 250/4000 psi.,Initial WHP 0 psi. RIH with 1.75" coil taking returns up CT. Cool down N2. Pressure test N2 lines 250/4000 psi. 2000' online with N2 down 4.5" tubing taking returns up 1.75" coil . Tagged twice at 10,388' CTMD. Pick up to 10,375' and blow well dry. 160 bbls of completion fluid returned to surface.,POOH from 10,375'. Conti nue taking N2 returns monitoring for fluid. Returns all gas. Close in choke. Start pressuring up well while POOH. Tagged up at surface. 3 vac truck loads manifested to G&I. 215,000 scf pumped. Or 2,308 gallons. 2600 gallons of liquid N2 remain.,Rig down SLB. Stage equipment on edge of pad. Location secu re. NOTE: returns were darker than normal. Saw crude oil in return tank. 5/13/2020 Already signed in and mobe to location. PTW and JSA. Yellowjacket had to go back to shop and get 8 perf charges to break the 26 ' gun into a 12 and 14 gun (LB 3B sand). Rig up lubricator. PT to 250 psi and had an o-ring leak. Put new oring and had field hand go down and get bring them a pit liner. PT to 250 psi low and 3500 psi high. TP - 2280 psi,RIH w/Gun #1, (Btm of LB3B) 2-7/8"x14' Razor HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 9872' to 9886' with 2202.4. Spotted and fired shot. After 5 min 2203.1 psi, 10 min - 2203.1 and 15 mi n - 2203.1 psi. POOH. All shots fired and gun was dry.,RIH w/Gun #1a, (Top of LB3B) 2-7/8"x12' Razor HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 9860' to 9872' with 2208.7 psi. Fired gun 2208.7 psi. After 5 min - 2210.7 psi, 10 min - 2210.6 psi and 15 min - 2 210.0. POOH. All shots fired and gun was dry.,RIH w/Gun #2, (LB 3A)) 2-7/8"x14' Razor HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 9836' to 9850'. Spotted and fired gun with 2246 psi on tubing. After 5 min - 2250.1 psi, 10 min - 2251.3 psi and 15 min - 2252.4 psi. POOH. All shots fired and gun was dry.,RIH w/Gun #3, (LB 3)) 2-7/8"x9' Razor HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 9778' to 9787'. Spotted and fired gun with 2320.0 psi on tubing. After 5 min - 2323.2 psi, 10 min - 2324.3 psi, and 15 min - 2325.5 p si.. POOH. All shots fired. Gun was Dry.,Rig down off well and turn over to field. 5/27/2020 Start at 0500. Sign in and mobe to location. PTW and JSA. Spot and rig up equipment. PT lubricator to 250 psi low and 3500 psi high.,RIH w/GPT tool and tie into OHL. Find solid fluid level at 9280' with 1640 psi on well. Looks like soapy fluid level above 9280'. Ran a correlation lo g and send to town. POOH.,RIH w/ Gun #1; 2-7/8"x20' Razor HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Told to add 4' to cor relation log. Added 4', spotted and fired gun from 9510' to 9530' with 1787.6 psi. After 5 min - 1794.0 psi , 10 min - 1798.8 psi, 15 min - 1803.3 psi. POOH. A ll shots fired gun was wet as expected.,RIH w/ Gun #2; 2-7/8"x17' Razor HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 9389' to 9406'. Spotted and fired gun with 1927.4 psi. After 5 min - 1931.1 psi, 10 min - 1935.6 psi and 15 min - 1939.1 psi. POOH All shots f ired, gun was wet.,RIH w/ Gun #3; 2-7/8"x6' Razor HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 9329' t o 9335'. Spotted and fired gun with 2031.8 psi. After 5 min - 2037.2 psi, 10 min - 2040.3 psi and 15 min - 2043.2 psi. POOH All shots fired, gun was wet.,Rig down lubricator and equipment. 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enjamin Hand Digitally signed by Benjamin Hand Date: 2020.04.24 14:28:50 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.04.24 14:47:27 -08'00' TD Shoe Depth: PBTD: Jts. 1 51 Yes X No X Yes No Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: 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?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: 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: Yes X No Bump press Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface? Yes X No Spacer returns?Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: 168 Casing (Or Liner) Detail Float Shoe 11 3/4 Rotate Csg Recip Csg Ft. Min.PPG Shoe @ 2143 FC @ Top of Liner 220 35 185 Spud Mud CASING RECORD County Kenai State Alaska Supv.S. Hauck/ J. Riley Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.CLU 15 Date Run 4-Apr-20 Component Size Wt.Grade THD Make BTC Innovex 1.60 2,143.67 2,142.07 Setting Depths Length Bottom Top Csg Wt. On Hook:Type Float Collar:No. Hrs to Run:TOP OUT JOB10.5Spacer 50 13.5 16.5 1 9.3 6 195/202 1030 36 HaliburtonFIRST STAGE530 2,099.00 15.8 60 210% Calcium Chloride Bump press Visual Bump Plug? 0 9:30 4/14/2020 0 15:35 4/4/2020 0 12 160 8.34 1 1/1 2,143.002,151.00 CEMENTING REPORT Csg Wt. On Slips:Type of Shoe:Bullnose Casing Crew:Weatherford Halliburton 0 8.66 Floats Held www.wellez.net WellEz Information Management LLC ver_04818br Bump Plug? Fresh Water 10 3/4'' Casing 10 3/4 45.5 L-80 DWC-C 41.13 2,142.07 2,100.94 Float Collar 11 3/4 BTC Innovex 1.24 2,100.94 2,099.70 10 3/4'' Casing 10 3/4 45.5 L-80 DWC-C 2,074.05 2,099.70 25.65 10 3/4'' Casing Pup 10 3/4 45.5 L-80 BTC 2.40 25.65 23.25 Hanger 16 BTC 1.15 23.25 22.10 FineCem 135 0.73 Lead 375 2.4 Tail 275 1.17 4.2 primary cement job Surface casing OOA sqz. 16.5 bbls cmt TD Shoe Depth: PBTD: Jts. 2 187 Yes X No Yes X 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? Yes X No % Returns during job Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: 2.19 Class A 245 1.24 4.5 21.80 Hanger 10 3/4 0.40 21.80 21.40 7,703.87 24.00 7 5/8'' Casing Pup jt 7 5/8 29.7 L-80 DWC-C 2.20 24.00 1.33 7,705.20 7,703.87 7 5/8'' Casing jt 7 5/8 29.7 L-80 DWC-C 7,679.87 Float Collar 8 5/8 DWC-C Weatherford L-80 DWC-C 83.47 7,788.67 7,705.20 www.wellez.net WellEz Information Management LLC ver_04818br 5 12 225 Type of Shoe:Antelope Bullnose Shoe Casing Crew:Weatherford Every Joint from 7790' up to 5961', then every other joint from 5961' up to 1978'. Total of 94 centralizers ran. Class A 585 7,790.107,800.00 CEMENTING REPORT Csg Wt. On Slips: 6% KCL Mud 7 5/8'' Casing Jt 7 5/8 29.7 15.3 53 Bump press CBL Bump Plug? 5:00 4/14/2020 1,900 15 9.35 6 1240FIRST STAGE10.5 40 DWC-C Antelope 1.43 7,790.10 7,788.67 Csg Wt. On Hook:Type Float Collar:Weatherford No. Hrs to Run: Setting Depths Component Size Wt.Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.CLU 15 Date Run 13-Apr-20 CASING RECORD County Kenai State Alaska Supv.R Pederson / J Riley 278 0 278 6% KCL 350/353 1640 0 Halliburton Ft. Min.PPG9.3 Shoe @ 7790.1 FC @ Top of Liner7,703.87 Floats Held Casing (Or Liner) Detail Float Shoe 8 5/8 Rotate Csg Recip Csg 7 5/8" intermediate casing (Note CBL indicated good bond over Sterling C ... gls 'This int casing set to isolate Sterling C CINGSA pool at approx 5000 TVD . Lost 30 bbls TD Shoe Depth: PBTD: Jts. 2 23 1 17 1 9 1 46 156 Yes X No Yes X No 80 Fluid Description: Liner hanger Info (Make/Model):Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg)Rate (bpm):Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface? Yes X No Spacer returns?Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: Class A 250 2.19 Class A 85 1.24 5 8,305.09 4.5" casing 4 1/2 12.6 L-80 DWC/C Vam 1,880.12 8,305.09 6,424.97 8,711.54 8,344.72 RA marker C 4 1/2 12.6 L-80 DWC/C Vam 39.63 8,344.72 40.95 8,752.49 8,711.54 4.5" casing 4 1/2 12.6 L-80 DWC/C Vam 366.82 RA marker B 4 1/2 12.6 L-80 DWC/C Vam 9,443.39 4.5" casing 4 1/2 12.6 L-80 DWC/C Vam 690.90 9,443.39 8,752.49 10,417.06 9,484.53 RA marker A 4 1/2 12.6 L-80 DWC/C Vam 41.14 9,484.53 1.30 10,418.36 10,417.06 4.5" casing 4 1/2 12.6 L-80 DWC/C Vam 932.53 Innovex Float collar 5 DWC Innovex Installed 88 centralizers 4.5" casing 4 1/2 12.6 L-80 DWC/C Vam 82.41 10,500.77 10,418.36 www.wellez.net WellEz Information Management LLC ver_04818br 3.5 Type of Shoe:Innovex Casing Crew:Weatherford 22.00 12 103 10,502.0010,511.00 CEMENTING REPORT Csg Wt. On Slips:55,500 6% KCL/polymer 18:30 4/23/2020 6,414 15.3 18.2 Bump press CBL Bump Plug? 157/158.3 1735 157 CementerFIRST STAGE10.5Tuned spacer 40 10 6 95 1000 Csg Wt. On Hook:70,000 Type Float Collar:Innovex No. Hrs to Run:20 6,395.30 24.94 2.44 24.94 22.50 6,370.364.5" casing 4 1/2 12.6 L-80 DWC/C 10-3/4"Atlas Bradford 10 3/4 22.50 Vam 15.01 L-80 DWC/C Vam Vam 6,410.31 Atlas Bradford 0.50 4 1/2 12.6 4 1/2 12.6 L-80 DWC/C 4 1/2 12.6 L-80 DWC/C Vam 6,416.316L-80 DWC/C 6.00 DWC Innovex 1.35 10,502.12 10,500.77 6,410.31 6,395.30 8.66 6,424.97 6,416.31 Setting Depths Component Size Wt.Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.CLU 15 Date Run 23-Apr-20 CASING RECORD County Kenai State Alaska Supv.S Hauck / J Richardson 10,417.06 Floats Held 60.5 121 0 121 6% KCL/polymer Rotate Csg Recip Csg Ft. Min.PPG10 Shoe @ 10502.12 FC @ Top of Liner 67 73.7 10 4.5" DWC pup 4.5" DWC pup Casing (Or Liner) Detail Innovex shoe 4.5" DWC pup Swell Packer 5 Note: Swell /cement packer completion Production casing DWC Innovex 1.35 10,502.12 10,500.77 6,416.31Swell Packer Swell packer at 6400 ft Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.04.23 17:08:09 -08'00' Taylor Wellman By Samantha Carlisle at 8:32 am, Apr 24, 2020 320-176320-178 DSR-4/27/2020gls 5/6/20 CT X + CBL over 4.5" liner Guy Schwartz SFD 5/7/2020 5/1/20 + Perforations approved below 9170 ft only. (>1500 ft TVD below Sterling C pool) CT and N2 ONLY + MIT-IA to 2500 psi 10-407 5/8/2020 dts 5/8/2020 JLC 5/8/2020 ( Verify IA has been tested to 2500 psi .. send chart to AOGCC) (swell packer at approx 6400 ft) (CBL on 4.5" casing)Forward 4.5" CBL to AOGCC Verbal Approval __________________________________________________________________________________________ ____ Perfs approved from LB 1A and deeper. ( CINGSA gas storage at 7400-7580 ft MD) Approval for remaining perf intervals pending. 1500 ft TVD from Sterling C ________ NOT APPROVED CBL5/5/20on4.5" (CINGSA GAS STORAGE APPROX 7400-7600 FT) 7790 FT MIT-IA to 2500 psi CBL run on 7 5/8" on 15-APR-20 ---------------- Gas storage 7400-7600 7790' Perforations below 9178ft approved. Not Approved STATE OF ALASKA J/�I+ Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Supry ARVA40 BOPE Test Report for: CANNERY LOOP UNIT 15 - Comm Contractor/Rig No.: Hilcorp 169. PTD#: 2200030 ' DATE: 4/7/2020 ` Inspector Jeff Jones Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Hauck/Riley Rig Rep: Davis/Trick Inspector Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopJJ200409132248 Rams: Annular: Valves: MASP: Type Test: INIT 250/3500 250/2500' 250/3500 " 3192 Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Upper Kelly 1 P/F Lower KellyI Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank P P System Pressure 2950 ` P Housekeeping: P Pit Level Indicators P P Pressure After Closure 1500 P PTD On Location P ` Flow Indicator P P 200 PSI Attained 24 P Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 86 -_ P Well Sign P H2S Gas Detector —P P Blind Switch Covers: _ all P Drl. Rig P MS Misc NA- INA_ Nitgn. Bottles (avg): 4(d,)2550 _ _ _P_ Hazard Sec. P Check Valve 0 NA ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly 1 P - Lower KellyI - —1 P Ball Type P Inside BOP l P FSV Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 NA No. Valves 15 P Annular Preventer _ 1 _ _ 1F' _ P _ Manual Chokes I P, #1 Rams 1 2 7/8 x 5" P Hydraulic Chokes 1 P, #2 Rams 1 Blind P CH Misc 0 NA #3 Rams 1 2 7/8 x 5" FP ✓ #4 Rams 0 NA _ #5 Rams _ _ 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 '3 1/8" FP Quantity P/F HCR Valves 2 -21/16-3 1/8" P--- Inside Reel Valves —_ 0--" NA Kill Line Valves 2 - 211/1611 FP i Check Valve 0 NA BOP Misc 0 NA Number of Failures: 3 Test Results Test Time 12 Remarks: Hilcorp rig #169 personnel performed the tests today in a safe manner with 3 failures observed. The manual kill and manual choke valves on the BOPE stack failed the pressure tests and were repaired and passed retests. The lower variable rams also failed o cold pressure and were rebuilt and successfully retested. The gas detection and pit volume totalizer alarm systems were tes a and operated properly. The rig appeared clean, orderly and in good condition. s Contractor/Rig No.: Hilcorp 169 Operator: Hilcorp Alaska, LLC Well Class: DEV MISC. INSPECTIONS: P/F P/F Location Gen.: P_ " Housekeeping: _ _P_ Warning Sign P 24 hr Notice: P Well Sign: P - Drlg. Rig. _P_ Misc: NA GAS DETECTORS: Visual Alarm Methane: P - P__ Hydrogen Sulfide: FP FP - Gas Detectors Misc: _ 0___NA �'r'' ATE OF OIL AN i, jAS CONSERVAI /�7��/ Reviewed Bye , i�� '� i'Z�CG�Gf P.I. SupryJljp DIVERTER Test Report for: CAT` &ffLaa 16 -Z Comm PTD#: 2200030 - DATE: 4/1/2020 - Inspector Bob Noble - Insp Source Operator Rep: Hauck/Riley Rig Rep: Davis/Huntington Inspector Inspection No: divRCN200403180658 Related Insp No: TEST DATA MUD SYSTEM: P/F Visual Alarm Trip Tank: _ P__ _P__ Mud Pits: P P Flow Monitor: P_ P ' Mud System Misc: 0 NA ACCUMULATOR SYSTEM: P/F Time/Pressure P/F Systems Pressure: 3000 P Pressure After Closure: 1400 P 200 psi Recharge Time: 25__ P___ Full Recharge Time: 100 P Nitrogen Bottles (Number of):_4 P Avg. Pressure: 2550 P Accumulator Misc: 0 NA DIVERTER SYSTEM: Size P/F Designed to Avoid Freeze-up? P Remote Operated Diverter? P ' No Threaded Connections? P " Vent line Below Diverter?__ ___ P ' Diverter Size: 21.25 _- P Hole Size: 13.5 P Vent Line(s) Size: 16 P " Vent Line(s) Length: 122.6 P Closest Ignition Source: 95 P " Outlet from Rig Substructure: 113.4 P " Vent Line(s) Anchored: P, Turns Targeted / Long Radius: NA Divert Valve(s) Full Opening: - P Valve(s) Auto & Simultaneous: Annular Closed Time: 40 - P - Knife Valve Open Time: 4 P Diverter Misc: 0 NA Number of Failures: 2 V Test Time: 3 Remarks: The H2S senser in the cellar failed and had to be changed out to get a FP. "TATE OF ALASKA OIL AtvD Reviewed By: GAS CONSERVATION COMMISSION P I Suprv. DIVERTER Test Report for: CANNERY LOOP UNIT 15 Comm Contractor/Rig No.: Saxon 169 PTD#: 2200030 DATE: 4/1/2020 Inspector Bob Noble Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Hauck/Riley Rig Rep: Davis/Huntington Inspector Well Class: DEV Inspection No: divRCN200403180658 Related Insp No: MISC. INSPECTIONS: GAS DETECTORS: Visual Alarm Methane: P - P Hydrogen Sulfide: FP "Fp Gas Detectors Misc: 0 NA TEST DATA MUD SYSTEM: P/F Location Gen.: P Housekeeping: P Warning Sign P " 24 hr Notice: P Well Sign: P Drlg. Rig. P _ Misc: NA GAS DETECTORS: Visual Alarm Methane: P - P Hydrogen Sulfide: FP "Fp Gas Detectors Misc: 0 NA TEST DATA MUD SYSTEM: P/F Visual Alarm Trip Tank: P P Mud Pits: _ P • P__ Flow Monitor: P - P Mud System Misc: 0 NA ACCUMULATOR SYSTEM: P/F Time/Pressure P/F Systems Pressure: 3000 P - Pressure After Closure: 1400 P 200 psi Recharge Time: 25 P Full Recharge Time: 100 P ' Nitrogen Bottles (Number of): 4 P ' Avg. Pressure: 2550 P Accumulator Misc: 0 NA DIVERTER SYSTEM: Size P/F Designed to Avoid Freeze-up? P, Remote Operated Diverter? P No Threaded Connections? P Vent line Below Diverter? P ' Diverter Size: 21.25 P . Hole Size: 13.5 P Vent Line(s) Size: 16 P Vent Line(s) Length: 122.6 P " Closest Ignition Source: 95 P Outlet from Rig Substructure: 113.4 P Vent Line(s) Anchored: P Turns Targeted / Long Radius: NA Divert Valve(s) Full Opening: P Valve(s) Auto & Simultaneous: Annular Closed Time: 40 P Knife Valve Open Time: 4 P Diverter Misc: 0 NA Number of Failures: 2 ✓ Test Time: 3 Remarks: The H2S senser in the cellar failed and had to be changed out to get a FP. ASSOCIATED FINANCE &ASSURANCE CORP Legend �-I-ci 1 Cannery Loop Unit 15—SHL Other Surface Well Locations CLU 15 SHL 660ft Radius • Other Bottom Hole Locations Well Paths 0 Oil and Gas Unit Boundary ASSOCIATED ------ FINANCE 8 'ASSURANCE CORP ('061681 34 Darts E. - '( k�ia{kovski �� '{z 4 ry LLI t.r GG , ..rev. W t ," �t .•. �P**' O° ('winery Loop Unit 15 SHL t�A CLU 11 ALU 03 DONNA D ° t a.. - FREDRICKSON O ° ° t- •aa_ i < eC c + O w- Hilcoro O ¢ 4 Alaska, o �. o ° mss t; 0, r►l�F p►�.),. yam` 41 TA r f r' rr it VAN ANTWERP AVE i . tAD L3 r rre .r ."L' � �1 ,✓ , -..