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Home My WebLink About212-069GCW 04/14/23 JLC 4/14/2023 04/17/2023Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.17 18:07:38 -08'00' RBDMS JSB 041823 7\SHRI5HTXHVW $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2SHUDWRU1DPH &XUUHQW:HOO&ODVV3HUPLWWR'ULOO1XPEHU ([SORUDWRU\ 'HYHORSPHQW $GGUHVV6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU ,ISHUIRUDWLQJ:HOO1DPHDQG1XPEHU :KDW5HJXODWLRQRU&RQVHUYDWLRQ2UGHUJRYHUQVZHOOVSDFLQJLQWKLVSRRO" :LOOSODQQHGSHUIRUDWLRQVUHTXLUHDVSDFLQJH[FHSWLRQ" <HV 1R 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU)LHOG3RROV 7RWDO'HSWK0'IW 7RWDO'HSWK79'IW (IIHFWLYH'HSWK0' (IIHFWLYH'HSWK79' 0363SVL 3OXJV0' -XQN0' 1$ &DVLQJ &ROODSVH 6WUXFWXUDO &RQGXFWRU SVL 6XUIDFH SVL ,QWHUPHGLDWH 3URGXFWLRQ SVL /LQHU 3DFNHUVDQG66697\SH 3DFNHUVDQG66690'IWDQG79'IW $WWDFKPHQWV 3URSRVDO6XPPDU\ :HOOERUHVFKHPDWLF :HOO&ODVVDIWHUSURSRVHGZRUN 'HWDLOHG2SHUDWLRQV3URJUDP %236NHWFK ([SORUDWRU\ 6WUDWLJUDSKLF 'HYHORSPHQW 6HUYLFH (VWLPDWHG'DWHIRU 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%HOXJD5LYHU)LHOG8QGHILQHG*DV3RRO &2 &HQWHUSRLQW'ULYH6XLWH $QFKRUDJH$. +LOFRUS$ODVND//& 2WKHU /HQJWK 6L]H / 79' %XUVW SVL 0' SVL SVL 3HUIRUDWLRQ'HSWK0'IW U\ 6WDWX )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Meredith Guhl at 8:50 am, Apr 08, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH %-0 6)' '656)' &2DSSURYHVDVSDFLQJH[FHSWLRQIRUWKLVZHOO GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.05.26 12:32:44 -08'00' RBDMS SJC 052622 tĞůůWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗ZhϮϰϰͲϮϯW/EƵŵďĞƌ͗ϱϬͲϮϴϯͲϮϬϭϲϱͲϬϬͲϬϬ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗:ƵĂŶŝƚĂ>ŽǀĞƚƚϳϳϳͲϴϯϯϮWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϭϮͲϬϲϵ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗:ĂŬĞ&ůŽƌĂ;ϵϬϳͿϳϳϳͲϴϰϰϮ;KͿ;ϳϮϬͿϵϴϴͲϱϯϳϱ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿϳϳϳͲϴϰϮϬ;KͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;DͿ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,W͗ΕϮϭϯϱƉƐŝΛϰϳϮϰ͛ds;Ϭ͘ϰϱϮƉƐŝͬĨƚŐƌĂĚŝĞŶƚƚŽďŽƚƚŽŵŶĞǁƉĞƌĨͿ DĂǆ͘WŽƚĞŶƚŝĂů^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗ΕϭϲϲϯƉƐŝ ;DĂǆĞǆƉĞĐƚĞĚ,WŵŝŶƵƐŐĂƐƚŽƐƵƌĨĂĐĞͿ tĞůů^ƚĂƚƵƐ͗ KŶůŝŶĞ'ĂƐWƌŽĚƵĐĞƌ;>ĂƐƚǁĞůůƚĞƐƚŽŶϯͬϮϯͬϮϬϮϮ͗ϮϴϱϰD&ͬϱϮtWͬϯϭϴηͿ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ 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hƉĚĂƚĞĚďǇDϬϵͲϮϵͲϮϭ ^,Dd/ ĞůƵŐĂZŝǀĞƌhŶŝƚ tĞůů͗ZhϮϰϰͲϮϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϱͬϮϵͬϮϬϭϰ Wd͗ϮϭϮͲϬϲϵ W/͗ϱϬͲϮϴϯͲϮϬϭϲϱͲϬϬͲϬϬ ϮϬ͟ ϵͲϱͬϴ͟ ϳ͟ Z<ƚŽD^>сϵϰ͛Z<ƚŽ'>сϭϴ͘ϱ͛ dDсϳ͕ϱϱϯ͛dsс ϲ͕ϲϴϱ͛ WDсϳ͕ϰϱϴ͛Wdsсϲ͕ϱϵϭ͛ DĂǆŶŐůĞсϰϵ͘ϲ ĚĞŐΛϭ͕ϵϵϲ͛ dKΛϯ͕ϰϳϬ͛ Ϯ ϯ ϰ ϱ ϲ ϳ ϴ ϱϬϰϴ͛ WĂĐŬĞƌ ϴ ϵ ϭϬ ϭϭͬϭϮ &ϭ &Ϯ &ϯ &ϰ 'ϭ 'Ϯ 'ϯ ^ϭͲ^Ϯ ^ϯͲ^ϰ 'ϰ 'ϱ 'ϲ 'ϳ 'ϴ 'ϵ 'ϭϬ 'ϭϭ 'ϭϮ 'ϭϯͲ'ϭϱ 'ϭϲ 'ϭϳ 'ϭϴ 'ϭϵ 'ϮϬ 'Ϯϭ 'ϮϮ 'Ϯϯ 'Ϯϰ 'Ϯϱ 'Ϯϲ 'Ϯϳ ĞůƵŐĂ Wϭ &ϱ &ϲ ϱϭϵϱ͛ WĂĐŬĞƌ ϱϳϭϭ͛ WĂĐŬĞƌ ϱϵϳϯ͛ WĂĐŬĞƌ ϲϯϮϬ͛ WĂĐŬĞƌ ϲϱϭϲ͛ WĂĐŬĞƌ ϲϱϵϴ͛ WĂĐŬĞƌ ĞůƵŐĂ &Ͳ ' ^/E'd/> ^ŝǌĞ dǇƉĞ td 'ƌĂĚĞ ŽŶŶ /ƚŵ ϮϬΖΖ ŽŶĚƵĐƚŽƌ ϭϲϱη ,ͲϰϬ tĞůĚ ϭϴ͘ϳϯΖΖ ϭϬϳΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬη >ͲϴϬ dͲD ϴ͘ϴϯϱΖΖ ϯ͕ϰϮϳΖ ϳΖΖ WƌŽĚƵĐƚŝŽŶ Ϯϲη >ͲϴϬ dͲD ϲ͘ϮϳϲΖΖ ϳ͕ϱϰϮΖ dh/E'd/>^ ϯ͘ϱΖΖ WƌŽĚƵĐƚŝŽŶ^ƚƌŝŶŐ ϵ͘ϯη >ͲϴϬ hϮ͘ϵϵϮΖΖ ϱ͕ϬϳϭΖ ϰΗ 'ƌĂǀĞůWĂĐŬΖΖ ϭϭ͘ϲη WͲϭϭϬ ^>,dZϮ ϯ͘ϰϮϴΖΖ ϱ͕ϮϬϭΖ ϰΖΖ 'ƌĂǀĞůWĂĐŬΖ&ͬ'Ζ ϭϭ͘ϲη WͲϭϭϬ ^>,dZϮ ϯ͘ϰϮϴΖΖ ϱ͕ϳϬϭΖ ϯ͘ϱΖΖ 'ƌĂǀĞůWĂĐŬ ϵ͘ϯη >ͲϴϬ /d Ϯ͘ϵϵϮΖΖ ϲ͕ϲϮϱΖ ϱ͘ϬϱΖΖ ^ƵŵƉWĂĐŬĞƌ ϴ^ϰ͘ϭϵϱΖΖ ϱ͕ϳϭϬΖ :t>Zzd/> WƌŽĚƵĐƚŝŽŶ^ƚƌŝŶŐ /͘ĞƉƚŚ D͕Ĩƚ /;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ ϭ ϭϴ ϯ͘ϵ sĞƚĐŽ'ƌĂǇdƵďŝŶŐ,ĂŶŐĞƌ Ϯ ϮϮ ϯ yŽ 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^ĐƌĞĞŶ͕ϰΗϭϮͲ'Ă͘ϯϭϲ>ϭϬ͘ϵηWͲϭϭϬ &ϭϭ ϱϲϭϳ Ϯ͘ϵϯϳ ^ĐƌĞĞŶ͕ϰΗϭϮͲ'Ăϯϭϲ>͕ϭϬ͘ϵηWͲϭϭϬ &ϭϮ ϱϲϱϭ Ϯ͘ϴϯ ^ĐƌĞĞŶ͕ϰΗϭϮͲ'Ăϯϭϲ>͕ϭϬ͘ϵηWͲϭϭϬ &ϭϯ ϱϲϴϭ ϯ͘ϯϴϱ yKϰΗ &ϭϰ ϱϲϴϮ Ϯ͘ϳϳϱ ĞͲƌŝƉƉůĞƌZŽĐŬĞƌ^ƚǇůĞϳϬϮϳs/ &ϭϱ ϱϲϴϵ Ϯ͘ϵϭ >ŽĐĂƚŽƌ͕WŽƉ>ĂĐǁͬϯ͘ϱΗϵ͘ϯη &ϭϲ ϱϲϵϭ Ϯ͘ϵϮ hŶŝƚ^ĞĂů &ϭϳ ϱϲϵϴ Ϯ͘ϵϭϱ ŝƐĂƉƉĞĂƌŝŶŐŚĞĐŬsĂůǀĞ &ϭϴ ϱϲϵϵ Ϯ͘ϵϭϮ DƵůĞƐŚŽĞ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB WŐ͘Ϯ hƉĚĂƚĞĚďǇDϬϵͲϮϵͲϮϭ ^,Dd/ ĞůƵŐĂZŝǀĞƌhŶŝƚ tĞůů͗ZhϮϰϰͲϮϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϱͬϮϵͬϮϬϭϰ Wd͗ϮϭϮͲϬϲϵ W/͗ϱϬͲϮϴϯͲϮϬϭϲϱͲϬϬͲϬϬ 'ƌĂǀĞůWĂĐŬ /͘ĞƉƚŚD;Ĩƚ͘Ϳ/;ŝŶ͘ͿĞƐĐƌŝƉƚŝŽŶ 'ϭϱ͕ϲϲϱϱ͘Ϯϱ,Z>ŝŶĞƌ^ĞƚƚŝŶŐ^ůĞĞǀĞ 'Ϯϱ͕ϲϳϳϰ͘ϮϲZ^EŝƉƉůĞ 'ϯϱ͕ϲϴϬϰ͘ϮϱϴϬͲϰϬ^ĞĂůŽƌĞ 'ϰϱ͕ϳϬϬϰ͘ϱƌŽƐƐŽǀĞƌϱΗǆϰ͘ϱΗ 'ϱϱ͕ϳϭϭϯ͘ϴϳϱϵϴͲϯϴϳWƌĞŵŝĞƌWĂĐŬĞƌ 'ϲϱ͕ϳϭϵϯ͘ϱƌŽƐƐŽǀĞƌϰ͘ϱΗǆϯ͘ϱΗ 'ϳϱ͕ϳϯϮϮ͘ϴϭϯyΖEŝƉƉůĞ 'ϴϱ͕ϳϳϳϮ͘ϳϱ,ĂůůŝďƵƌƚŽŶ&ƌĂĐŽŽƌ;ĐůŽƐĞĚϭϬͬϮϳͬϮϬϭϮͿ 'ϵϱ͕ϴϭϵϮ͘ϵϵϮĂƌďŝĚĞůĂƐƚZŝŶŐƐϱ͕ϴϮϰΖͲϱ͕ϴϯϴΖ 'ϭϬϱ͕ϴϱϴϮ͘ϳϱ^ĞůĞĐƚĂ&ůŽǁ^ĐƌĞĞŶǁͬϮ͘ϳϱΗyWƌŽĨŝůĞKƉĞŶƐŽǁŶ 'ϭϭϱ͕ϵϳϯϮ͘ϴϳϱϱϵϴͲϮϴϳWƌĞŵŝĞƌWĂĐŬĞƌƐƐĞŵďůǇ 'ϭϮϲ͕ϬϯϬϮ͘ϳϱ,ĂůůŝďƵƌƚŽŶ&ƌĂĐŽŽƌ;ĐůŽƐĞĚϭϬͬϮϳͬϮϬϭϮͿ 'ϭϯϲ͕ϬϰϮϮ͘ϵϵϮĂƌďŝĚĞůĂƐƚZŝŶŐƐϲ͕ϬϰϳΖͲϲ͕ϬϲϲΖ 