•. r Iel _ 0 250 500 Cannery Loop Unit Feet N CLU -15 Well Alaska State Plane Zone 4, NAD27 llilvorp Alaska, LLC wp04 Map Date: July 10, 2019 THE STATE F1 Mal � 1 ;63- WA GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager 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.00gcc.alaska.gov Re: Cannery Loop Field, Sterling Undefined, Beluga and Upper Tyonek Gas Pools, CLU 15 Hilcorp Alaska, LLC Permit to Drill Number: 220-003 Surface Location: 2539' FSL, 2464' FEL, SEC. 4, T5N, RI I W, SM, AK Bottomhole Location: 2205' FNL, 963' FEL, SEC. 8, T5N, RI I W, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jer M. Price air DATED this M-* day of January, 2020. STATE OF ALASKA AL,,, -)KA OIL AND GAS CONSERVATION COMM—ON PERMIT TO DRILL 20 AAC 25.005 RECEIVED JAN 0 8 2020 1 a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. S e used for: Drill E Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone ❑✓ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑✓ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑✓ Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022224484 CLU 15 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 11,690' TVD: 9,121' Cannery Loop Unit Sterling Uncle lin d Gas Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2539' FSL, 2464' FWL, Sec 4, T5N, R11 W, SM, AK Private Fee, ADI -391791, ADL 391792, ADL Beluga Gas Pool 391790, ADL324602 Upper Tyonek Gas Pool Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1382' FNL, 732' FEL, Sec 8, T5N, R11 W, SM, AK LOCI 78-156 2/15/2020 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 2205' FNL, 963' FEL, Sec 8, T5N, R11 W, SM, AK 807 3297' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 53' 15. Distance to Nearest Well Open Surface: x-280837 y- 2396118 Zone -4 GL / BF Elevation above MSL (ft): 35' Ito Same Pool: 955' CLU 05RD 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 60 degrees Downhole: 4104 Surface: 3192 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" 109# X-56 Weld 120' Surface Surface 120' 120' Driven 13-1/2" 10-3/4" 45.5# L-80 DWC 2,100' Surface Surface 2,100' 1,690' L - 879 ft3 / T - 316 ft3 9-7/8" 7-5/8" 29.7# L-80 DWC 7,638' Surface Surface 7,638' 5,199' L - 1253 ft3 / T - 299 ft3 6-3/4" 4-1/2" 12.6# L-80 DWC 6,289' 11,689' 9,121' L - 795 ft3 / T - 93 ft3 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): 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 ❑✓ 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program Time v. Depth Plot ❑✓ ❑ Shallow Hazard Analysis ❑ Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: David Gorm Authorized Name: Monty Myers Contact Email: d orm hilcor .COm Authorized Title: Drilling Manager Contact Phone: 777-8333 Authorized Signature: — Date: (-9.207-3 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: a 50- 133—Z —0 0 — 00 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: Other: , 3 5DD pp, /SU Samples req'd: Yes ❑ No ER", Mud log req'd: Yes ❑ No[]� / s �r H2S measures: Yes ❑ No Directional svy req'd: Yes EVNo ❑❑/ C :,� 4- L,1 ` ,�/ /� '"'� � Spacing exception req'd: Yes Inclination -only sv req'd: Yes No 9 p q' ❑ No L� Y Y q' ❑ L� C e, zi tf z Post initial injection MIT req'd: Yes ❑ No❑ c ORIGINAL APPROVED BY Approved by: COMMISSIONER THE COMMISSION / ate5ubmit Form and Form 1 40 e ed 5%2017 his permit is valid for Z4 months from the date of approvafpeT g Attac ments in Duplicate Hilcorp Alaska, LLC CLU #15 Drilling Program Cannery Loop Rev 0 December, 2019 CLU #15 Drilling Procedure ovens 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 NIU 21-1/4" 2M Diverter...............................................................................................................11 11. Drill 13-1/2" Hole Section.............................................................................................................12 12. Run 10-3/4" Surface Casing.........................................................................................................14 13.0 Cement 10-3/4" Surface Casing...................................................................................................17 14.0 BOP NIU and Test.........................................................................................................................20 15.0 Drill 9-7/8" Hole Section..............................................................................................................21 16.0 Run 7-5/8" Intermediate Casing.................................................................................................23 17.0 Cement 7-5/8" Intermediate Casing............................................................................................26 18.0 Drill 6-3/4" Hole Section..............................................................................................................29 19.0 Run 4-1/2" Production Casing....................................................................................................32 20.0 Cement 4-1/2" Production Casing..............................................................................................35 21.0 RDMO...........................................................................................................................................37 22.0 Completions..................................................................................................................................37 23.0 BOP Schematic.............................................................................................................................38 24.0 Wellhead Schematic.....................................................................................................................39 25.0 Days Vs Depth................................................................................................................................40 26.0 Geo-Prog.........................................................................................................................................41 27.0 Anticipated Drilling Hazards......................................................................................................42 28.0 Hilcorp Rig 169 Layout.................................................................................................................45 29.0 FIT Procedure................................................................................................................................46 30.0 Choke Manifold Schematic...........................................................................................................47 31.0 Casing Design Information...........................................................................................................48 32.0 9-7/8" Hole Section MASP............................................................................................................49 33.0 6-3/4" Hole Section MASP............................................................................................................50 34.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................51 35.0 Surface Plat (NAD 27)...................................................................................................................52 36.0 Directional Plan (wp05)................................................................................................................53 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 1.0 Well Summary Well CLU #15 Pad & Old Well Designation CLU #15 is a grass roots well on Cannery Pad #3 Planned Completion Type Perforated, TBG less Target Reservoir(s) Beluga Planned Well TD, MD / TVD 11,689' MD / 9,120' TVD PBTD, MD / TVD 11,609' MD / 9,043' TVD Surface Location (Governmental) 2539' FSL, 2464' FWL, Sec 4, TSN, RI IW, SM, AK Surface Location (NAD 27) X=280837.3, Y=2396118.6 Surface Location (NAD 83) X=1420857.52, Y=2395880.21 Top of Productive Horizon (Governmental) 1382' FNL, 732' FEL, Sec 8, TSN, R11W, SM, AK TPH Location (NAD 27) X = 277590.77, Y = 2392247.31 TPH Location (NAD 83) X = 1417610.95, Y = 2392009.51 BHL (Governmental) 2205' FNL, 963' FEL, Sec 8, TSN, R11 W, SM, AK BHL (NAD 27) X = 277346.69, Y = 2391429.47 BHL (NAD 83) X = 1417366.86, Y = 2391191.66 AFE Number AFE Drilling Days AFE Completion Days AFE Drilling Amount AFE Completion Amount Maximum Anticipated Pressure (Surface) 3,192 psi Maximum Anticipated Pressure (Downhole/Reservoir) 4,104 psi Work String 4-1/2" 16.6# 5-135 CDS-40 RKB — GL 53' Ground Elevation 35' BOP Equipment 11" 5M T3 -Energy Single Ram 11" 5M T3 -Energy Double Ram 11" 5M T3 -Energy Single Ram Page 2 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 2.0 Management of Change Information Hilcorp �sy comp�y Hilcorp Alaska, LLC Changes to Approved Permit to Drill Date: Subject: Changes to Approved Permit to Drill for CLU #15 File #: CLU #15 Drilling and Completion Program Any modifications to CLU #15 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be communicated to and approved by the AOGCC. Sec I Page I Date Approval: Prepared: Drilling Manager Drilling Engineer Procedure Change Approved I Approved Date Date Page 3 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 3.0 Tubular Program: Hole OD (in) ID Drift Conn Wt Gracie Conn Burst Collapse Tension Section _._.?_. (in) OD (#/ft) (psi) (psi) (k -lbs) Cond 16" 15" - - 109 X-56 Weld 13-1/2" 10-3/4" 9.95" 9.875" 11.75" 45.5 L-80 DWC 5210 2480 1040 9-7/8" 7-5/8" 6.875" 6.75" 8.5" 29.7 L-80 DWC 6890 4790 683 6-3/4" 4-1/2" 3.958" 3.833" 5" 12.6 L-80 DWC 8430 7500 288 4.0 Drill Pipe Information: Hole OD (in) Section " H) (in) TJ ID in TJ OD in Wt #/ft Grade Cana. Burst _ si Collapse si Tension (k -lbs) All 4-U2" 3.826 2.6875" 5.25" 16.6 5-135 CDS40 17,693 16,769 468k All casing will be new Page 4 Version 0 December, 2019 CLU #15 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. • 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. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Detailed Daily Plan Forwards • Distributed to daorm@hilcop.com and mmyers(j hilcop.com 5.3 Afternoon Updates • Submit a short operations update each work day to pmazzolinighilcorp.com, mm.} ersghilcorp.com, dRorm e,hilcorp.com and cdinger@a,hilcorp.com 5.4 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. 5.5 EHS Incident Reporting • Health and safety: Notify EHS field coordinator. • Environmental: Drilling Environmental coordinator • Notify Drilling Manager & Drilling Engineer • Submit Hilcorp Incident report to contacts above within 24 hrs 5.6 Casing Tally • Send final "As -Run" Casing tally to mmyersghilcorp.com, dizornighilcorp.com and cdin eg_rghilcorp.com 5.7 Casing and Cmt report • Send casing and cement report for each string of casing to mmyerskhilcorp.com, daornighilcorp.com and cdingerghilcorp.com 5.8 Hilcorp Kenai Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer David Gorm 907.777.8333 505.215.2819 daorm@hilcorp.com Completion Engineer Ted Kramer 907.777.8420 985.867.0665 tkramer@hilcorp.com Geologist Benjamin Siks 907.777.8388 907.229.0865 bsiks@hilcorp.com Reservoir Engineer Anthony McConkey 907.777.8460 amcconkey@hilcorp.com Drlg Environmental Coord Keegan Fleming 907.777.8477 907.350.9439 kflemina@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 caiones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 Version 0 December, 2019 Hi1COrp EneW Company 6.0 Planned Wellbore Schematic PROPOSED SCHEMATIC llik-." AI -1a. I.LC 10 M5L= 38' 16' la3/4" 4-112" TD=11,688' (MJ) / 9,121' MO PI31'D=11.609' (MD) / 9.043' (TVD) CASING DETAIL CLU #15 Drilling Procedure Rev 0 Cannery Loop Well: CLU #15 PTD: TBD Size Type Wt/Grade/Conn ID Top Btm 16" Cwiductor 109/X-56/Weld 15" Surf 120' 10-3/4" Surface 4S.SJL-BO/5WC 9.950" Surf 2,100' 7-S/8" Intermediate 29.7 / L-8©/ DWC 6.87S" Surf 7,638' 4-112" Production 12-6/L-80/DWC 3958" 5,400' 11.689' G t � Nlti�a JEWELRY DETAIL )vGi a tr' 1 J4, .'��„ 13 OPEN HOLE /CEMENT DETAIL 10.314"T -H2 --L's of cement in 13.5" Hole. Returns to Surface (50% excess) 7-5/Bm " 276 BBL's of cement in 9-7/8" Hole. Est TOC @ 1,900' (25% excess) 4-1/2" 158 BBL's of cement in 6-3/4" Hole. Est TOC @ 6,400125%excess) No Depths Item 1 6,400' 4-112" Swell Packer aLe- s�, GYM' r`v e) -ft � (is re- -�s -ry b) Page 6 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 7.0 Drilling / Completion Summary CLU #15 is a grass roots development well from Pad #3 in the Cannery Loop Field targeting the Beluga Sands. . The base plan is an "S" turn wellbore, kicking off at 300' MD and building to 60 deg, then dropping back to 14 deg. starting at 5,400' MD, then drilling a tangent to TD at 11,689' MD. Drilling operations are expected to commence approximately February 15th, 2020. " The Hilcorp Rig # 169 will be used to drill and partially complete the wellbore. A wireline unit will follow behind to perforate the well. Surface casing will be run to 2,100' MD and cemented to surface to ensure protection of surface water. 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. Intermediate CSG will be run to 7,638' MD approx. 50' below the base of the CINGSA storage sand to ensure isolation with an estimated TOC at 1,900' MD. The production string will be tied back to surface estimated run depth to 11,689' MD with an estimated TOC at 6,400' MD. 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 21-1/4" x 2M diverter. 3. Drill 13-1/2" hole to 2,100' MD. Run and cmt 10-3/4" surface casing. 4. N/D diverter, N/U & test 11" x 5M T3 -Energy BOP. 5. Drill 9-7/8" hole section to 7,638' MD. Run and cmt 7-5/8" intermediate casing. 6. Drill 6-3/4" production hole section to well TD. Run and cmt 4-1/2" prod casing. Reservoir Evaluation Plan: 1. Surface hole: LWD: GR + Res + Den/Neu (Triple Combo). Mud loggers will generate a mud log. • 2. Intermediate hole: LWD: GR + Res + Den/Neu (Triple Combo). Mud loggers will generate a mud log. 3. Production hole: LWD: GR + Res + Den/Neu (Triple Combo). Mud loggers will generate a mud log. Page 7 Version 0 December, 2019 CLU #15 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 CLU #15. Ensure to provide AOGCC 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 5/10 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 APD. • 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 permit is posted on the rig floor and in Co Man office. Page 8 Version 0 December, 2019 Hilcorp Energy Company Summary of BOP Equipment and Test Requirements CLU #15 Drilling Procedure Rev 0 Hole Section Equipment Test Pressure(psi) 13-1/2" 21-1/4" x 2M Hydril MSP diver -ter Function Test Only • 11" x 5M Townsend Annular BOP • 11" x 5M Townsend Double Ram o Blind ram in btm cavity • Mud cross 9-7/8" & 6-3/4" • 11" x 5M Townsend Single Ram Initial Test: 250/3500 • 3-1/8" 5M Choke Line (Annular 2500 psi) • 2-1/16" x 5M Kill line • 3-1/8" x 2-1/16" 5M Choke manifold • 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 APD. Additional requirements may be stipulated on APD and Sundry. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: jim.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / Email: melvinAxse cgalaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.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 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 9.0 R/U and Preparatory Work 9.1 Set 16" conductor at +/-120' below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install 16-3/4" 3M "A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Hilcorp Rig # 169, spot service company shacks, spot & R/IJ company man & toolpusher offices. 9.7 6 RU Mud loggers on surface hole section for gas detection only. No samples required 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 13-1/2" hole section. 9.10 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. Stroke Diameter of Liner 6 3,4" 6 i_" 6" 5 'lr" 51, 4 %" Rated pressure 2730 psi 16.3 MPa 2558 psi 17.6 MPa 3000 psi 20.7 MPa 3572 psi 24.6 MPa 4322 psi 29.8 MPa 5000 psi 34.5 MPa Stroke Rated power Discharge capacity GPM (spm) kW HP 6'1." 6 Via' 6" 5,T' = 4 150 799 1071 697 646 551 463 382 310 140• 746' 1000' 1 651 603 514 432 357 _'R9 130 692 928 604 560 477 401 33! 269 120 639 857 558 517 441 370 306 248 110 585 785 511 474 404 339 280 227 100 532 714 465 431 367 309 255 207 90 479 642 418 388 330 278 229 186 U Page 10 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 10.0 N/U 21-1/4" 2M Diverter 10.1 N/U 21-1/4" Hydril MSP 2M diverter System. • N/U 16-3/4" 3M x 21-1/4" 2M DSA (Hilcorp) on 16-3/4" 3M wellhead. • 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. 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. 10.5 Rig 169 and estimated Diverter line Orientation on CLU Pad 43: — s SECTION 4, TSN, R 11 W, SM AK EDW OF PAD MACJ -+ _:. CLU Ni 1 JI ,, CLU 04 f CLU #3 4 I t i WI Page 11 Version 0 December, 2019 f CLU #15 Drilling Procedure Rev 0 Hilcorp Eneu Company 11.0 Drill 13-1/2" Hole Section 11.1 P/U 13-1/2" 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. • Bit TFA should be —0.7 to 0.8 in2. We need to pump at 500 - 550 gpm to clean the hole effectively. • Workstring will be 4.5" 16.64 S-135 CDS40 11.2 Hydraulics Summary: 11.3 4-1/2" Workstring & HWDP & Jars. 11.4 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 11.5 Drill 13-1/2" hole section to 2,100' MD / 1,690' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 550 gpm. This gives us an annular velocity for effective hole cleaning. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Work through coal seams once drilled. • 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. Keep API fluid loss < 10. • TD the hole section in a good shale between 2,100' — 2,300' MD. • Take MWD surveys every stand drilled (60' intervals). 11.6 13-1/2" 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. Page 12 Version 0 December, 2019 Est Open Depth- Hole Size Pump Rate Standpipe hole AV MW ECD TFA MD (ft) (in) (gpm) Pressure (psi) (fpm) (ppg) (ppg) (in2) BHA MM + MWD + 25 0 — 2,100' 13-1/2" 550 1800 85 9.0 9.3 0.788 HWDP 11.3 4-1/2" Workstring & HWDP & Jars. 11.4 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 11.5 Drill 13-1/2" hole section to 2,100' MD / 1,690' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 550 gpm. This gives us an annular velocity for effective hole cleaning. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Work through coal seams once drilled. • 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. Keep API fluid loss < 10. • TD the hole section in a good shale between 2,100' — 2,300' MD. • Take MWD surveys every stand drilled (60' intervals). 11.6 13-1/2" 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. Page 12 Version 0 December, 2019 Hilcorp Energy Company CLU #15 Drilling Procedure Rev 0 MD Totco 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: 8.8 — 9.5 ppg Pre -Hydrated Aquagel/freshwater spud mud Properties: System Formulation: AQUAGEL/freshwater spud mud 11.7 11.8 Product Mud Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL MD caustic soda Viscosity PV YP API FL LGS _ Weight , ALDACIDE G 0.1 ppb 120'— 3,300' 8.8-9.5 250- 85 40-20 55-25 <10 <15% System Formulation: AQUAGEL/freshwater spud mud 11.7 11.8 Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 15 - 20 ppb caustic soda 0.1 ppb (8.5 — 9.0 pH) BARAZAN D+ as needed BAROID 41 as required for 8.8 — 9.5 ppg PAC -L /DEXTRID LT if required for <10 FL ALDACIDE G 0.1 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 13 Version 0 December, 2019 ./ CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 12.0 Run 10-3/4" Surface Casing 12.1 R/U and pull the wear bushing. 12.2 R/U 10-3/4" casing running equipment. • Ensure 10-3/4" DWC 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 10-3/4" 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. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. • After making up several connections, use the torque required to M/U to base of triangle as the M/U torque and continue running string. • 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. 10-3/4" DWC Estimated M/U Torque Casing OD Minimum Maximum Connection Yield 10-3/4" 35,900 ft -lbs 42,200 ft -lbs 48,500 ft -lbs Page 14 Version 0 December, 2019 Hilcorp Energy Company Technical Specifications Connection Type: Size(O.D.): DWC/C Casing 10-3/4 in STANDARD Material L-80 Grade 80,000 Minimum Yield Strength (psi.) 95,000 Minimum Ultimate Strength (psi.) CLU #15 Drilling Procedure Rev 0 Weight (Wall): Grade: 45.50 Ibtft (0.4 in) L-80 AIM �LUSA Connection Dimensions 11.750 Connection O.D. (in.) 9.950 Connection I.D. (in.) 9.875 Connection Drift Diameter (in.) 4.81 Make-up Loss (in.) 13.006 Critical Area (sq. in.) 100.0 Joint Efficiency (%) Pipe Dimensions VAM USA 10.750 Nominal Pipe Body O.D. (in.) 2107 CliyYlfest Boulevard Suite 1300 9.950 Nominal Pipe Body I.D. in. P Y ( ) Houston. 3. 77042 Phone: 713-479-3200 0.400 Nominal Wall Thickness (in.) Fax. 713-476-3234 45.50 Nominal Weight (lbs./ft.) E-mail: �rAPoJU les..a^Vam uso.com 44.26 Plain End Weight (lbs./ft.) Approximated Field End Torque Values 35,900 13.006 Nominal Pipe Body Area (sq. in.) Maximum Final Torque (ft -lbs-) 48,500 Connection Yield Torque (ft.-Ibs.) Pipe Body Performance Properties 1,040,000 Minimum Pipe Body Yield Strength (lbs.) 2,470 Minimum Collapse Pressure (psi.) 5,210 Minimum Internal Yield Pressure (psi.) 4,800 Hydrostatic Test Pressure (psi.) Connection Dimensions 11.750 Connection O.D. (in.) 9.950 Connection I.D. (in.) 9.875 Connection Drift Diameter (in.) 4.81 Make-up Loss (in.) 13.006 Critical Area (sq. in.) 100.0 Joint Efficiency (%) For detailed information on performance properties, refer to DWC Connection Data Notes on following page(s). Connection specifications within the control of VAM USA were correct as of the date printed. Specifications are subject to change without ruitice. Certain connection specifications are dependent on the mechanical properties of the pipe. Medical properties of ndll pro tory pipe grades were obtained from mill publications and are subject to change. Properties of mill proprietary grades _should be co th the mill. Users are advised to obtain current connection specifications and verify pipe mechanical properties for each application. All information is provided by VAM USA or its affiliates at user's sole risk, without liability for loss, damage or iryury resulting from the use thereof; and on an "AS IS" basis without wananty or representation of any kind. whether express or implied, including without limitation any warranty of merchantability, fitness for purpose or completeness. This document and its contents are subject to change without notice. In Page 15 Version 0 December, 2019 Connection Performance Properties 1,040,000 Joint Strength (lbs.) 16,330 Reference String Length (ft) 1.4 Design Factor 1,063,000 API Joint Strength (lbs.) 520,000 Compression Rating (lbs.) 2,470 API Collapse Pressure Rating (psi.) 5,210 API Internal Pressure Resistance (psi.) 17.1 Maximum Uniaxial Bend Rating [degrees/100 ft] Approximated Field End Torque Values 35,900 Minimum Final Torque (ft.-Ibs.) 42,200 Maximum Final Torque (ft -lbs-) 48,500 Connection Yield Torque (ft.-Ibs.) For detailed information on performance properties, refer to DWC Connection Data Notes on following page(s). Connection specifications within the control of VAM USA were correct as of the date printed. Specifications are subject to change without ruitice. Certain connection specifications are dependent on the mechanical properties of the pipe. Medical properties of ndll pro tory pipe grades were obtained from mill publications and are subject to change. Properties of mill proprietary grades _should be co th the mill. Users are advised to obtain current connection specifications and verify pipe mechanical properties for each application. All information is provided by VAM USA or its affiliates at user's sole risk, without liability for loss, damage or iryury resulting from the use thereof; and on an "AS IS" basis without wananty or representation of any kind. whether express or implied, including without limitation any warranty of merchantability, fitness for purpose or completeness. This document and its contents are subject to change without notice. In Page 15 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp 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 RAJ 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 16 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 13.0 Cement 10-3/4" 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. • 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. 13.2 R/tJ cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.3 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. Pump remaining volume of spacer. 13.4 Drop bottom plug. Mix and pump cmt per below recipe. 13.5 Cement volume based on annular volume + 50% open hole excess. Job will consist of lead & tail, TOC brought to surface. Estimated Total Cement Volume: SURFACE CEMENT CALCULATIONS CSG BTM (ft) 2,100 CSG Size 103/4 Section: Calculation: BLS Vol (ft3) LEAD: 16" Conductor x 13-1/2" Casing 120' x.106 bpf = 12.76 71.6 annulus: LEAD: 13-1/2" OH x 10-3/4" Casing (1600'— 120') x.065 bpf x 1.5 = 143.82 807.5 annulus: Total LEAD: 156.58 879.1 TAIL: 13-1/2" OH x 10-3/4" Casing (2,100'-1,600') x .065 bpf x 1.5 = 48.59 272.8 annulus: TAIL: 80 x .096 bpf = 7.69 43.2 10-3/4" Shoe track: Total TAIL: 56.28 316.0 Total Cement: 212.86 1195.1 Page 17 Version 0 December, 2019 36 Se Z6'35-� Hilcorp anew C -P -y Cement Slurry Design: CLU #15 Drilling Procedure Rev 0 13.7 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. 13.8 After pumping cement, drop top plug and displace cement with 9.0 ppg 6% KCl/EZ MUD/BDF- 976 drilling fluid (mud to be used on next hole section). 13.9 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.10 Displacement calculation: ,/ 2,020' x.0962 bpf = 194 bbls " 13.11 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. 13.12 Do not over -displace by more than 1/2 shoe track volume. Total volume in shoe track is 7.69 bbls. 13.13 Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 6 — 18 hours after CIP. 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. Page 18 Version 0 December, 2019 Lead Slurry (1,600' MD to surface) Tail Slurry (2,100' to 1,600' MD) System VARICEM (TM) CEMENT BONDCEM (TM) SYSTEM Density 12 Ib/gal 15.8 Ib/gal Yield 2.386 ft3/sk ✓ 1.215 ft3/sk r Mixed Water 14.11 gal/sk 5.44 gal/sk Expected Thickening 3:42 HR:MIN 3:47 HR:MIN Code Description Concentration Code Description Concentration Additives Type1 Cement 94 lb/sk Type1 Cement 94 lb/sk WeIlLife 1094 Monofilament fiber 0.21% BWOC WeIlLife 1094 Monofilament fiber 0.20% BWOC 13.7 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. 13.8 After pumping cement, drop top plug and displace cement with 9.0 ppg 6% KCl/EZ MUD/BDF- 976 drilling fluid (mud to be used on next hole section). 13.9 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.10 Displacement calculation: ,/ 2,020' x.0962 bpf = 194 bbls " 13.11 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. 13.12 Do not over -displace by more than 1/2 shoe track volume. Total volume in shoe track is 7.69 bbls. 13.13 Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 6 — 18 hours after CIP. 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. Page 18 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp EncrU Company 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. 13.17 M/U pack -off running tool and pack -off to bottom of Landing joint. Set casing hanger packof. . 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 success or problems during the cement job Send final "As -Run" casing tally & casing and cement report to dorm hilcorp.com cdirghilcorp. com. This will be included with the EOW documentation that goes to the AOGCC. Page 19 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp E-ew Company 14.0 BOP N/U and Test 14.1 N/D the diverter. 14.2 N/U wellhead assy. Install packoff 10-3/4" P -seals. Test to 3000 psi. 14.3 N/U 11" x 5M T3 -Energy BOP as follows: • BOP configuration from Top down: 1 I" x 5M T3 -Energy annular BOP/11" x 5M T3 -Energy Model 6011i double ram /11" x 5M mud cross/11" x 5M T3 -Energy Model 601 li single ram • Double ram should be dressed with 2-7/8 x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5" VBRs. • N/U bell nipple, install flowline. • Install (1) manual valves & (1) HCR 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 5/5 min. Test annular to 250/2500 psi for 5/5 min. /( • 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 drilling fluid for 9-7/8" hole section. 14.8 Set wear -bushing in wellhead. 14.9 Rack back as much 4-1/2" DP in derrick as possible to be used while drilling the hole section. 14.10 Install 5" liners in mud pumps. • HHF-1000 Pumps are rated at 3457 psi (80%) with 5" liners and can deliver 306 gpm at 120 spm. This will allow us to drill the 9-7/8" hole section with (1) mud pump. Page 20 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp EneW Company 15.0 Drill 9-7/8" Hole Section L % 4 15.1 Prior to P/U 9-7/8" directional assembly, test casing against blind rams to 2600 psi / 30 min. 15.2 P/U 9-7/8" directional drilling assy. 15.3 Ensure BHA components have been inspected previously. 15.4 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.5 Bit TFA should be —.8 in2. We need to pump at —450 - 500 gpm to clean the hole effectively. Have the directional driller run hydraulics calculations to confirm optimum TFA. 15.6 9-7/8" hole section mud program summary: Primary weighting material to be used for the hole section will be Calcium Carbonate to minimize solids. We will have barite on location to weight up the active system 1ppg above highest anticipated MW in the event of a well control situation. 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: 9.0 — 9.5 ppg 6% KCl/EZ MUD/BDF-976 fresh water based drilling fluid. Properties: Product Mud Water Plastic KCI 22 ppb (29 K chlorides) Caustic MD BARAZAN D+ Viscosity BDF-976 yield Point pH HPHT DEXTRID LT Weight PAC -L Viscosity BARACARB 5/25/50 15 - 20 ppb (5 ppb of each) BAROTROL/Soltex 2,100- 9.0-9.5 40-53 15-25 15-25 8.5-9.5 < 11.0 7,638' 0.5 ppb (maintain per dilution rate) Product Concentration Water 0.905 bbl KCI 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) BDF-976 2 - 4 ppb EZ MUD DP 0.75 ppb DEXTRID LT 1-2 ppb PAC -L 1 ppb BARACARB 5/25/50 15 - 20 ppb (5 ppb of each) BAROTROL/Soltex 2 — 4 ppb as needed BAROID 41 as required for a 9.0 — 9.5 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) Page 21 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy company 15.7 TIH, Conduct shallow hole test of MWD and confirm LWD functioning properly. 15.8 Continue in hole and tag TOC. Note depth tagged on AM report. 15.9 Drill out plugs and shoe track. Clean out rat hole and drill an additional 20' of new formation. 15.10 CBU and condition mud for FIT. 15.11 Conduct FIT to 12.5 ppg EMW. 15.12 Triple combo LWD will be run in 9-7/8" hole section: • Gamma Ray (DGR: Combined Gamma Ray) • Resistivity (EWR: Shallow/Med/Deep) • Density (DEN: Bulk Density) • Neutron (NEU: Thermal neutron porosity) • Density Image, dip picks, and additional engineer for same. 15.13 Drill 9-7/8" hole section to 7,638' MD / 5,200 TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 450 - 500 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. If tight hole is encountered, screw in and begin backreaming connections until hole conditions improve. Shales in the Beluga formations are notorious for swelling and causing tight hole. Most of the time, backreaming them on a short trip is the only solution. • 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 other stand drld. Surveys can be taken more frequently if deemed necessary. • The Cingsa gas storage reservoir will be penetrated at 4,909' TVD and exited at 5,143' TVD. 1K - Keep a close eye on gains or losses while drilling through this section. 15.14 Hilcorp Geologists will follow LWD log closely to determine exact TD below the CINGSA Sand s and above Upper Beluga. 15.15 At TD pump sweeps, CBU, and pull a wiper trip back to the 10-3/4" shoe. 15.16 TOH with the drilling assy, stand back BHA if possible. Page 22 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 16.0 Run 7-5/8" Intermediate Casing 16.1 R/U and pull wear -bushing. Install and test 7-5/8" casing ram in top ram cavity. Test to 250/3500 16.1 R/U 7-5/8" casing running equipment. • Ensure 7-5/8" DWC 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. 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/ 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. 16.4 Continue running 7-5/8" surface casing • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Fill casing while running using fill up line on rig floor. • Use "API Modified" thread compound. Dope pin end only w/ paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Install centralizers over couplings on every joint to 6,500' MD for cement isolation of CO, CINGSA storage sand and upper sterling B sands. • Install centralizers over couplings on every other joint above 6,500' MD to 10-3/4" shoe at 2,100' MD. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 7-5/8" DWC Estimated M/U Torque Casing OD Minimum Maximum Yield 7-5/8" 21,700 ft -lbs 25,100 ft -lbs 28,500 ft -lbs Page 23 Version 0 December, 2019 Hilcorp Energy Company Technical Specifications CLU #15 Drilling Procedure Rev 0 Connection Type: Size(O.D.): Weight (Wall): Grade: DWC/C Casing 7-5/8 in 29.70 Ib/ft (0.375 in) L-80 STANDARD Connection Performance Properties 683,000 Joint Strength (lbs.) 16,430 Reference String Length (ft) 1.4 Design Factor 721,000 API Joint Strength (lbs.) 342,000 Compression Rating (lbs.) 4,790 API Collapse Pressure Rating (psi.) 6,890 API Internal Pressure Resistance (psi.) 24.0 Maximum Uniaxial Bend Rating [degrees/100 ft] Approximated Field End Torque Values 21,700 Minimum Final Torque (ft. -lbs.) 25,100 Maximum Final Torque (ft.-Ibs.) 28,500 Connection Yield Torque (ft. -lbs.) Page 24 Version 0 December, 2019 Material 683,000 L-80 Grade Minimum Collapse Pressure (psi.) 80,000 Minimum Yield Strength (psi.) 1AM 95,000 Minimum Ultimate Strength (psi.) U SA 100.0 Pipe Dimensions VAM USA 7.625 Nominal Pipe Body O.D. (in.) 2107 CityWest Boulevard Suite 1300 6.875 Nominal Pipe Body I.D. (in.) Houston, 3- 77 Phone: 713-479-32-32 00 0.375 Nominal Wall Thickness (in.) Fax: 713-479-3234 29.70 Nominal Weight (lbs./ft.) E-mail: VAMUSAsalesnvam-usa.com 29.06 Plain End Weight (Ibs./ft.) "--— 8.541 Nominal Pipe Body Area (sq. in.) Connection Performance Properties 683,000 Joint Strength (lbs.) 16,430 Reference String Length (ft) 1.4 Design Factor 721,000 API Joint Strength (lbs.) 342,000 Compression Rating (lbs.) 4,790 API Collapse Pressure Rating (psi.) 6,890 API Internal Pressure Resistance (psi.) 24.0 Maximum Uniaxial Bend Rating [degrees/100 ft] Approximated Field End Torque Values 21,700 Minimum Final Torque (ft. -lbs.) 25,100 Maximum Final Torque (ft.-Ibs.) 28,500 Connection Yield Torque (ft. -lbs.) Page 24 Version 0 December, 2019 Pipe Body Performance Properties 683,000 Minimum Pipe Body Yield Strength (lbs.) 4,790 Minimum Collapse Pressure (psi.) 6,890 Minimum Internal Yield Pressure (psi.) 6,300 Hydrostatic Test Pressure (psi.) Connection Performance Properties 683,000 Joint Strength (lbs.) 16,430 Reference String Length (ft) 1.4 Design Factor 721,000 API Joint Strength (lbs.) 342,000 Compression Rating (lbs.) 4,790 API Collapse Pressure Rating (psi.) 6,890 API Internal Pressure Resistance (psi.) 24.0 Maximum Uniaxial Bend Rating [degrees/100 ft] Approximated Field End Torque Values 21,700 Minimum Final Torque (ft. -lbs.) 25,100 Maximum Final Torque (ft.-Ibs.) 28,500 Connection Yield Torque (ft. -lbs.) Page 24 Version 0 December, 2019 Connection Dimensions 8.500 Connection O.D. (in.) 6.875 Connection I.D. (in.) 6.750 Connection Drift Diameter (in.) 4.69 Make-up Loss (in.) 8.541 Critical Area (sq. in.) 100.0 Joint Efficiency (%) Connection Performance Properties 683,000 Joint Strength (lbs.) 16,430 Reference String Length (ft) 1.4 Design Factor 721,000 API Joint Strength (lbs.) 342,000 Compression Rating (lbs.) 4,790 API Collapse Pressure Rating (psi.) 6,890 API Internal Pressure Resistance (psi.) 24.0 Maximum Uniaxial Bend Rating [degrees/100 ft] Approximated Field End Torque Values 21,700 Minimum Final Torque (ft. -lbs.) 25,100 Maximum Final Torque (ft.-Ibs.) 28,500 Connection Yield Torque (ft. -lbs.) Page 24 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 16.5 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.6 Slow in and out of slips. 16.7 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. 16.8 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 16.9 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. 16.10 After circulating, lower string and land hanger in wellhead again. I/ Page 25 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp E -MW ComPEY 17.0 Cement 7-5/8" Intermediate Casing 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. • Pump 20 bbls of freshwater through all of Cementers 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 17.2 17.3 17.4 17.5 PUMP. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. Pump 5 bbls 10.5 ppg spacer. Test surface cmt lines. Pump remaining 20 bbls of 10.5 ppg spacer. Mix and pump slurry per below design (25% excess lead and tail). 'faC INTERMEDIATE CEMENT CALCULATIONS CSG BTM (ft) 7,638 CSG Size 75/8 Section: Calculation: Vol (BBLS) Vol ft3 LEAD: 10-3/4" x 7-5/8" Casing (2100'-1900') x .04 bpf = 7.94 44.6 annulus: LEAD: 9-7/8" OH x 7-5/8" Casing (6,600' — 2,100') x .038 bpf x 1.25 = 215.16 1208.0 annulus: Total LEAD: 223.10 1252.6 TAIL: 9-7/8" OH x 7-5/8" Casing (7,638'-6600') x .038 bpf x 1.25 = 49.63 278.7 annulus: TAIL: 80 x .046 bpf = 3.67 20.6 7-5/8" Shoe track: Total TAIL: 53.30 299.3 Total Cement: 276.40 1551.9 Page 26 Version 0 December, 2019 5-(. S:A CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 17.6 After pumping cement, drop top plug and displace cement with 9.2 ppg 6% KCl/EZ M- JDBDF- 976 drilling fluid (mud to be used on next hole section). 17.7 Use the cement unit to displace with as volumes can be tracked much more accurately. Displacement calcs. L/ 7,558' x.046 bpf = 347 bbls. 17.8 Monitor returns closely while displacing cement. Adjust pump rate is necessary. 17.9 Do not over -displace by more than 1/2 shoe track volume. Total volume in shoe track is 3.6 bbls. 17.10 There should be no cmt returns to surface. TOC is planned to be at 1,900' MD. tali (—r ,q 17.11 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. V/ Page 27 Version 0 December, 2019 Lead Tail System VARICEM (TM) CEMENT EXPANDACEM (TM) SYSTEM Density 12 Ib/gal 15.3 Ib/gal Yield 2.386 ft3/sk 1.237 ft3/sk Mixed Water 14.11 gal/sk 5.55 gal/sk Expected Thickening 6:28 HR:MIN 3:52 HR:MIN Code Description Concentration Code Description Concentration Additives Type1 Cement 94 lb/sk Type1 Cement 94 lb/sk WeIlLife 1094 Monofilament fiber 0.21% BWOC WeIlLife 1094 Monofilament fiber 0.20% BWOC 17.6 After pumping cement, drop top plug and displace cement with 9.2 ppg 6% KCl/EZ M- JDBDF- 976 drilling fluid (mud to be used on next hole section). 17.7 Use the cement unit to displace with as volumes can be tracked much more accurately. Displacement calcs. L/ 7,558' x.046 bpf = 347 bbls. 17.8 Monitor returns closely while displacing cement. Adjust pump rate is necessary. 17.9 Do not over -displace by more than 1/2 shoe track volume. Total volume in shoe track is 3.6 bbls. 17.10 There should be no cmt returns to surface. TOC is planned to be at 1,900' MD. tali (—r ,q 17.11 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. V/ Page 27 Version 0 December, 2019 Hilcorp Energy Company CLU #15 Drilling Procedure Rev 0 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 success or problems during the cement job Send final "As -Run " casing tally & casing and cement report to cdin eerrghilcorp.com and dgormkhilcorp. com. This will be included with the EOW documentation that goes to the AOGCC. 17.12 R/D cement equipment. Flush out wellhead with FW. 17.13 Back out and L/D landing joint, flush out wellhead with FW. 17.14 M/U pack -off running tool and pack -off to bottom of landing joint. Set casing hanger pack -off. Run in lock downs and inject plastic packing element. Test void to 250/3000 psi for 10 min. 17.15 Lay down landing joint and pack -off running tool. Page 28 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 18.0 Drill 6-3/4" Hole Section 18.1 Remove 7-5/8" casing rams from BOP. Install 2-7/8" x 5" VBRs in top cavity. BOP configuration should be (from top down): Annular/VBR/Blind/Mud cross/VBR. 18.2 Test BOPS on 4-1/2" test joint S �v 18.3 Ensure mud loggers are R/U for the 6-3/4" production hole section. 18.4 Pull test plug, run and set wear bushing. 18.5 RU wireline and run a CBL across the 7-5/8" CSG to confirm cement isolation of CINGSA �� torage sand and Sterling B sands. Review CBL Log with Drilling Engineer and Geologist prior 011'��l'a o proceeding. L_--;,�► ,�n PL—,,4 4-- A O c7 c 18.6 Ensure BHA Components have been inspected previously. 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. 18.7 Drift & caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 18.8 Ensure TF offset is measured accurately and entered correctly into the MWD software. 18.9 Confirm that the bit is dressed with a TFA of — 0.393 in2. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 270 gpm. 18.10 Triple combo LWD will be run in 6-3/4" hole section: • Gamma Ray (DGR: Combined Gamma Ray) • Resistivity (EWR: Shallow/Med/Deep) • Density (DEN: Bulk Density) • Neutron (NEU: Thermal neutron porosity) • Density Image, dip picks, and additional engineer for same. 18.11 P/U 6-3/4" directional drilling assembly. 18.12 TIH to TOC. Shallow test MWD on trip in. Note depth TOC tagged at on AM report. �{ 18.13 Conduct casing test to 3500 psi / 30 min. `� 18.14 Drill out shoe track and additional 20' new formation. CBU and prep for FIT. 18.15 Conduct FIT to 12.5 ppg E C)A-T-ok-- 4-, Page 29 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp En.By Company 18.16 Drill 6-3/4" hole to 11,689' MD / 9,120' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See attached mud program for hole cleaning and LCM strategies. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain HTHP fluid loss < 6. • Take MWD surveys every stand drilled. • Pull wiper trips every 500 — 1000 ft drilled. If tight hole conditions are encountered, screw in with top drive and begin back -reaming connections until hole conditions improve. 18.17 6-3/4" hole section mud program summary: Primary weighting material to be used for the hole section will be Calcium Carbonate to minimize solids. We will have barite on location to weight up the active system 1ppg above highest anticipated MW in the event of a well control situation. 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. M Page 30 Version 0 December, 2019 Hilcorp Energy Company CLU #15 Drilling Procedure Rev 0 System Type: 9.2 — 9.8 ppg 6% KCl/EZ NWDBDF-976 fresh water based drilling fluid. Properties: MID Concentration �i"'sity cYield Point pH HPHT 0.2 ppb (9 pH) eu ht 1.25 ppb (as required 18 YP) viscosity 2 - 4 ppb EZ MUD DP 0.75 ppb 5,962'- 9.2-9.8 40-53 15-25 15-25 8.5-9.5 < 11.0 10,385' ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate 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) BDF-976 2 - 4 ppb EZ MUD DP 0.75 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 9.5 —12.2 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate 18.18 Hilcorp Geologists will follow LWD log closely to determine exact TD. 18.19 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8" shoe. 18.20 TOH with drilling assy, handle BHA as appropriate. Page 31 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 HilColp Energy Company 19.0 Run 4-1/2" Production Casing 19.1 R/U 4-1/2" casing running equipment. • Ensure 4-1/2" DWC x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted prior to running. • Be sure to count the total # of joints 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. 19.2 P/U shoe joint, visually verify no debris inside joint. 19.3 Continue M/U & thread locking shoe track assy consisting of - (1) £(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). • Solid body centralizers will be pre-installed on shoe joint an FC 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 19.4 Continue running 4-1/2" production 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 solid body centralizers on every joint to 7,638' MD (7-5/8" shoe). Leave the centralizers free floating. Pick up the swell packer and place in string at approximately 6,400' MD. 4-1/2" DWC M/U torques Casing OD Minimum Maximum Yield 4-1/2" 5,800 ft -lbs 6,500 ft -lbs 7,200 ft -lbs Z Page 32 Version 0 December, 2019 Hilcorp Energy Company Technical Specifications Connection Type: Size(O.D.): Weight (Wall): DWC1C Tubing 4-112 in 12.60 Ibtft (0.271 in) STANDARD CLU #15 Drilling Procedure Rev 0 Grade: L-80 1AM �fi•� U SA VAh1 USA 2107 CityWest Boulevard Suite 1300 Houston. TX 77042 Phone-- 713479-3200 Fax 713-479-3234 E-mail: %IAMUSAsalest�,vam-usa.com 0 Page 33 Version 0 December, 2019 Material L-80 Grade 80,000 Minimum Yield Strength (psi.) 95,000 Minimum Ultimate Strength (psi.) 7,700 Pipe Dimensions 4.500 Nominal Pipe Body O.D. (in.) 3.958 Nominal Pipe Body I.D_ (in.) 0.271 Nominal Wall Thickness (in.) 12.60 Nominal Weight (lbs_lft_) 12.25 Plain End Weight (lbs.ift.) 3.600 Nominal Pipe Body Area (sq. in.) CLU #15 Drilling Procedure Rev 0 Grade: L-80 1AM �fi•� U SA VAh1 USA 2107 CityWest Boulevard Suite 1300 Houston. TX 77042 Phone-- 713479-3200 Fax 713-479-3234 E-mail: %IAMUSAsalest�,vam-usa.com 0 Page 33 Version 0 December, 2019 Pipe Body Performance Properties 288,000 Minimum Pipe Body Yield Strength (lbs.) 7,500 Minimum Collapse Pressure (psi.) 8,430 Minimum Internal Yield Pressure (psi.) 7,700 Hydrostatic Test Pressure (psi.) CLU #15 Drilling Procedure Rev 0 Grade: L-80 1AM �fi•� U SA VAh1 USA 2107 CityWest Boulevard Suite 1300 Houston. TX 77042 Phone-- 713479-3200 Fax 713-479-3234 E-mail: %IAMUSAsalest�,vam-usa.com 0 Page 33 Version 0 December, 2019 Connection Dimensions 5.000 Connection O.D. (in_) 3.953 Connection I.D. (in.) 3.833 Connection Drift Diameter (in.) 3.94 Make-up Loss (in.) 3.600 Critical Area (sq. in.) 100.0 Joint Efficiency (%) CLU #15 Drilling Procedure Rev 0 Grade: L-80 1AM �fi•� U SA VAh1 USA 2107 CityWest Boulevard Suite 1300 Houston. TX 77042 Phone-- 713479-3200 Fax 713-479-3234 E-mail: %IAMUSAsalest�,vam-usa.com 0 Page 33 Version 0 December, 2019 Connection Performance Properties 288,000 Joint Strength (lbs.) 14,290 Reference String Length (ft) 1.6 Design Factor 314,000 API Joint Strength (lbs.) 288,000 Compression Rating (lbs.) 7,500 API Collapse Pressure Rating (psi.) 8,430 API Internal Pressure Resistance (psi.) 81.5 Maximum Uniaxial Bend Rating [degrees1100 ft] Approximated Field End Torque Values 5,800 Minimum Final Torque (ft.-Ibs.) 6,500 Maximum Final Torque (ft -lbs.) 7,200 Connection Yield Torque (ft.-Ibs.) CLU #15 Drilling Procedure Rev 0 Grade: L-80 1AM �fi•� U SA VAh1 USA 2107 CityWest Boulevard Suite 1300 Houston. TX 77042 Phone-- 713479-3200 Fax 713-479-3234 E-mail: %IAMUSAsalest�,vam-usa.com 0 Page 33 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 19.5 Run in hole w/ 4-1/2" casing to the 7-5/8" casing shoe. 19.6 Fill the casing with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. 19.7 Obtain slack off weight, PU weight, rotating weight and torque of the casing. 19.8 Circulate 2X bottoms up at shoe, ease casing thru shoe. 19.9 Continue to RIH w/ casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 19.10 Set casing slowly in and out of slips. 19.11 PU swell packer to be placed at approximately 6,400' MD. Swell packer should have 10' handling pups installed on both ends with bow spring centralizers on pups. 19.12 Swedge up and wash last 2 joints to bottom. P/U 5' off bottom. Note slack -off and pick-up weights. 19.13 Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 19.14 Reciprocate string if hole conditions allow. Circulate until hole and mud is in good condition for cementing. Page 34 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hllcorp Energy C—P-Y 20.0 Cement 4-1/2" Production Casing 20.1 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 Cementers 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. 20.2 Attempt to reciprocate the casing during cmt operations until hole gets sticky 20.3 Pump 5 bbls of 10.5 ppg Mud Push spacer. 20.4 Test surface cmt lines to 4500 psi. 20.5 Pump remaining 25 bbls 10.5 ppg Mud Push spacer. 20.6 Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 25% OH excess. PRODUCTION CEMENT CALCULATIONS CSG BTM (ft) 11,689 CSG Size 41/2 Section: Calculation: Vol (BBLS) Vol ft3 LEAD: 7-5/8" x 4-1/2" (7,638'-6,400') x.026 bpf = 32.49 182.4 Casing annulus: LEAD: 6-3/4" OH x 4-1/2" (11,189' — 7,638') x .025 bpf x 1.25 = 109.15 612.8 Casing annulus: Total LEAD: 141.64 795.2 TAIL: 6-3/4" OH x 4-1/2" Casing (11,689'-11,189') x.025 bpf x 1.25 = 15.37 86.3 annulus: TAIL: 80 x .015 bpf = 1.22 6.8 4-1/2" Shoe track: Total TAIL: 16.59 93.1 Total Cement: 158.22 888.4 Page 35 Version 0 December, 2019 331 si- S(�- CLU #15 Drilling Procedure Rev 0 Hilcolp Energy Company 20.7 Drop wiper plug and displace with 6% KCl 20.8 If hole conditions allow — continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 20.9 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. 20.10 Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 3 minutes. 20.11 Do not over -displace by more than 1/2 shoe track. Shoe track volume is 1.2 bbls. 20.12 Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 20.13 RD cementers and flush equipment 20.14 WOC minimum of 12 hours, test casing to 3500 psi and chart for 30 minutes. Page 36 Version 0 December, 2019 Lead (11,189'— 6,400') Tail (11,689'— 11,189') System VARICEM (TM) CEMENT EXPANDACEM (TM) SYSTEM Density 12 Ib/gal 15.3 Ib/gal Yield 2.386 ft3/sk 1.237 ft3/sk Mixed Water 14.11 gal/sk 5.55 gal/sk Expected Thickening 6:28 HR:MIN 3:52 HR:MIN Code Description Concentration Code Description Concentration Additives Type1 Cement 94 lb/sk Type1 Cement 94 Ib/sk WeIlLife 1094 Monofilament fiber 0.21% BWOC WeIlLife 1094 Monofilament fiber 0.20% BWOC 20.7 Drop wiper plug and displace with 6% KCl 20.8 If hole conditions allow — continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 20.9 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. 20.10 Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 3 minutes. 20.11 Do not over -displace by more than 1/2 shoe track. Shoe track volume is 1.2 bbls. 20.12 Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 20.13 RD cementers and flush equipment 20.14 WOC minimum of 12 hours, test casing to 3500 psi and chart for 30 minutes. Page 36 Version 0 December, 2019 Hileorp Energy Company CLU #15 Drilling Procedure Rev 0 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 success or problems during the cement job 20.15 PU 2-7/8" work string/scraper and bit. Clean out to PBTD. Send final "As -Run "casing tally & casing and cement report to dgormghilcorp com. cdingeerghilcorp.com. This will be included with the EDW documentation that goes to the AOGCC. 21.0 RDMO 21.1 Install BPV in wellhead 21.2 N/D BOPE 21.3 N/U temp abandonment cap 21.4 RDMO Hilcorp Rig #169 22.0 Completions 22.1 A separate Sundry will be submitted to the AOGCC that will cover the completion operationsfor ,. CLU #15. `fr�zK� ItL `' � lit c 7" — � A Page 37 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 23.0 BOP Schematic I "/t. Page 38 Version 0 December, 2019 24.0 Wellhead Schematic CLU #15 Drilling Procedure Rev 0 11 iti4�vr \lad.»_ Al CLU #1S CLU 1115 16X 10 X75/8 X 112 BHTk Otis, 4 1/16 SM FE X 6.5" Otis Quick Union C,. Valve, Swab, C€W-FLS. �a�S,�4E' y.�.SE' .11i 4 1/16 SM FE, HWO, EE trim�N,}%yoF�"oQeia� Valve Upper Master ❑W -FLS, 4 11116 SM FE, HWO, EE trim Valve, Master, CIW-FLS, 4 1/16 SM FE, H'WO, EE trim Mulbbuwl Wellhead, SMB -22, Tei 11 SM X 16 % 31A, W/ t 4- 2 1116 SM SSO Starting mead, S -22 -ET 16 X 3M X 16" SOW, w/ 2- 2 1116 SM EFO 16' VII) '- 7 SI ES" 4 ,.g.. Page 39 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 25.0 Days Vs Depth 0 2000 HIIIII] 4— 6000 Q v v ic 8000 10000 12000 Days Vs Depth coed 14000 0 5 10 15 20 25 30 35 40 Days Page 40 Version 0 December, 2019 0 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 26.0 Geo-Prog danrwy Loop Unit CLU 15 FIELD 2W863.14 ; STATE: 2396048.88 Proposed TVD REF DATUM 277421.80 Pto ed TVD REF ELEV 2391658.00 ' RO ELF'4 ON AtAD27 A1C4 True Narth GROUND ELE' ff,b89'llfis -- 9,f2v1'TVD :�AFER.I)_ Tit roprlaME UlNti;tltiY lAR ' FL!!AD Ant II l II S �STIaG +mss ••'�� rss�a. r 53-81 cieare sandstone 6.659 rets 4,268 -1215 2.392.68288 277.767.89 ne.., r 1027 r acre 0.45 264t 062 ST -b2 clean sardstane 6.751 4,351 -4298 2,392642.63 277.743.87 TD:," 0.45 2'611 0.60 ST -C t?OP CINGSA GAS STORAGE)clean sandstone- MI -gas 7,336 4,909 -4856 2,392"490.68 277,679.80 1571 0.32 2965 0.64 ST -C EASEL SE CINGSA GAS STM clear~ sandstone 7,579 5J43 •-5090 2,392"410.87 277,645.13 1646 0.32 -177 Ire k t[L l;:t:.ei 5�Ie+yJ� -ski pCS3616 goers 7.585 5,148 -x'+95 2.392.410.27 277644-69. -..1544_ ..__..0.301 29.13 0.62 V!y t l& gas T545 AIM 2392407.40 277.64Z74 b silty sans one 7.642 5� -5151 239238002 27763789 1717 0.33! 3227 0.62 _ UB -E silly sandstone dooetedg- 7.763 5,321 5268 Z39Z38rL22 277,669.45 M y 0.121 3299 0-62 L B -F sib sandstone s 7.8tt7 5,393 5310 2392 353 01 277,62183 83 536 O.fO' 3631 0-70 VB -G sr sandstone eted � � 7,825 5G361 -5328 2,392343.01 277,61596 484 0.09 3408 0.65', sandstone e 351 Z39Z342-58 277,614.02 X16 � j 2928 0.60. "l" X (Top �t4"dcllese"�•aa; 8312 5852 -57799 239223&90 277.598-77 0-62 +c ' st?Y sandstone 8.512 6046 -5993 2392189.10 277.586.45 2539 0.42 0 +?� ` sdy san'dstane 8.660 6,189 -6136 2392163.15 277.585.64 2785 045' 0 r!t TG SUPYsandstane 8.772 £,298 -62 4 5 2.392128.9E 277.57730 2015 0.32 0 s,ac r Skisandstane � 8.798 A322 -6269 2392121.87 27757567 2275 0.36: 0 saoystoll? 8.837 6.360 -6307 239210526 277.569.71 2417 0.38 0 M,S-88 s(ltysandstone depleted gas 8,992 8,423 -6370 2,392.096.82 277,56705 1220 0.19 3844 0.63 M&9 s7tysandstone depletedgas 8.927 6,447 4394 2392,09260 277,56549 516 0.08 3577 0.59 MS -9A :ilry sarndstone deIMOodgas 8.959 8478 -6425 2392,08215 277,56261 1879 0291 3569 _ M t8 4Fi silty sandstone depleted gas 9,000 6,518 -6465 2,392,079.96 277,561.27 1434 0.221 3046 058 48-10 silty sandstone_ depleted gas 9.046 8,564 -6511 2,392,054.65 277,548.61 919 0.14 3742 0.66 MR -IIA silty sandstone depletedgas 9,109 6,623 -6570 2,392056.39 277,545.04 1492 0.18 3744 0.62 A4B-ffC silly sandstone depleted gas 9,151 5,664 -Ulf 2.392050.43 277,544-39 1266 0.19; 4034 062 tB-1(Top Lowersetuga) vsiltysandstone d4detadges 9,236 6`746 -6693 239202512 177,536-74 1956 0.29 3933 0.62 Lf1.2 v silty sandstone 9.254 0764 -6711 239202512 277.535-96 2570 0.38' 3483 0.62 LB -4 vsdt sandstone 9.321 $829-6776 2.391,999.80 277.531.74 2322 --- 0.34 -711 - z _ L9.6 v sdty sands me posssbe 9-9.397 .9.455 8.902 -049 2391-979.16 277.523.16 3106 0.45 -- _.0.35 -71 t LB -8 �. T vssd-ndstwe ift' a956 -6905 2391.971.82 27752232 2435 -711 . L9-10 v sky sandskne 9.521 7,022 -6969 2.391.961.85 277.519.09 3160 0.45 338°, 0.62 L8-11 ' vSAYsanostre_ R56E 7,066 7013 2391.956.71 277.51221 2968 042 3969 0.62 LB -13 vdtysands tr-ne 9.638 7135 1'082 2.391.944.97 277.50487 2569 0.36 4040 0.62 LB -15 vsa'tysanashre 9.762 7,255 7202 2391.890-29 277.501.85 2884 0.37 -384 LB -15 vsAtysandstone 9.813:3 7,295 -7242 2.391.880.08 277.496.53 2699 0.37 -304 - LB -19 _ v silty sandskvte posse gas 9,980 7„486 -7413 2391.856.40 277.493.78 2912 0.39 4074 0.62 LB -24 vsiirysardstcne possNe gas 10.174 7,654 -7601 2391,79733 277.476.91 3444 0.45 4213 0.62 UT -1 I Tap Upper Tytusek) • • . possible gas 1a416 7,889 -7835 2391,736-57 277,473.29 3550 0.45 4385 0.62 'LAT Sands (1-4J dear, sad&ons s passbk gas 10.535 $ 003 -7950 2.391.73657 277.473.29 3601 0.45 -506 UT -9B vclean sandstone - 11,181 Aea -an 2,391.563.35 277,410.84 690 008 4805 0-62 Page 41 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Cmnpany 27.0 Anticipated Drilling Hazards 13-1/2" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. BARACARBs/BAROFIBRE/STEELSEALs. Ensure Walnut M plug is also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Bara carb 10 & 20 to the active system at 1 — 2 ppb. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with 20 barrels mud, add 1.0 ppb BARAZAN D PLUS 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. H2S: 1-12S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 42 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 9-7/8" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. BARACARBsBAROFIBRE/STEELSEALs. Ensure Walnut M plug is also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Bara carb 10 & 20 to the active system at 1 — 2 ppb. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with 20 barrels mud, add 1.0 ppb BARAZAN D PLUS 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: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to reduce the chances for losses and differential sticking. LCM (BARACARBs 5/25/50) should be maintained at elevated concentrations while drilling coals to help strengthen the wellbore. Black products can be used in this interval if there is potential for coal sloughing. If severe losses are encountered consider spotting multiple sized BARACARB pills throughout the loss zone. Pills should consist of both large and small particle size distributions. 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 a "running coal. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb Black products pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss. H2S: • H2S is not present in this hole section. Obtain recent Wellhead injection pressure on the offset CINGSA wells to estimate the storage sand pressure. Ensure wellbore mud weights are such we remain overbalanced while drilling through the storage sands. Current Estimated sand pressure of 1650 psi (4,879' TVD) 6.5 ppg equivalent. No abnormal pressures or temperatures are present in this hole section. Page 43 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hileorp Energy Company 6-3/4" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. BARACARBs. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Bara carb 10 & 20 to the active system at 1 — 2 ppb. Hole Cleaning: Maintain a YP between 15 - 25 or as needed to achieve adequate hole cleaning. Pump high viscosity sweeps throughout the interval as needed, particularly prior to POH for casing. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated wellbore. Maximize pipe rotation (ideally > 100 RPM). Wellbore stability: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to reduce the chances for losses and differential sticking. LCM (BARACARBs 5/25/50) should be maintained at elevated concentrations while drilling coals to help strengthen the wellbore. If severe losses are encountered consider spotting multiple sized BARACARB pills throughout the loss zone. Pills should consist of both large and small particle size distributions 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. • Increase fluid density as required to control a "running coal". • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: a 1-12S is not present in this hole section. Page 44 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp EneW Company 28.0 Hilcorp Rig 169 Layout Page 45 Version 0 December, 2019 FFIFF ,.. .. fil .;Ob 1 / 1 ; Page 45 Version 0 December, 2019 Hilcorp Energy Company 29.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: CLU #15 Drilling Procedure Rev 0 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 46 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 30.0 Choke Manifold Schematic Page 47 Version 0 December, 2019 II� - fl�r[ } �v' n n�1 v :i fY Page 47 Version 0 December, 2019 Hilcorp EneW company CLU #15 Drilling Procedure Rev 0 31.0 Casing Design Information Calculation & Casing Design Factors DATE: 6-26-2019 Well: CLU #15 Field: Cannery Loop DESIGN BY: David Gorm Design Criteria: Hole Size 9 713 Mud Density: 9.5 ppg Hole Size 6 314 Mud Density: 9.5 ppg Drilling Mode MASP: 2192 Production Mode MASP: 3192 psi (See attached MASP determination & calculation) Collapse Calculation: Section Calculation 1,2 Normal gradient external stress (0.45 psVtt) and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 1 2 3 4 Casing OD 103/4 i 7 518 41/2 I To MD 0 0 0 Top (TVD) 0 I 0 0 r Bottom (MD) 2,100 7,638 11,689 Bottom TVD 1,690 I. 5,200 9,121 11 Length 2,100 7,638 11,689 Weight (PPL) 45-5 29 12.6 . Grade _,.. L-80 . L-80 L-80 _ Connection_ DWC DWC DWC _ We ight w/o Bouyancy Factor (lbs) 95,550 — 226,850 147,287 _m Tension at Top of Section Ibs 95,550 226,850 147,287 Min strength Tension (1000 lbs) 1040 683 289 Worst Case Safe Factor enslon 10.88 3.01 1.96 Collapse Pressure at bottom Psi 760 2,340 4,104 _ Collapse Resistance w/o tension (Psi) 2,480 j 4,790 7,500 Worst Case Safety Factor Colla 3.26 2.05 1.83 MASP (psi) 591 3,192 3,192 Minimum Yield (psi) 5,210 6,890 8,430 _ Worst case safety factor Burst 8.81 2.16 264 Page 48 Version 0 December, 2019 Hilcorp Energy Company 32.0 9-7/8" Hole Section MASP Maamum Allbcipated Surface Pressure Calculation 9.TiS H* Tion CLU t15 Cannary, Lip MD NO Planum! Tap: 2100 1533 PWnad M. 7638 5233 Antldoamed Farmatiar%and firmurm CLU #15 Drilling Procedure Rev 0 V I Famrrn TO EstPreskre ObGza'Wei PRO -3rad ST43 t 4 1.921 gas 87 0.45 ST -82 4,351 UM as {an Rra1 8.7 0.45 fiT G _(70]]P CINGSA GA° FORAM STZC USE jESE Ca1GSA GAS ST01IME 4,909. 5143 1.571 1.645 C MM - as sIaae 62 62031 0.32 tsx u 8 1 5148 1 —r-44 NL, 58 0; W -A 5158 I.w PMhk gas 1 5.9 0.36 LIE-& 5,244 1,717 gas 6.3 D.33 ME 5.321 539 ftlwocl qz 2.3 D 12 OhN Well Mud Dertsibes J LIME RM rww Tm iTvrii Rmvw irin'. rain CLU 47 9.s-9.8 on 4.?70 7,992 200 CLUAS 9.3.9.8 PPQ 4 W" 7.940 A''4 CLU * 9.2 - 9.8 ppg 2.063 ;3,441 2ra}4 CL..0 913 9t0 -14.4_ PPg 2.787 7,664 2015 CLU #14 909.5 x_645. _ - 5100 2419 Asswiptim, 1. Mak6m planned ruud d2rsty tar the 9-718" Pdo section tr 9.5 ppgl 2. Caku6`tons ass+ u fesarvi%contah 10%gas (Ml rasa 3. Calculations asudw vmW Lm cwt is campW emwaaw of +dune to gas. 4. AmticipmW Naclure gradiard as 16311' T4'13 z 114.2 F EMM Frattrarc Ilittwe all &314'shoe mn&dtrinj a till cdwn all jas harm dw W nWxr. i ,fi94 (8j rt 11.74 jpstil� 1254 psi 1,250 (0) - (4.11 f psdll i,69D lt7J= 1881 MAY frond pare pressure; anilre welihace ayxuatad to gas cram TD 5, 00 lHj A 45 jpsi{t"}- 239 1 2,344t�si$-�0.1�psun,5,36a�t"l]= leaia` 5ummarf. 1. MASP " Cfiingi��tim nx& is gcwm N SIBW minus &-M waihcm aimiked to gas hm M. Page 49 Version 0 December, 2019 V/ CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 33.0 6-3/4" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 6-3/4 tole Section t ti�oly CLU #15 Cannery Loop MD TVD Planned Top: 7638 5200 Planned TO: 11689 9121 Anticipated Fnrmatinns and Drass::as• v Formation TVD Est Pressure OWGas/Wet PPG Grad UB -B UB- 5,204 5.321 1717 539 as de feted as 6.35 2.31 0.33 0.12 UB -F 5,363 536 depleted gas 1.92 0.10 UB -G UB -H 5.381 5,404 484 486 da feted as depleted gas 1.73 1.73 0.09 0.09 MB -1X (Top Middle Beluga) 5,852 2516 gas 827 0.43 MB -4 6,046 2539 gas 8.08 0.42 M3-6 6.189 2785 gas 8.65 0.45 MB -7B 6,298 2015 oas 6.15 0.32 61B-8 6,322 2276 as 6.92 0.36 f0 -11A 6,360 2417 gas 7.31 0.38 M13-813 6,423 1220 depleted gas 3.65 0.19 MB -9 6,447 516 de fetid as 1.54 0.08 MB -9A 6,478 1879 depleted gas 5.58 0.29 1603-96 6,518 1434 depleted gas 4.23 0.22 MB -10 MB -11A 6,564 6.,623 919 1192 depleted gas depleted gas 2.69 3.46 0.14 0.18 MB -11C 6.,664 12'.EC• depleted gas 3.65 0.19 LB -1 (Ta Lanier Beluga) niLB-2 6,746 1956, depleted as 5.58 0.29 6,764 2570 gas 7.31 0.38 LB -4 6,829 2322 gas 6.54 0.34 LB -6 6,902 3106 possible gas 8.65 0.45 LB -8 6,958 2435 gas 6.73 0.35 L13, 10 7,022 3160 gas 8.65 0.45 LB -11 7,066 2968 gas 8.08 0.42 LB -13 7,135 2569 gas 6.92 0.36 LB -15 7,255 2684 gas 7.12 0.37 LB -16 LB -19 7,295 7,466 2699 2912 gas possible gas 7.12 7.50 0.37 0.39 LB -24 7,654 3444 possible gas 8.65 0.45 UT -1 (ToE Upper T nek 7.,888 3550 Eossible gas 8.65 0-45 UT Sands 1-9 8,003 3601 possible as8.65 0.45 UT -9B 8,629 690 "f.1AJOR DEPLETION- 1.54 0.08 Offset Well Mud Densities V/ Wulf r r514! .---- T...n CLU #7 9.5 - 9.8 ppg 4,970 7,992 2004 CLU #B 9.3 - 9.8 M9 4,940 7,940 2004 CLU #9 9..2 - 9.8 ppg 2.063 8,041 2004 CLU #13 9.0 - 10.0 ppg 2,787 7,660 2015 CLU #14 9.0-9..5 ppg 5.100 8,043 2019 Assumptions: 1_ flardmiurn planned spud density for the 6-314" hole section is 9.8 ppg. 2. Calculations assume reservoirs contain 100% gas (worst case). 3. Calculations assume worst ease event is complete evacuation of wellbore to gas_ 4. Anticipated fracture gradient at 5,200' TVD = 13.8 ppg EMYJ Fracture Pressure at 7-W shoe considering a full column of gas from shoe to surface: 5200 (ft) x 0.72 (psdit)=3744 si 3,744 (psi) - [0.1(psYft)•5,200 (ft)]= 3224 si MASP from pore pressure. entire wellbore evacuated to gas from To 9,121 (ft) x0,45(psitft)= 4104 psi 4,104 (psi) - ]0.1(psVft)•9.121 (ft)]= 3192 psi Summary: 1. MASP during Drilling/produclion mode is governed by S1BHP minus entire wellbore evacuated to gas from TD. Page 50 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 34.0 Spider Plot (NAD 27) (Governmental Sections) ADL393034 ADL373302 Robert L. Holt and`Piatricia J. Holt ASSOCIATED FINANCE 8 ASSURANCE CORP JOHN H-EARLEY CLU 03 B.16HN P CROWLEY AND FiTHOMAS CROWLEY ' AMANDA -E WALKER-----.___._.----_--_----_..� ADL373302 `--AISSOCIATED FINANCE & ASSURANCE CORP City of Kenai C061681 �>Doris E. W_alkowski f)�N P HILLING�'��` Orthodox Church in America, Inc. NOLA\ I -`--- -� ALASKA PACKERS ASSOCIATION / DONALD FRE'- L -' Cannery Loop Unit 15 SHL a ADL365454 s o AIL391791_ ��% o - 0 HicortAlaska ,LLC � o ADL373302 o ADL324602 ° ADL917 I -- 3" ADL391790 >�L365454 o ` .\\ S005NO11W CLU 04 SHL: /i i oo°o --- -- -- `34 cl u 1z BHL - �, u o \ ADL3930 i o \„ - �i\ S-1 BHL i - oo V W R UNITED CORP `` CLU 11 BHL✓ ° CANNERY LOOP LINA oo'. \ o Hilcorp Alaska, LLC °B o FEEADI`,60568 ° ADL359153 - - - \\ � o ADL391792 CLU 07 BH \\\ ° o ADL37330 WALDO EDMUND ET UX o �a CLU 01 RDPYBH \ ._y� usutoBHt�-Cannery Loop Unit 15 I-1 —_-- �i CLU 06 BHL \\ ai Hive' \ ,Keri \ ©; BHL•/ �\ '� �'.'' yam' AD), -(24602 Cannery Loop Unit 15 BHL ,WL391790 � C'Lj L1 /CLU S'i BHL Hilcorp Alaska, LLC Legend iCLU oa`�_. _ - s Cannery Loop Unit 15 -SHL • Other Surface Well Locations CL�T'la BHL< /� / X Cannery Loop Unit 15_TPH • Other Bottom Hole Locations / Hilcorp Alaska, LLC •\ / FEE ADL 60568 /moi + Cannery Loop Unit 15 BHL — Well Paths CLU S3 BHV �\ �� Q Oil and Gas Unit Boundary 0 1,000 2,000 Cannery Loop Unit Feet CLU -15 Well w Alaska State Plane Zone 4, NAD27 ltilcorp Al—k., LLC W1h04 Map Date: July 10, 2019 Page 51 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 35.0 Surface Plat (NAD 27) A"UILT CANNERY LOOP UNIT I NO.15 WELL I ASP ZONE 4 NAD27 SCALE N: 2,396,118.6 J a o i,:1I E: Z80.837.3 1 1 LAT: 60'33'11.1 7WW ,Ex I LONG: 151'13'03543:M I FWL >r 2484' FSL = 2539+ C 1 ELEV = 35A' (NGVO 29) —"` SECTION 4, T5N, R11 W. SM AN i — -- – -EDGE OF PAD f I 1 2460 FWLrn I GLUM 1 CLU #12 ! t ,¢ CLU 44 I crl CLU 83 p�y V)+ 4 i � I r ~ –r I 2 �iZI H 1 I I I I9ECTTON 4, T5N, R11 W, S.At„ AK f I I SECTIUN UNE NOT TO SCALE a d I P MOTES , _ 8A_' -S # COOIRINATES IS US:C.A G.S. THI BTAT6k1 AU0RY IN A S.P. ZONE 4, NKO 2n AVERAGE CONVERGENCE OF POINTS SHOWN 01161.w 2 OWDRYLOCATIGN. LAT 673C3G5 S8'N LONG. 181.1677 dw" NORTHING t 2,382.04i Al EASTMO c 268,148a75 3. OASIS OF VERTICAL CONTROL IS NCS P€Nt,S1 MARK MONLOWENT 'N,ENAP. CLEVAfION 431.287 FEET?NGVU 201 lAS7 S A HALL EwE� [1V:%L[mwfi+mNu. L:aaFn12�PE»nw F 6. OCR Yf ifY r,OTws Ye 41tNf °"` 11ar,3f4as,f ..: iGIIM}1A' �wu, E.wa w_yvcaF+sxcov Hilt,nr 1 AlawkR. LL[. I HILCORP ALASKA, LLC CLU PAD 3 WELL # 15 AS -BUILT AS -BUILT SURFACE LOCATION WE n,y,�„a„ ana aewE r.,ac mofccT a ,: aGCx T+G lu tfi.l.l l4� Iq:y SEC. 4 T5N R1 1W SEWARD MERIDIAN, ALASKA "j Page 52 Version 0 December, 2019 CLU #15 Drilling Procedure Rev 0 Hilcorp Energy Company 36.0 Directional Plan (wp05) Page 53 Version 0 December, 2019 M I z Hilcorp Alaska, LLC Kenai C.I.U. Cannery Loop Unit #3 Pad Cannery Loop Unit 15 Cannery Loop Unit 15 Plan: CLU 15 wp05 Standard Proposal Report 09 December, 2019 HALLIBURTON Sperry Drilling Services HALLIBURTON Sperry Drilling Sec MD Inc Azi TVD +N/ -S +E/ -W 1 18.00 0.00 0.00 18.00 Q.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 3 1804.91 60.20 222.97 1542.94 -527.20 -491.04 4 5332.66 60.20 222.97 3296.33 -2767.21 -2577.41 5 6650.28 25.00 194.00 4259.37 -3484.36 -3053.43 6 6750.28 25.00 194.00 4350.00 -3525.37 -3063.65 7 7097.85 14.59 195.56 4676.60 -3639.11 -3093.24 810690.02 14.59 195.56 8153.00 -4510.54 -3335.85 911690.02 14.59 195.56 9120.77 -4753.13 -3403.39 0 750 1 7 Hilcorp Alaska, LLC calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Closest Approach 3D Error Surface: Pedal Curve Warning Method: Error Ratio REFERENCE INFORMATION Coordinate (N/E) Reference: Well Cannery Loop Unit 15, True North Vertical (TVD) Reference: CLU 15 As -Built @ 53.00usft Measured Depth Reference: CLU 15 As -Built @ 53.00usft Calculation Method: Minimum Curvature Annotation Start Dir 41/100' : 300' MD, 300'TVD End Dir : 1804.91' MD, 1542.94' TVD Start Dir 311100': 5332.66' MD, 3296.33'TVD End Dir : 6650.28' MD, 4259.37' TVD Start Dir 30/100' : 6750.28' MD, 4350'TVD End Dir : 7097.85' MD, 4676.6' TVD Total Depth : 11690.02' MD, 9120.77' TVD SECTION DETAILS Dleg TFace VSect Target 0.00 0.00 0.00 Formation 0.00 0.00 0.00 TVDSS MD Size Name 4.00 222.97 714.51 4298.00 0.00 0.00 3750.42 4909.00 3.00 -161.24 4610.64 ST -C (TOP CINGSA GAS STORAGE) 0.00 0.00 4649.93 CLU 15 wp02 tgt 1 3.00 177.83 4759.63 5146.34 7638.00 7-5/8 7 5/8" x 9 7/8" 0.00 0.00 5609.40 CLU 15 wp02 tgt 2 0.00 0.00 5845.97 9120.78 REFERENCE INFORMATION Coordinate (N/E) Reference: Well Cannery Loop Unit 15, True North Vertical (TVD) Reference: CLU 15 As -Built @ 53.00usft Measured Depth Reference: CLU 15 As -Built @ 53.00usft Calculation Method: Minimum Curvature Annotation Start Dir 41/100' : 300' MD, 300'TVD End Dir : 1804.91' MD, 1542.94' TVD Start Dir 311100': 5332.66' MD, 3296.33'TVD End Dir : 6650.28' MD, 4259.37' TVD Start Dir 30/100' : 6750.28' MD, 4350'TVD End Dir : 7097.85' MD, 4676.6' TVD Total Depth : 11690.02' MD, 9120.77' TVD - - - - - - - - - - - Start Dir 41/100' : 300' MD, 300'TVD 500 End Dir : 1804.91' MD, 1542.94' TVD 000 1 CV O 2250-1 10 3/4" x'1 3 1/2" -r- -Z5_4500 N 0 m U -5250 a� F� 6000 6750 7500 O Ny 00 ^O 00 Oh 00 p0 00 ph CASING DETAILS TOP DETAILS TVDPath TVDssPath WELL DETAILS: Cannery Loop Unit 15 Formation 4268.00 TVD TVDSS MD Size Name ST -B1 4351.00 4298.00 35.00 ST -B2 4909.00 1689.61 1636.61 2100.00 10-3/4 10 3/4" x 13 1/2" ST -C (TOP CINGSA GAS STORAGE) +N/ -S +E/ -W Northing Easting Latittude Longitude ST -C BASE (BSE CINGSA GAS STORAG ) 5199.34 5146.34 7638.00 7-5/8 7 5/8" x 9 7/8" 7584.96 0.00 0.00 2396118.60 280837.30 60' 33'11.178 N 151' 133.544 W 7763.72 9120.78 9067.78 11690.02 4-1/2 4 1/2" x 6 3/4" 5799.00 8312.40 MB -1X (Top Middle Beluga) 6423.00 6370.00 8902.41 MB -8B 6764.00 6711.00 9254.77 LB -2 SURVEY PROGRAM 6849.00 9397.36 LB -6 7466.00 7413.00 9980.14 LB -19 Project: Kenai C.I.U. 7835.00 Date: 2019-11-11T00:00:00 Validated: Yes Version: 7950.00 10535.02 UT Sands (1-9) Site: Cannery Loop Unit #3 Pad 8576.00 Depth From Depth To Survey/Plan Tool Well: Cannery Loop Unit 15 18.00 800.00 CLU 15 wp05 (Cannery Loop Unit 15) 3_Gyro-GC_Drop+Sag Wellbore: CanneryLOO Unit 15 p 800.00 2100.00 CLU 15 wp05 (Cannery Loop Unit 15) 3_MWD+IFR1+MS+Sag Design: CLU 15 wp05 2100.00 7638.00 7638.00 11690.02 CLU 15 wp05 (Cannery Loop Unit 15) CLU 15 mpO5(Cannery Loop Unit 15 3_MWD+IFR1+MS+Sag 3 MWD+IFR1+MS+Sa - - - - - - - - - - - Start Dir 41/100' : 300' MD, 300'TVD 500 End Dir : 1804.91' MD, 1542.94' TVD 000 1 CV O 2250-1 10 3/4" x'1 3 1/2" -r- -Z5_4500 N 0 m U -5250 a� F� 6000 6750 7500 O Ny 00 ^O 00 Oh 00 p0 00 ph Oo Start Dir 31/100' : 5332.66' MD, 3296.33'TVD h0 00 " 6000 End Dir : 6650.28' MD, 4259.37' TVD ST -81 650 - ' Start Dir 31/100' : 6750.28' MD, 4350'TVD _. .. - -- - ---- - --------- ST -B2 CLU 15 wp02 tgt 1 _ _ ST -C (TOP CINGSA GAS STORAGE) End Dir : 7097.85' MD, 4676.6' TVD ST -C BASE (BSE CINGSA GAS STORAGE) X500 UB -X (Top Upper Beluga) UB -E 7 5/8" x 9 7/8" 90p0 MB -1X (Top Middle Beluga) 95p0 MB -8B LB -2 8000 UT -1 (Top Upper Tyonek) 8250 UT Sands (1-9) CLU 15 wp02 tgt 2 UT -9B 9000 11000 11500 4 1/2" x 6 3/4'--blA446gu- - - - Total Depth : 11690.02' MD, 9120.77' TVD CLU 15 wp05 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 Vertical Section at 215.60° (1500 usft/in) FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 4268.00 4215.00 6659.80 ST -B1 4351.00 4298.00 6751.38 ST -B2 4909.00 4856.00 7338.00 ST -C (TOP CINGSA GAS STORAGE) 5143.00 5090.00 7579.79 ST -C BASE (BSE CINGSA GAS STORAG ) 5148.00 5095.00 7584.96 UB -X (Top Upper Beluga) 5321.00 5268.00 7763.72 UB -E 5852.00 5799.00 8312.40 MB -1X (Top Middle Beluga) 6423.00 6370.00 8902.41 MB -8B 6764.00 6711.00 9254.77 LB -2 6902.00 6849.00 9397.36 LB -6 7466.00 7413.00 9980.14 LB -19 7888.00 7835.00 10416.19 UT -1 (Top Upper Tyonek) 8003.00 7950.00 10535.02 UT Sands (1-9) 8629.00 8576.00 11181.87 UT -913 Oo Start Dir 31/100' : 5332.66' MD, 3296.33'TVD h0 00 " 6000 End Dir : 6650.28' MD, 4259.37' TVD ST -81 650 - ' Start Dir 31/100' : 6750.28' MD, 4350'TVD _. .. - -- - ---- - --------- ST -B2 CLU 15 wp02 tgt 1 _ _ ST -C (TOP CINGSA GAS STORAGE) End Dir : 7097.85' MD, 4676.6' TVD ST -C BASE (BSE CINGSA GAS STORAGE) X500 UB -X (Top Upper Beluga) UB -E 7 5/8" x 9 7/8" 90p0 MB -1X (Top Middle Beluga) 95p0 MB -8B LB -2 8000 UT -1 (Top Upper Tyonek) 8250 UT Sands (1-9) CLU 15 wp02 tgt 2 UT -9B 9000 11000 11500 4 1/2" x 6 3/4'--blA446gu- - - - Total Depth : 11690.02' MD, 9120.77' TVD CLU 15 wp05 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 Vertical Section at 215.60° (1500 usft/in) HALLIBURTON I Project: Kenai C.I.U. CASING DETAILS r o nn Site: Cannery Loop Unit #3 N d MD Size Well: Cannery Loop Unit 15 °EMWellbore: 2100.00 Plan: Cannery Loop Unit 15 CLU 15 wp05 5146.34 7638.00 7-5/8 7 5/8" x 9 7/8" 120.78 -400 -800 a 0 -2400 0 V 0 -2800 7 Start Dir 40/100' : 300' MD, 300TVD- End Dir : 1804.91' MD, 15::_1_1 TVD 00 10 3/4" x 13 1/2" Start Dir 3o/100'* 5332.66' MD, 3296.33'TVD -3200 End Dir : 6650.28' MD, 4259.37 TVD 4000 _ - - CLUISwp02tgtl __---- -3600 ,45oo Start Dir YAW : 6750.28' MD, 4350'TVD 4750 - - 5000 5250 End Dir : 7097.85' MD, 4676.6' TVD 5500 5j50 -4000 6000 6250 7 5/8" x 9 7/8" 6500 6750 7000 0 -4400 CLU 15 wp02 tgt 2 7 00 7750 00 82- 8S00 87S0 prt Total Depth :11690.02' MD, 9120.77 TVD -4800 �l CLU IS t+'POS 4 1/2" x 6 3/4" -5200 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Cannery Loop Unit 15, True North Vertical (TVD) Reference: CLU 15 As -Built @ 53.00usft Measured Depth Reference: CLU 15 As -Built @ 53.00usft Calculation Method: Minimum Curvature WELL DETAILS: Cannery Loop Unit 15 35.00 +N/ -S +E/ -W Northing Easting Latittude Longitude 0.00 0.00 2396118.60 280837.30 60° 33' 11.178 N 151° 13'3.544 W -4000 -3600 -3200 -2800 -2400 -2000 -1600 -1200 -800 -400 0 West( -)Bast(+) (600 usft/in) CASING DETAILS TVD TVDSS MD Size Name 689.61 1636.61 2100.00 10-3/4 10 3/4" x 13 1/2" 199.34 5146.34 7638.00 7-5/8 7 5/8" x 9 7/8" 120.78 9067.78 11690.02 4-1/2 4 1/2" x 6 3/4" REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Cannery Loop Unit 15, True North Vertical (TVD) Reference: CLU 15 As -Built @ 53.00usft Measured Depth Reference: CLU 15 As -Built @ 53.00usft Calculation Method: Minimum Curvature WELL DETAILS: Cannery Loop Unit 15 35.00 +N/ -S +E/ -W Northing Easting Latittude Longitude 0.00 0.00 2396118.60 280837.30 60° 33' 11.178 N 151° 13'3.544 W -4000 -3600 -3200 -2800 -2400 -2000 -1600 -1200 -800 -400 0 West( -)Bast(+) (600 usft/in) HALLIBURTON Sperry Orllltrip Bemlcw Project: Kenai C.I.U. Site: Cannery Loop Unit #3 Pa 1A/c11• (`.nn I - I Wf 1 r -4800 -4267 -3733 -3200 -2667 -2133 -1600 -1067 -533 0 533 West( -)/East(+) (800 usft/in) =7_l-�l-� =i�Ji l�T►� Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Proiect: Kenai C.I.U. Site: Cannery Loop Unit #3 Pad Well: Cannery Loop Unit 15 Wellbore: Cannery Loop Unit 15 Design: CLU 15 wp05 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Cannery Loop Unit 15 TVD Reference: CLU 15 As -Built @ 53.00usft MD Reference: CLU 15 As -Built @ 53.00usft North Reference: True Survey Calculation Method: Minimum Curvature Proiect Kenai C.I.U. Map System: US State Plane 1927 (Exact solution) Svstem Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Usinq Well Reference Point Map Zone: Alaska Zone 04 Usinq qeodetic scale factor Site Site Position: From: Position Uncertainty: Cannery Loop Unit #3 Pad Northing: Map Easting: 15.00 usft Slot Radius: 2,396,226.43 usft Latitude: 280,559.09 usft Longitude: 13-3/16" Grid Convergence: 600 33' 12.189 N 151° 13'9.147 W -1.06 ° Well Cannery Loop Unit 15 Well Position +N/ -S 0.00 usft Northing: 2,396,118.60 usft Latitude: 60° 33' 11.178 N +E/ -W 0.00 usft Eastinq: 280,837.30 usft Longitude: 151' 13'3.544 W Position Uncertainty 0.50 usft Wellhead Elevation: usft Ground Level: 35.00 usft) Wellbore Cannery Loop Unit 15 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2019 1/15/2020 15.18 73.54 55,332.94684036 Design CLU 15 wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.00 Vertical Section: Depth From (TVD) +NIS +E/ -W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 215.60 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclinatio Azimut Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) n h (usft) usft (usft) (usft) (°1100usft) (°/1o0usft (°/Ioousft (°) 18.00 0.00 0.00 18.00 -35.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 247.00 0.00 0.00 0.00 0.00 0.00 0.00 1,804.91 60.20 222.97 1,542.94 1,489.94 -527.20 -491.04 4.00 4.00 0.00 222.97 5,332.66 60.20 222.97 3,296.33 3,243.33 -2,767.21 -2,577.41 0.00 0.00 0.00 0.00 6,650.28 25.00 194.00 4,259.37 4,206.37 -3,484.36 -3,053.43 3.00 -2.67 -2.20 -161.24 6,750.28 25.00 194.00 4,350.00 4,297.00 -3,525.37 -3,063.65 0.00 0.00 0.00 0.00 7,097.85 14.59 195.56 4,676.60 4,623.60 -3,639.11 -3,093.24 3.00 -3.00 0.45 177.83 10,690.02 14.59 195.56 8,153.00 8,100.00 -4,510.54 -3,335.85 0.00 0.00 0.00 0.00 11,690.02 14.59 195.56 9,120.77 9,067.77 -4,753.13 -3,403.39 0.00 0.00 0.00 0.00 12/912019 2:22:OOPM Pape 2 COMPASS 5000.15 Build 91E HALLIBURTON Database: NORTH US + CANADA Companv: HilcorpAlaska, LLC Proiect: Kenai C.I.U. Site: Cannery Loop Unit #3 Pad Well: Cannery Loop Unit 15 Wellbore: Cannery Loop Unit 15 Desiqn: CLU 15 wp05 Planned Survey Measured Well Cannery Loop Unit 15 TVD Reference: Vertical Depth Inclination Azimuth Depth (usft) (°) (°) (usft) 18.00 0.00 0.00 18.00 100.00 0.00 0.00 100.00 200.00 0.00 0.00 200.00 300.00 0.00 0.00 300.00 Start Dir 41/100': 300' MD, 300'TVD 0.00 400.00 4.00 222.97 399.92 500.00 8.00 222.97 499.35 600.00 12.00 222.97 597.81 700.00 16.00 222.97 694.82 800.00 20.00 222.97 789.91 900.00 24.00 222.97 882.61 1,000.00 28.00 222.97 972.47 1,100.00 32.00 222.97 1,059.05 1,200.00 36.00 222.97 1,141.94 1,300.00 40.00 222.97 1,220.73 1,400.00 44.00 222.97 1,295.02 1,500.00 48.00 222.97 1,364.48 1,600.00 52.00 222.97 1,428.74 1,700.00 56.00 222.97 1,487.51 1,800.00 60.00 222.97 1,540.49 1,804.91 60.20 222.97 1,542.94 End Dir : 1804.91' MD, 1542.94' ND 166.28 1,900.00 60.20 222.97 1,590.20 2,000.00 60.20 222.97 1,639.90 2,100.00 60.20 222.97 1,689.61 10 3/4" x 13 1/2" 1,167.73 -245.22 2,200.00 60.20 222.97 1,739.31 2,300.00 60.20 222.97 1,789.01 2,400.00 60.20 222.97 1,838.72 2,500.00 60.20 222.97 1,888.42 2,600.00 60.20 222.97 1,938.12 2,700.00 60.20 222.97 1,987.82 2,800.00 60.20 222.97 2,037.53 2,900.00 60.20 222.97 2,087.23 3,000.00 60.20 222.97 2,136.93 3,100.00 60.20 222.97 2,186.64 3,200.00 60.20 222.97 2,236.34 3,300.00 60.20 222.97 2,286.04 3,400.00 60.20 222.97 2,335.74 3,500.00 60.20 222.97 2,385.45 3,600.00 60.20 222.97 2,435.15 3,700.00 60.20 222.97 2,484.85 3,800.00 60.20 222.97 2,534.56 3,900.00 60.20 222.97 2,584.26 4,000.00 60.20 222.97 2,633.96 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Cannery Loop Unit 15 TVD Reference: CLU 15 As -Built @ 53.00usft MD Reference: CLU 15 As -Built @ 53.00usft North Reference: True Survey Calculation Method: Minimum Curvature 1,686.31 -778.07 Map Map 2,395,354.11 TVDss +N/ -S +E/ -W Northing Easting DLS Vert usft (usft) (usft) (usft) (usft) -35.00 Section -35.00 0.00 0.00 2,396,118.60 280,837.30 0.00 0.00 47.00 0.00 0.00 2,396,118.60 280,837.30 0.00 0.00 147.00 0.00 0.00 2,396,118.60 280,837.30 0.00 0.00 247.00 0.00 0.00 2,396,118.60 280,837.30 0.00 0.00 346.92 -2.55 -2.38 2,396,116.09 280,834.88 4.00 3.46 446.35 -10.20 -9.50 2,396,108.58 280,827.61 4.00 13.83 544.81 -22.90 -21.33 2,396,096.09 280,815.55 4.00 31.04 641.82 -40.60 -37.82 2,396,078.70 280,798.74 4.00 55.03 736.91 -63.21 -58.88 2,396,056.49 280,777.27 4.00 85.67 829.61 -90.62 -84.40 2,396,029.56 280,751.24 4.00 122.82 919.47 -122.69 -114.27 2,395,998.05 280,720.78 4.00 166.28 1,006.05 -159.27 -148.35 2,395,962.11 280,686.04 4.00 215.86 1,088.94 -200.18 -186.45 2,395,921.91 280,647.18 4.00 271.31 1,167.73 -245.22 -228.40 2,395,877.66 280,604.41 4.00 332.35 1,242.02 -294.18 -274.00 2,395,829.56 280,557.91 4.00 398.70 1,311.48 -346.81 -323.02 2,395,777.85 280,507.93 4.00 470.03 1,375.74 -402.85 -375.22 2,395,722.78 280,454.71 4.00 545.99 1,434.51 -462.04 -430.35 2,395,664.63 280,398.50 4.00 626.20 1,487.49 -524.08 -488.14 2,395,603.66 280,339.57 4.00 710.29 1,489.94 -527.20 -491.04 2,395,600.61 280,336.61 4.00 714.51 1,537.20 -587.58 -547.27 2,395,541.28 280,279.27 0.00 796.35 1,586.90 -651.07 -606.42 2,395,478.89 280,218.97 0.00 882.40 1,636.61 -714.57 -665.56 2,395,416.50 280,158.66 0.00 968.46 1,686.31 -778.07 -724.70 2,395,354.11 280,098.36 0.00 1,054.52 1,736.01 -841.56 -783.84 2,395,291.72 280,038.05 0.00 1,140.58 1,785.72 -905.06 -842.98 2,395,229.34 279,977.75 0.00 1,226.64 1,835.42 -968.56 -902.13 2,395,166.95 279,917.45 0.00 1,312.69 1,885.12 -1,032.06 -961.27 2,395,104.56 279,857.14 0.00 1,398.75 1,934.82 -1,095.55 -1,020.41 2,395,042.17 279,796.84 0.00 1,484.81 1,984.53 -1,159.05 -1,079.55 2,394,979.78 279,736.53 0.00 1,570.87 2,034.23 -1,222.55 -1,138.69 2,394,917.39 279,676.23 0.00 1,656.93 2,083.93 -1,286.04 -1,197.83 2,394,855.00 279,615.93 0.00 1,742.98 2,133.64 -1,349.54 -1,256.98 2,394,792.61 279,555.62 0.00 1,829.04 2,183.34 -1,413.04 -1,316.12 2,394,730.22 279,495.32 0.00 1,915.10 2,233.04 -1,476.53 -1,375.26 2,394,667.84 279,435.01 0.00 2,001.16 2,282.74 -1,540.03 -1,434.40 2,394,605.45 279,374.71 0.00 2,087.22 2,332.45 -1,603.53 -1,493.54 2,394,543.06 279,314.41 0.00 2,173.27 2,382.15 -1,667.02 -1,552.68 2,394,480.67 279,254.10 0.00 2,259.33 2,431.85 -1,730.52 -1,611.83 2,394,418.28 279,193.80 0.00 2,345.39 2,481.56 -1,794.02 -1,670.97 2,394,355.89 279,133.49 0.00 2,431.45 2,531.26 -1,857.52 -1,730.11 2,394,293.50 279,073.19 0.00 2,517.51 2,580.96 -1,921.01 -1,789.25 2,394,231.11 279,012.89 0.00 2,603.56 121912019 2:22:OOPM Paae 3 COMPASS 5000.15 Build 91E HALLIBURTON Database: NORTH US + CANADA Company: HilcorpAlaska, LLC Proiect: Kenai C.I.U. Site: Cannery Loop Unit #3 Pad Well: Cannery Loop Unit 15 Wellbore: Cannery Loop Unit 15 Design: CLU 15 wp05 Planned Survey Measured Map Vertical Depth Inclination Azimuth Depth TVDss (usft) (1) (1) (usft) usft 4,100.00 60.20 222.97 2,683.67 2,630.67 4,200.00 60.20 222.97 2,733.37 2,680.37 4,300.00 60.20 222.97 2,783.07 2,730.07 4,400.00 60.20 222.97 2,832.77 2,779.77 4,500.00 60.20 222.97 2,882.48 2,829.48 4,600.00 60.20 222.97 2,932.18 2,879.18 4,700.00 60.20 222.97 2,981.88 2,928.88 4,800.00 60.20 222.97 3,031.59 2,978.59 4,900.00 60.20 222.97 3,081.29 3,028.29 5,000.00 60.20 222.97 3,130.99 3,077.99 5,100.00 60.20 222.97 3,180.70 3,127.70 5,200.00 60.20 222.97 3,230.40 3,177.40 5,300.00 60.20 222.97 3,280.10 3,227.10 5,332.66 60.20 222.97 3,296.33 3,243.33 Start Dir 31/100' : 5332.66' MD, 3296.33'TVD 0.00 5,400.00 58.29 222.20 3,330.77 3,277.77 5,500.00 55.46 221.01 3,385.42 3,332.42 5,600.00 52.64 219.73 3,444.13 3,391.13 5,700.00 49.84 218.35 3,506.73 3,453.73 5,800.00 47.06 216.86 3,573.05 3,520.05 5,900.00 44.29 215.22 3,642.92 3,589.92 6,000.00 41.56 213.41 3,716.14 3,663.14 6,100.00 38.85 211.40 3,792.51 3,739.51 6,200.00 36.19 209.14 3,871.82 3,818.82 6,300.00 33.57 206.58 3,953.85 3,900.85 6,400.00 31.01 203.64 4,038.39 3,985.39 6,500.00 28.53 200.24 4,125.19 4,072.19 6,600.00 26.15 196.26 4,214.02 4,161.02 6,650.28 25.00 194.00 4,259.37 4,206.37 End Dir : 6650.28' MD, 4259.37' TVD -3,373.83 -3,014.73 6,659.80 25.00 194.00 4,268.00 4,215.00 ST -B1 2,392,755.63 277,741.35 3.00 4,546.48 6,700.00 25.00 194.00 4,304.43 4,251.43 6,750.28 25.00 194.00 4,350.00 4,297.00 Start Dir 311100': 6750.28' MD, 4350'TVD - CLU 15 wp02 tgt 1 6,751.38 24.97 194.00 4,351.00 4,298.00 ST -B2 -3,504.75 -3,058.51 2,392,671.21 277,714.59 6,800.00 23.51 194.14 4,395.33 4,342.33 6,900.00 20.51 194.48 4,488.03 4,435.03 7,000.00 17.52 194.94 4,582.57 4,529.57 7,097.85 14.59 195.56 4,676.60 4,623.60 End Dir : 7097.85' MD, 4676.6' TVD 2,392,594.84 277,693.81 7,100.00 14.59 195.56 4,678.67 4,625.67 7,200.00 14.59 195.56 4,775.45 4,722.45 7,300.00 14.59 195.56 4,872.23 4,819.23 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Cannery Loop Unit 15 TVD Reference: CLU 15 As -Built @ 53.00usft MD Reference: CLU 15 As -Built @ 53.00usft North Reference: True Survey Calculation Method: Minimum Curvature 12/92019 2:22:OOPM Page 4 COMPASS 5000.15 Build 91E Map Map +NIS +E/ -W Northing Easting DLS Vert (usft) (usft) (usft) (usft) 2,630.67 Section -1,984.51 -1,848.39 2,394,168.73 278,952.58 0.00 2,689.62 -2,048.01 -1,907.53 2,394,106.34 278,892.28 0.00 2,775.68 -2,111.50 -1,966.68 2,394,043.95 278,831.97 0.00 2,861.74 -2,175.00 -2,025.82 2,393,981.56 278,771.67 0.00 2,947.80 -2,238.50 -2,084.96 2,393,919.17 278,711.37 0.00 3,033.85 -2,301.99 -2,144.10 2,393,856.78 278,651.06 0.00 3,119.91 -2,365.49 -2,203.24 2,393,794.39 278,590.76 0.00 3,205.97 -2,428.99 -2,262.39 2,393,732.00 278,530.45 0.00 3,292.03 -2,492.49 -2,321.53 2,393,669.62 278,470.15 0.00 3,378.09 -2,555.98 -2,380.67 2,393,607.23 278,409.85 0.00 3,464.14 -2,619.48 -2,439.81 2,393,544.84 278,349.54 0.00 3,550.20 -2,682.98 -2,498.95 2,393,482.45 278,289.24 0.00 3,636.26 -2,746.47 -2,558.09 2,393,420.06 278,228.93 0.00 3,722.32 -2,767.21 -2,577.41 2,393,399.69 278,209.24 0.00 3,750.42 -2,809.81 -2,616.57 2,393,357.82 278,169.30 3.00 3,807.86 -2,872.41 -2,672.18 2,393,296.26 278,112.55 3.00 3,891.13 -2,934.07 -2,724.62 2,393,235.58 278,058.98 3.00 3,971.79 -2,994.62 -2,773.74 2,393,175.96 278,008.74 3.00 4,049.62 -3,053.88 -2,819.42 2,393,117.55 277,961.98 3.00 4,124.39 -3,111.71 -2,861.52 2,393,060.52 277,918.82 3.00 4,195.92 -3,167.93 -2,899.93 2,393,005.02 277,879.38 3.00 4,264.00 -3,222.40 -2,934.54 2,392,951.20 277,843.76 3.00 4,328.44 -3,274.97 -2,965.27 2,392,899.21 277,812.07 3.00 4,389.07 -3,325.49 -2,992.02 2,392,849.20 277,784.39 3.00 4,445.72 -3,373.83 -3,014.73 2,392,801.29 277,760.79 3.00 4,498.24 -3,419.84 -3,033.32 2,392,755.63 277,741.35 3.00 4,546.48 -3,463.42 -3,047.76 2,392,712.33 277,726.11 3.00 4,590.31 -3,484.36 -3,053.43 2,392,691.50 277,720.05 3.00 4,610.64 -3,488.27 -3,054.40 2,392,687.61 277,719.01 0.00 4,614.38 -3,504.75 -3,058.51 2,392,671.21 277,714.59 0.00 4,630.18 -3,525.37 -3,063.65 2,392,650.69 277,709.07 0.00 4,649.93 -3,525.82 -3,063.77 2,392,650.24 277,708.95 3.00 4,650.37 -3,545.18 -3,068.62 2,392,630.97 277,703.74 3.00 4,668.93 -3,581.49 -3,077.88 2,392,594.84 277,693.81 3.00 4,703.85 -3,613.00 -3,086.14 2,392,563.49 277,684.97 3.00 4,734.28 -3,639.11 -3,093.24 2,392,537.52 277,677.38 3.00 4,759.63 -3,639.63 -3,093.39 2,392,537.01 277,677.23 0.00 4,760.14 -3,663.89 -3,100.14 2,392,512.88 277,670.03 0.00 4,783.80 -3,688.15 -3,106.89 2,392,488.75 277,662.83 0.00 4,807.45 12/92019 2:22:OOPM Page 4 COMPASS 5000.15 Build 91E HALLIBURTON Database: NORTH US + CANADA Local Co-ordinate Reference Companv: Hilcorp Alaska, LLC TVD Reference: Proiect: Kenai C.I.U. MD Reference: Site: Cannery Loop Unit #3 Pad North Reference: Well: Cannery Loop Unit 15 Survev Calculation Method: Wellbore: Cannery Loop Unit 15 Northing Easting Design: CLU 15 wp05 (usft) (usft) 4,856.00 Section 2,392,479.58 Planned Survey 0.00 4,816.44 2,392,464.62 277,655.63 0.00 4,831.11 Measured 277,648.42 Vertical 4,854.77 2,392,421.24 277,642.68 Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W (usft) (°) (°) (usft) usft (usft) (usft) 7,338.00 14.59 195.56 4,909.00 4,856.00 -3,697.36 -3,109.46 ST -C (TOP CINGSA GAS STORAGE) 277,626.82 0.00 4,925.74 2,392,343.97 7,400.00 14.59 195.56 4,96Y 4,916.01 -3,712.41 -3,113.65 7,500.00 14.59 195.56 5,065.78 5,012.78 -3,736.67 -3,120.40 7,579.79 14.59 195.56 5,143.00 5,090.00 -3,756.02 -3,125.79 ST -C BASE (BSE CINGSA GAS STORAGE) 5,046.95 2,392,223.33 277,583.61 7,584.96 14.59 195.56 5,148.00 5,095.00 -3,757.27 -3,126.14 UB -X (Top Upper Beluga) 0.00 5,114.99 2,392,150.94 277,562.01 7,600.00 14.59 195.56 5,162.56 5,109.56 -3,760.92 -3,127.16 7,638.00 14.59 195.56 5,199.34 5,146.34 -3,770.14 -3,129.72 7 5/8" x 9 7/8" 0.00 5,209.61 2,392,054.43 277,533.20 0.00 7,700.00 14.59 195.56 5,259.34 5,206.34 -3,785.18 -3,133.91 7,763.72 14.59 195.56 5,321.00 5,268.00 -3,800.64 -3,138.21 UB -E 0.00 5,303.61 2,391,982.04 277,511.60 0.00 5,304.24 7,800.00 14.59 195.56 5,356.11 5,303.11 -3,809.44 -3,140.66 7,900.00 14.59 195.56 5,452.89 5,399.89 -3,833.70 -3,147.42 8,000.00 14.59 195.56 5,549.67 5,496.67 -3,857.96 -3,154.17 8,100.00 14.59 195.56 5,646.45 5,593.45 -3,882.22 -3,160.92 8,200.00 14.59 195.56 5,743.22 5,690.22 -3,906.48 -3,167.68 8,300.00 14.59 195.56 5,840.00 5,787.00 -3,930.74 -3,174.43 8,312.40 14.59 195.56 5,852.00 5,799.00 -3,933.75 -3,175.27 MBAX (Top Middle Beluga) 8,400.00 14.59 195.56 5,936.78 5,883.78 -3,955.00 -3,181.19 8,500.00 14.59 195.56 6,033.56 5,980.56 -3,979.26 -3,187.94 8,600.00 14.59 195.56 6,130.33 6,077.33 -4,003.52 -3,194.69 8,700.00 14.59 195.56 6,227.11 6,174.11 -4,027.78 -3,201.45 8,800.00 14.59 195.56 6,323.89 6,270.89 -4,052.04 -3,208.20 8,900.00 14.59 195.56 6,420.67 6,367.67 -4,076.29 -3,214.96 8,902.41 14.59 195.56 6,423.00 6,370.00 -4,076.88 -3,215.12 MB -BB 9,000.00 14.59 195.56 6,517.44 6,464.44 -4,100.55 -3,221.71 9,100.00 14.59 195.56 6,614.22 6,561.22 -4,124.81 -3,228.46 9,200.00 14.59 195.56 6,711.00 6,658.00 -4,149.07 -3,235.22 9,254.77 14.59 195.56 6,764.00 6,711.00 -4,162.36 -3,238.92 LB -2 9,300.00 14.59 195.56 6,807.78 6,754.78 -4,173.33 -3,241.97 9,397.36 14.59 195.56 6,902.00 6,849.00 -4,196.95 -3,248.55 LB -6 9,400.00 14.59 195.56 6,904.55 6,851.55 -4,197.59 -3,248.73 9,500.00 14.59 195.56 7,001.33 6,948.33 -4,221.85 -3,255.48 9,600.00 14.59 195.56 7,098.11 7,045.11 -4,246.11 -3,262.23 9,700.00 14.59 195.56 7,194.89 7,141.89 -4,270.37 -3,268.99 9,800.00 14.59 195.56 7,291.66 7,238.66 -4,294.63 -3,275.74 9,900.00 14.59 195.56 7,388.44 7,335.44 -4,318.89 -3,282.49 Halliburton Standard Proposal Report Well Cannery Loop Unit 15 CLU 15 As -Built @ 53.00usft CLU 15 As -Built @ 53.00usft True Minimum Curvature Map Map Northing Easting DLS Vert (usft) (usft) 4,856.00 Section 2,392,479.58 277,660.09 0.00 4,816.44 2,392,464.62 277,655.63 0.00 4,831.11 2,392,440.49 277,648.42 0.00 4,854.77 2,392,421.24 277,642.68 0.00 4,873.64 2,392,419.99 277,642.31 0.00 4,874.86 2,392,416.36 277,641.22 0.00 4,878.42 2,392,407.19 277,638.49 0.00 4,887.41 2,392,392.23 277,634.02 0.00 4,902.08 2,392,376.86 277,629.43 0.00 4,917.15 2,392,368.10 277,626.82 0.00 4,925.74 2,392,343.97 277,619.62 0.00 4,949.39 2,392,319.84 277,612.42 0.00 4,973.05 2,392,295.72 277,605.22 0.00 4,996.70 2,392,271.59 277,598.01 0.00 5,020.36 2,392,247.46 277,590.81 0.00 5,044.02 2,392,244.47 277,589.92 0.00 5,046.95 2,392,223.33 277,583.61 0.00 5,067.67 2,392,199.20 277,576.41 0.00 5,091.33 2,392,175.07 277,569.21 0.00 5,114.99 2,392,150.94 277,562.01 0.00 5,138.64 2,392,126.81 277,554.81 0.00 5,162.30 2,392,102.68 277,547.61 0.00 5,185.95 2,392,102.10 277,547.43 0.00 5,186.52 2,392,078.55 277,540.40 0.00 5,209.61 2,392,054.43 277,533.20 0.00 5,233.27 2,392,030.30 277,526.00 0.00 5,256.92 2,392,017.08 277,522.06 0.00 5,269.88 2,392,006.17 277,518.80 0.00 5,280.58 2,391,982.68 277,511.79 0.00 5,303.61 2,391,982.04 277,511.60 0.00 5,304.24 2,391,957.91 277,504.40 0.00 5,327.89 2,391,933.78 277,497.20 0.00 5,351.55 2,391,909.65 277,489.99 0.00 5,375.20 2,391,885.52 277,482.79 0.00 5,398.86 2,391,861.39 277,475.59 0.00 5,422.52 12/9/2019 2:22:OOPM Pape 5 COMPASS 5000.15 Build 91E HALLIBURTON Halliburton Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Cannery Loop Unit 15 Companv: Hilcorp Alaska, LLC TVD Reference: CLU 15 As -Built @ 53.00usft Proiect: Kenai C.I.U. MD Reference: CLU 15 As -Built @ 53.00usft Site: Cannery Loop Unit #3 Pad North Reference: True Well: Cannery Loop Unit 15 Survev Calculation Method: Minimum Curvature Wellbore: Cannery Loop Unit 15 Northing Easting Northing Easting Design: CLU 15 wp05 (usft) (usft) 7,413.00 Section 2,391,842.06 Planned Survey 0.00 5,441.47 2,391,837.26 277,468.39 0.00 5,446.17 Measured 277,461.19 0.00 Vertical 2,391,789.01 277,453.99 0.00 Depth Inclination Azimuth Depth TVDss +N/ -S +E1 -W (usft) (°) (°) (usft) usft (usft) (usft) 9,980.14 14.59 195.56 7,466.00 7,413.00 -4,338.33 -3,287.91 LB -19 2,391,692.49 277,425.18 0.00 5,588.11 2,391,670.77 277,418.70 10,000.00 14.59 195.56 7,485.22 7,432.22 -4,343.15 -3,289.25 10,100.00 14.59 195.56 7,582.00 7,529.00 -4,367.41 -3,296.00 10,200.00 14.59 195.56 7,678.77 7,625.77 -4,391.66 -3,302.76 10,300.00 14.59 195.56 7,775.55 7,722.55 -4,415.92 -3,309.51 10,400.00 14.59 195.56 7,872.33 7,819.33 -4,440.18 -3,316.26 10,416.19 14.59 195.56 7,888.00 7,835.00 4,444.11 -3,317.36 UT -1 (Top Upper Tyonek) 277,353.17 0.00 5,824.67 2,391,429.48 277,346.69 10,500.00 14.59 195.56 7,969.11 7,916.11 -4,464.44 -3,323.02 10,535.02 14.59 195.56 8,003.00 7,950.00 -4,472.94 -3,325.38 UT Sands (1-9) 10,600.00 14.59 195.56 8,065.88 8,012.88 -4,488.70 -3,329.77 10,690.02 14.59 195.56 8,153.00 8,100.00 -4,510.54 -3,335.85 CLU 15 wp02 tgt 2 10,700.00 14.59 195.56 8,162.66 8,109.66 -4,512.96 -3,336.53 10,800.00 14.59 195.56 8,259.44 8,206.44 -4,537.22 -3,343.28 10,900.00 14.59 195.56 8,356.22 8,303.22 -4,561.48 -3,350.03 11,000.00 14.59 195.56 8,452.99 8,399.99 -4,585.74 -3,356.79 11,100.00 14.59 195.56 8,549.77 8,496.77 -4,610.00 -3,363.54 11,181.87 14.59 195.56 8,629.00 8,576.00 -4,629.86 -3,369.07 UT -9B 11,200.00 14.59 195.56 8,646.55 8,593.55 -4,634.26 -3,370.29 11,300.00 14.59 195.56 8,743.33 8,690.33 -4,658.52 -3,377.05 11,400.00 14.59 195.56 8,840.10 8,787.10 -4,682.78 -3,383.80 11,500.00 14.59 195.56 8,936.88 8,883.88 -4,707.04 -3,390.56 11,600.00 14.59 195.56 9,033.66 8,980.66 -4,731.29 -3,397.31 11,690.02 14.59 195.56 9,120.77 9,067.77 -4,753.13 -3,403.39 Total Depth : 11690.02' MD, 9120.77' TVD Tarqets Target Name hit/miss target Dip Angle Dip Dir. TVD Shape (°) (°) (usft) CLU 15 wp02 tgt 2 0.00 0.00 8,153.00 - plan hits target center - Point CLU 15 wp02 tgt 1 0.00 0.00 4,350.00 - plan hits target center - Point Map Map Northing Easting Northing Easting DLS Vert (usft) (usft) 7,413.00 Section 2,391,842.06 277,469.82 0.00 5,441.47 2,391,837.26 277,468.39 0.00 5,446.17 2,391,813.14 277,461.19 0.00 5,469.83 2,391,789.01 277,453.99 0.00 5,493.49 2,391,764.88 277,446.79 0.00 5,517.14 2,391,740.75 277,439.59 0.00 5,540.80 2,391,736.84 277,438.42 0.00 5,544.63 2,391,716.62 277,432.38 0.00 5,564.45 2,391,708.17 277,429.86 0.00 5,572.74 2,391,692.49 277,425.18 0.00 5,588.11 2,391,670.77 277,418.70 0.00 5,609.40 2,391,668.36 277,417.98 0.00 5,611.77 2,391,644.23 277,410.78 0.00 5,635.42 2,391,620.10 277,403.58 0.00 5,659.08 2,391,595.97 277,396.38 0.00 5,682.73 2,391,571.85 277,389.18 0.00 5,706.39 2,391,552.09 277,383.28 0.00 5,725.76 2,391,547.72 277,381.97 0.00 5,730.05 2,391,523.59 277,374.77 0.00 5,753.70 2,391,499.46 277,367.57 0.00 5,777.36 2,391,475.33 277,360.37 0.00 5,801.02 2,391,451.20 277,353.17 0.00 5,824.67 2,391,429.48 277,346.69 0.00 5,845.97 +N/ -S +E/ -W Northing Easting (usft) (usft) (usft) (usft) -4,510.54 -3,335.85 2,391,670.77 277,418.70 -3,525.37 -3,063.65 2,392,650.69 277,709.07 12/9/2019 2.22:OOPM Pape 6 COMPASS 5000.15 Build 91E • 0 Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Kenai C.I.U. Site: Cannery Loop Unit #3 Pad Well: Cannery Loop Unit 15 Wellbore: Cannery Loop Unit 15 Design: CLU 15 wp05 Casing Points Measured Vertical Depth Depth WSW (usft) 11,690.02 9,120.78 4 1/2" x 6 3/4" 7,638.00 5,199.34 7 5/8" x 9 7/8" 2,100.00 1,689.61 10 3/4" x 13 1/2" Formations Measured Vertical Vertical Depth Depth Depth SS (usft) (usft) Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survev Calculation Method: Halliburton Standard Proposal Report Well Cannery Loop Unit 15 CLU 15 As -Built @ 53.00usft CLU 15 As -Built @ 53.00usft True Minimum Curvature Casing Hole Diameter Diameter Name 4-1/2 6-3/4 7-5/8 9-7/8 10-3/4 13-1/2 Dip Dip Direction Name Lithologv (°) (") 6,751.38 4,351.00 ST -B2 11,181.87 8,629.00 UT -9B 8,902.41 6,423.00 MB -8B 9,254.77 6,764.00 LB -2 9,397.36 6,902.00 LB -6 7,579.79 5,143.00 ST -C BASE (BSE CINGSA GAS STORAG 7,763.72 5,321.00 UB -E 8,312.40 5,852.00 MB -1X (Top Middle Beluga) 7,338.00 4,909.00 ST -C (TOP CINGSA GAS STORAGE) 10,416.19 7,888.00 UT -1 (Top UpperTyonek) 6,659.80 4,268.00 ST -61 7,584.96 5,148.00 UB -X (Top Upper Beluga) 9,980.14 7,466.00 LB -19 10,535.02 8,003.00 UT Sands (1-9) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 Start Dir 4°/100' : 300' MD, 3007VD 1,804.91 1,542.94 -527.20 -491.04 End Dir : 1804.91' MD, 1542.94' TVD 5,332.66 3,296.33 -2,767.21 -2,577.41 Start Dir 31/100' : 5332.66' MD, 3296.33'TVD 6,650.28 4,259.37 -3,484.36 -3,053.43 End Dir : 6650.28' MD, 4259.37' TVD 6,750.28 4,350.00 -3,525.37 -3,063.65 Start Dir 31/100' : 6750.28' MD, 43507VD 7,097.85 4,676.60 -3,639.11 -3,093.24 End Dir : 7097.85' MD, 4676.6' TVD 11,690.02 9,120.77 -4,753.13 -3,403.39 Total Depth: 11690.02' MD, 9120.77' TVD 12/92019 2:22:OOPM Page 7 COMPASS 5000.15 Build 91E Hilcorp Alaska, LLC Kenai C.I.U. Cannery Loop Unit #3 Pad Cannery Loop Unit 15 Cannery Loop Unit 15 CLU 15 wp05 Sperry Drilling Services Clearance Summary Anticollision Report 09 December, 2019 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: Cannery Loop Unit #3 Pad - Cannery Loop Unit 15 - Cannery Loop Unit 15 - CLU 15 wp05 Well Coordinates: 2,396,118.60 N, 280,837.30 E (60° 33' 11.18" N, 1510 13' 03.54" W) Datum Height: CLU 15 As -Built (g] 53.00usft Scan Range: 0.00 to 11,690.02 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft 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 Hilcorp Alaska, LLC HALLIBURTON Kenai C.I.U. Anticollision Report for Cannery Loop Unit 15 - CLU 15 wp05 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) @Measure Clearance Summary Based Reference Design: Cannery Loop Unit #3 Pad -Cannery Loop Unit 15 -Cannery Loop Unit 15 -CLU 15 wp05 Scan Range: 0.00 to 11,690.02 usft. Measured Depth. Separation Warning f -fin ninth Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft 2.147 Centre Distance Measure Minimum @Measure Site Name d Distance d Comparison Well Name - Wellbore Name - Design ninth 1-ftl nenth Cannery Loop Unit Pass - 436.16 6,906.96 Cannery Loop Unit S-1 - Cannery Loop Unit S-1 - CLU 7,397.09 144.50 7,397.09. Cannery Loop Unit S-1 - Cannery Loop Unit S-1 - CLU 7,400.00 144.53 7,400.00 Plan: Cannery Loop Unit S-6 - Cannery Loop Unit S-6 6,585.76 605.24 6,585.76 Plan: Cannery Loop Unit S-6 - Cannery Loop Unit S-6 6,700.00 611.37 6,700.00 Plan: Cannery Loop Unit S-6 - Cannery Loop Unit S-6 6,875.00 646.53 6,875.00 Cannery Loop Unit #1 Pad Cannery Loop Unit 01 - Cannery Loop Unit 01 - Canne Cannery Loop Unit 01 - Cannery Loop Unit 01 RD - CA Cannery Loop Unit 01 - Cannery Loop Unit 01 RD - CA Cannery Loop Unit 01 - Cannery Loop Unit 01 RD - CA Cannery Loop Unit 01 - Cannery Loop Unit 01 RDPB1 - Cannery Loop Unit 01 - Cannery Loop Unit 01 RDP81 - Cannery Loop Unit 01 - Cannery Loop Unit 01 RDP81 - Cannery Loop Unit 05 - Cannery Loop Unit 05RD - CLU Cannery Loop Unit 05 - Cannery Loop Unit 05RD - CLU Cannery Loop Unit 05 - Cannery Loop Unit 05RD - CLU Cannery Loop Unit 06 - Cannery Loop Unit 06 - Canne Cannery Loop Unit 06 - Cannery Loop Unit 06 - Canne Cannery Loop Unit 06 - Cannery Loop Unit 06 - Canne Cannery Loop Unit 07 - Cannery Loop Unit 07 - Canne Cannery Loop Unit 07 - Cannery Loop Unit 07 - Canne Cannery Loop Unit 07 - Cannery Loop Unit 07 - Canne Cannery Loop Unit 13 - Cannery Loop Unit 13 - CLU # Cannery Loop Unit #3 Pad Cannery Loop Unit 03 - Cannery Loop Unit 03 - Canne Cannery Loop Unit 04 - Cannery Loop Unit 04 - Canne Ellipse @Measure Clearance Summary Based 434.70 Separation d Factor on Minimum Separation Warning f -fin ninth 11,122.64 616.86 77.19 7,839.87 2.147 Centre Distance Pass - 77.15 7,839.74 2.145 Clearance Factor Pass - 428.06 6,763.32 3.416 Centre Distance Pass - 417.81 6,817.26 3.159 Ellipse Separation Pass - 436.16 6,906.96 3.073 Clearance Factor Pass - 11,690.02 1,104.36 11,690.02 434.70 11,080.76 1.649 Clearance Factor Pass - 11,122.64 790.87 11,122.64 616.86 10,835.00 4.545 Centre Distance Pass - 11,125.00 790.87 11,125.00 616.82 10,835.00 4.544 Ellipse Separation Pass - 11,175.00 792.60 11,175.00 617.80 10,835.00 4.534 Clearance Factor Pass - 10,453.91 1,048.72 10,453.91 891.57 10,043.03 6.673 Centre Distance Pass - 10,500.00 1,049.06 10,500.00 891.23 10,075.22 6.647 Ellipse Separation Pass - 10,650.00 1,055.05 10,650.00 895.52 10,187.49 6.613 Clearance Factor Pass - 11,425.07 697.02 11,425.07 559.81 10,549.81 5.080 Centre Distance Pass - 11,625.00 698.84 11,625.00 556.83 10,743.58 4.921 Ellipse Separation Pass - 11,690.02 700.83 11,690.02 557.44 10,793.83 4.888 Clearance Factor Pass - 7,675.00 507.46 7,675.00 454.06 8,320.00 9.503 Clearance Factor Pass - 7,825.00 482.98 7,825.00 434.91 8,320.00 10.048 Ellipse Separation Pass - 7,830.82 482.94 7,830.82 435.08 8,320.00 10.091 Centre Distance Pass - 8,135.16 937.63 8,135.16 765.87 8,592.00 5.459 Centre Distance Pass - 8,225.00 938.58 8,225.00 764.93 8,671.54 5.405 Ellipse Separation Pass - 8,375.00 944.38 8,375.00 768.44 8,796.00 5.368 Clearance Factor Pass - 11,408.97 904.32 11,408.97 810.41 10,066.00 9.630 Clearance Factor Pass - 700.05 27.89 700.05 16.06 704.87 2.358 Clearance Factor Pass - 665.74 37.31 665.74 26.09 669.08 3.327 Centre Distance Pass - 09 December, 2019 - 14.:48 Page 2 of 5 COMPASS Hileorp Alaska, LLC HALLIBURTON Survey Kenai C.I.U. Anticollision Report for Cannery Loop Unit 15 - CLU 15 wp05 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: Cannery Loop Unit #3 Pad - Cannery Loop Unit 15 -Cannery Loop Unit 15 - CLU 15 wp05 Scan Range: 0.00 to 11,690.02 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is 1,000.00 usft Measure Minimum @Measure Ellipse @Measure Clearance Summary Based Site Name d Distance d Separation d Factor on Minimum Separation Warning Comparison Well Name - Wellbore Name - Design Daoth 1—M Deoth /u_sftl Deoth Cannery Loop Unit 04 - Cannery Loop Unit 04 - Canne 675.00 37.38 675.00 26.07 678.04 3.305 Clearance Factor Pass - Cannery Loop Unit 11 - Cannery Loop Unit 11 - Canne 1,028.24 116.70 1,028.24 108.56 981.17 14.334 Centre Distance Pass - Cannery Loop Unit 11 - Cannery Loop Unit 11 - Canne 1,050.00 116.78 1,050.00 108.48 1,001.33 14.062 Ellipse Separation Pass - CanneryLoop Unit 11 - Cannery Loop Unit 11 - Canne 1,650.00 161.88 1,650.00 144.22 1,576.75 9.168 Clearance Factor Pass - Cannery Loop Unit 12 - Cannery Loop Unit 12 - Canne 879.55 76.00 879.55 68.58 854.16 10.233 Ellipse Separation Pass - Cannery Loop Unit 12 - Cannery Loop Unit 12 - Canne 1,025.00 82.54 1,025.00 74.07 992.18 9.741 Clearance Factor ass- Pass- Survey tool program From To Survey/Plan Survey Tool (usftl lusftl 18.00 800.00 CLU 15 wp05 3_Gym-GC _Drop+Sag 800.00 2,100.00 CLU 15 wp05 3 MWD+IFRI+MS+Sag 2,100.00 7,638.00 CLU 15 wp05 3 MWD+IFRI+MS+Sag 7,638.00 11,690.02 CLU 15 wp05 3_MWD+IFRI+MS+Sag 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. 09 December, 2019 - 14.'48 Page 3 of 5 COMPASS NALLIBURTON Pro: Kenai C.I.U. REFERENCE INFORMATION WELL DETAnS:Cne Ino Unit 15 NAD1927 A DCONCONUS Alaska Zone04Site: Cannery Loop Unit #3 Pad Co-ortlinate (N/E) Reference: Wall Cannery Loop UnR 15, True NORM1 35.00 Well: Cannery Loop Unit 15 W-1 (TVD) Raierence: CLU 15 As-eui8053 WusR Sp®rry ornnn° Measured DNpth Relevance: CLU 15 As -Built 053I]Ousfl +N/ -S IT NoT." EatUng IntiII& L..&& Wellbore: Canna Loo Unit 15 Cannery P Ca I� tlon Method: Minimum cary - 0.00 0.00 2396118.60 280837.30 60o 33' 11.178 N 151-13'3.544 W Plan: CLU 15 wp05 SURVEY PROGRAM GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Date: 201x11-11-0000 vard-d:va Verw 18.00 To 11690.02 Em Depth To Suney(Plan Tpal CASING DETAILS `*'M11.01 16.00 800.00 CLU 15wp05 (Cannery Loap UnR 15) 3_Gyro-GC Drop+Sag 600.00 210000 CLU15wp05(Cannary Loap U 15) 3MWD+IFRI+MS+Sag 7VD TVD$$ N� $1ZC NatTre Ladder/ S.F. Plots 00.00 ]63800 CLU 15 wp05 (Cannery Loop Unit l 5) 3_MWD+IFRI+MS+Sag WPM (C ]63800 11690.02 CLU Loap UnR 15) 3_MWD+IFRI+MS+Sag 1689.61 1636.61 2100.00 10-3/4 103/4"x131/2" 5199.34 5146.34 7638.00 7-5/8 75/8"x97/8" 9120.78 9067.78 11690.02 4-1/2 4 1/2" x 6 3/4" 180.00 -- - I I CLU Storage 1 X150.00 o Canner P Loop LIMA f .120.00.- ! C o r 0.90.00 Q) 60.00 - - n o " Cad nary Loop Jnit 04 W 30.00 I� I 0.00 I 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 Measured Depth (1200 usft/in) _ EiUS6 pvp0 I -I o - annery L op Unit 4 I -� a.00 netylo4 .Slnii 03 _- CLU Storage 1 0 .00 Fi 3.00- Car 7RD nary Loo{ Unit 0 LL tL a Collision Risk Procedures q. 2.00 n ar Collision Avoidance Req. - No -Go Zone - Stop Drilling 1.00 I NOERRORS i 0.00 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 Measured Depth (1200 usfUin) Transform Points Source coordinate system 0- �— U Target coordinate system State Plane 1927 - Alaska Zone 4 BW Albers Equal Area 0 50) Datum: C- c"O (A 9%t Datum - NAD 1927 - North America Datum of 1927 (Mean) NAD 1927 - North America Datum of 1927 (Mean) a 17ype values into the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctd+C to ,6opy and Ctrl+V to paste. Then click on the appropriate arrow button to transform the points to the desired coordinate system. Help < Back Cancel TRANSMITTAL LETTER CHECKLIST WELL NAME: C L U�5 PTD: V Development — Service _ ExploratoryStrati hic T -- $mP est _ Non -Conventional FIELD: h h eV' Cid POOL: (41 Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MUETI 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. between60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PIS and API number (50- - - ) from records, data and logs acquired for well name on rmit . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Companv Name) 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 Sam les are first caught and 10' sam le intervals through taret zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for hNon-Conventional (name of well) until after (Compan Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (ComnanName) must contact the AOGCC to obtain advance approval of such water well test inprogram. 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 (Company Name) 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 com letion, su ension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KENAI C.L.U., BELUGA GAS - 449575 Well Name: CANNERY LOOP UNIT 15 Program DEV _ _ __ __ Well bore seg ❑ PTD#: 2200030 Company Hilc_orP Alaska _LLC Initial Class/Type DEV /_PEND GeoArea 820 _ Unit 10320_On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached- NA 12 Lease number appropriate- Yes - - i3 Unique well name and number Yes 4 Well located in a-defined_pool _ Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes - - - 7 Sufficient acreage available in drilling unit _ Yes 8 If deviated, is wellbore plat included Yes _ 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes - 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes DLB 1/10/2020 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile _area _of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31,05.0300.1.A),0.2.A-D) NA 18 Conductor string provided Yes 16" conductor set at 120 ft Engineering 19 Surface casing protects all known USDWs Yes 10 3/4" surface casing set at 2100 ft and fully cemented 20 CMT vol adequate -to circulate on conductor & surf -csg - Yes 121 CMT vol_ adequate to tie-in long string to surf csg Yes 7 5/8" int casing set just -below Sterling C storage sands and cemented to 1900 ft md, 22 CMT -will coverall known productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes BTC calcs supplied 24 Adequate tankage or reserve pit Yes Hilcorp rig 169 has steel pits. All waste to KGF disposal well. 25 If a re -drill, has a 10-403 for abandonment been approved NA_ - 26 Adequate wellbore separation proposed Yes No issues ... 27 If_diverter required, does it meet_ regulations_ Yes Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max form pressure = 4100 psi (8.6 ppg EMW) drilling with 9.2-9.8 ppg mud --------------- GLS 1/22/2020 29 BOPEs,-do they meet regulation Yes i30 BOPE-press rating appropriate; test to (put prig in comments) Yes - - - - - MASP = 3192 psi Will test BOPE to 3500 psi (annular to 2500 psi) 131 Choke manifold complies w/API_RP-53 (May 84) Yes 32 Work will occur without operation shutdown Yes Sundry required to perforate well ( CINGSA standoff vertically based on CBL results.) 133 Is presence of H2S gas probable No - - 34 _Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures - Yes - - H2S not anticipated based on offset wells. Geology 136 Data presented on potential overpressure zones Yes Appr Date 1137 Seismic analysis of shallow gas zones NA DLB 1/10/2020 38 Seabed condition survey -(if off -shore) NA_ 39 Contact name/phone for weekly- progress reports [exploratory only] - - NA Geologic Engineering Public CINGSA storage gas in area. Int Casing will be set 50 ft below Sterling C storage sands. Need CBL on all casing strings and Commissioner: Date: ZI�'�jj Commissioner: Date missi ner Date AOGCC approval for any perforations in well. GIs.