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BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB WŐ͘ϯ hƉĚĂƚĞĚďǇDϬϵͲϮϵͲϮϭ ^,Dd/ ĞůƵŐĂZŝǀĞƌhŶŝƚ tĞůů͗ZhϮϰϰͲϮϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϱͬϮϵͬϮϬϭϰ Wd͗ϮϭϮͲϬϲϵ W/͗ϱϬͲϮϴϯͲϮϬϭϲϱͲϬϬͲϬϬ WZ&KZd/KEd/> ^ĂŶĚƐͬŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿŵƚĂƚĞ^ƚĂƚƵƐ ĞůƵŐĂϱ͕ϭϮϯ͛ϱ͕ϭϯϭ͛ϰ͕Ϯϱϲ͛ϰ͕Ϯϲϰ͛ϴ͛ϵͬϮϯͬϮϬϮϭKƉĞŶ ĞůƵŐĂϱ͕ϭϴϮΖϱ͕ϭϵϭΖϰ͕ϯϭϱΖϰ͕ϯϮϰΖϵΖϲͬϴͬϮϬϭϰKƉĞŶ ĞůƵŐĂ&ϱ͕Ϯϯϲ͛ϱ͕ϮϰϮ͛ϰ͕ϯϲϵ͛ϰ͕ϯϳϱ͛ϲ͛ϵͬϮϯͬϮϬϮϭKƉĞŶ ĞůƵŐĂ&ϱ͕Ϯϳϰ͛ϱ͕Ϯϵϰ͛ϰ͕ϰϬϴ͛ϰ͕ϰϮϴ͛ϮϬ͛ϵͬϮϯͬϮϬϮϭKƉĞŶ ĞůƵŐĂ&ϱ͕ϰϰϵ͛ϱ͕ϰϱϲ͛ϰ͕ϱϴϮ͛ϰ͕ϱϴϵ͛ϳ͛ϵͬϮϯͬϮϬϮϭKƉĞŶ ĞůƵŐĂ&ϱ͕ϰϲϳ͛ϱ͕ϰϴϬ͛ϰ͕ϲϬϬ͛ϰ͕ϲϭϯ͛ϭϯ͛ϵͬϮϯͬϮϬϮϭKƉĞŶ ĞůƵŐĂ&ϱ͕ϱϮϬ͛ϱ͕ϱϮϳ͛ϰ͕ϲϱϯ͛ϰ͕ϲϲϬ͛ϳ͛ϲͬϴͬϮϬϭϰKƉĞŶ ĞůƵŐĂ&ϱ͕ϱϯϴ͛ϱ͕ϱϰϴ͛ϰ͕ϲϳϭ͛ϰ͕ϲϴϭ͛ϭϬ͛ϲͬϴͬϮϬϭϰKƉĞŶ ĞůƵŐĂ&ϱ͕ϱϴϲ͛ϱ͕ϱϵϮ͛ϰ͕ϳϭϵ͛ϰ͕ϳϮϰ͛ϲ͛ϵͬϮϯͬϮϬϮϭKƉĞŶ ĞůƵŐĂ&ϱ͕ϲϬϵΖϱ͕ϲϯϭΖϰ͕ϳϰϮΖϰ͕ϳϲϰΖϮϮΖϲͬϴͬϮϬϭϰKƉĞŶ ĞůƵŐĂ'ϱ͕ϲϰϰ͛ϱ͕ϲϰϵ͛ϰ͕ϳϳϳ͛ϰ͕ϳϴϮ͛ϱ͛ϵͬϮϯͬϮϬϮϭKƉĞŶ ĞůƵŐĂ'ϱ͕ϲϲϮΖϱ͕ϲϳϳΖϰ͕ϳϵϱΖϰ͕ϴϭϬΖϭϱΖϲͬϴͬϮϬϭϰKƉĞŶ ĞůƵŐĂ'ϱ͕ϴϮϳΖϱ͕ϴϯϯΖϰ͕ϵϲϬΖϰ͕ϵϲϲΖϲΖϵͬϭϯͬϮϬϭϮKƉĞŶ ĞůƵŐĂ,ϲ͕ϬϱϬΖϲ͕ϬϲϭΖϱ͕ϭϴϯΖϱ͕ϭϵϰΖϭϭΖϵͬϯͬϮϬϭϮKƉĞŶ ĞůƵŐĂ,ϲ͕ϮϭϳΖϲ͕ϮϯϯΖϱ͕ϯϱϬΖϱ͕ϯϲϲΖϭϲΖϴͬϵͬϮϬϭϮKƉĞŶ ĞůƵŐĂ,ϲ͕ϮϲϮΖϲ͕ϮϳϬΖϱ͕ϯϵϱΖϱ͕ϰϬϯΖϴΖϴͬϵͬϮϬϭϮKƉĞŶ ĞůƵŐĂ,ϲ͕ϯϬϳΖϲ͕ϯϬϵΖϱ͕ϰϰϬΖϱ͕ϰϰϮΖϮΖϴͬϵͬϮϬϭϮKƉĞŶ ĞůƵŐĂ,ϲ͕ϯϰϳΖϲ͕ϯϲϭΖϱ͕ϰϴϬΖϱ͕ϰϵϰΖϭϰΖϴͬϵͬϮϬϭϮKƉĞŶ ĞůƵŐĂ,ϲ͕ϱϲϯΖϲ͕ϱϳϭΖϱ͕ϲϵϲΖϱ͕ϳϬϰΖϴΖϴͬϵͬϮϬϭϮKƉĞŶ ĞůƵŐĂ/ϲ͕ϲϴϲΖϲ͕ϳϬϬΖϱ͕ϴϭϵΖϱ͕ϴϯϯΖϭϰΖϵͬϯͬϮϬϭϮKƉĞŶ ĞůƵŐĂ/ϳ͕ϬϯϬΖϳ͕ϬϰϮΖϲ͕ϭϲϯΖϲ͕ϭϳϱΖϭϮΖϵͬϯͬϮϬϭϮKƉĞŶ ĞůƵŐĂ/ϳ͕ϬϵϲΖϳ͕ϭϬϴΖϲ͕ϮϮϵΖϲ͕ϮϰϭΖϭϮΖϵͬϭͬϮϬϭϮKƉĞŶ ^d/Dh>d/KEd/> ^ĂŶĚƐͬŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿŵƚĂƚĞ^ƚĂƚƵƐ ĞůƵŐĂϱϭϴϮϱ͕ϭϵϭΖϰ͕ϯϭϱΖϰ͕ϯϮϰΖϵΖϲͬϭϯͬϮϬϭϰϮϬͲϰϬĂƌďŽůŝƚĞǁͬϲй<> ĞůƵŐĂ&ϱϱϮϬϱ͕ϲϳϳΖϰ͕ϲϱϯΖϰ͕ϴϭϬΖϭϱϳΖϲͬϭϮͬϮϬϭϰϮϬͲϰϬĂƌďŽůŝƚĞǁͬϲй<> ĞůƵŐĂ'ϱϴϮϳϱϴϯϯϰ͕ϵϲϬΖϰ͕ϵϲϲΖϲΖϵͬϭϯͬϮϬϭϮϮϬͲϰϬĞƌĂŵŝĐƉƌŽƉƉĂŶƚ ĞůƵŐĂ,ϲϬϱϬϲ͕ϯϬϵΖϱ͕ϰϰϬΖϱ͕ϰϰϮΖϮϱϵΖϵͬϭϯͬϮϬϭϮϮϬͲϰϬWŽůĂƌWƌŽƉƉĂŶƚ ĞůƵŐĂ,ϲϬϱϬϲ͕ϯϬϵΖϱ͕ϯϵϱΖϱ͕ϰϬϯΖϮϱϵΖϵͬϭϯͬϮϬϭϮϮϬͲϰϬWŽůĂƌWƌŽƉƉĂŶƚ ĞůƵŐĂ,ϲϬϱϬϲϯϬϵϱ͕ϯϵϱΖϱ͕ϯϵϲΖϮϱϵΖϵͬϭϯͬϮϬϭϮϮϬͲϰϬWŽůĂƌWƌŽƉƉĂŶƚ ĞůƵŐĂ,ϲϬϱϬϲ͕ϯϬϵΖϱ͕ϭϴϯΖϱ͕ϭϵϰΖϮϱϵΖϵͬϭϯͬϮϬϭϮϮϬͲϰϬWŽůĂƌWƌŽƉƉĂŶƚ ĞůƵŐĂ,ϲϯϰϳϲ͕ϯϲϭΖϱ͕ϰϴϬΖϱ͕ϰϵϰΖϭϰΖϵͬϭϮͬϮϬϭϮϮϬͲϰϬWŽůĂƌZĞƐŝŶͲŽĂƚĞĚWƌŽƉƉĂŶƚ ĞůƵŐĂ,ϲϱϲϯϳϭϬϴϲ͕ϮϮϵΖϲ͕ϮϰϭΖϱϰϱΖϵͬϳͬϮϬϭϮϮϬͲϰϬĞƌĂŵŝĐWƌŽƉƉĂŶƚ ĞůƵŐĂ,ϲϱϲϯϳϭϬϴϱ͕ϴϭϵΖϱ͕ϴϯϯΖϱϰϱΖϵͬϳͬϮϬϭϮϮϬͲϰϬĞƌĂŵŝĐWƌŽƉƉĂŶƚ ĞůƵŐĂ,ϲϱϲϯϳϭϬϴϱ͕ϲϵϲΖϱ͕ϳϬϰΖϱϰϱΖϵͬϳͬϮϬϭϮϮϬͲϰϬĞƌĂŵŝĐWƌŽƉƉĂŶƚ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB WŐ͘ϭ hƉĚĂƚĞĚďǇ:>>ϬϰͬϬϲͬϮϮ WZKWK^ ĞůƵŐĂZŝǀĞƌhŶŝƚ tĞůů͗ZhϮϰϰͲϮϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϱͬϮϵͬϮϬϭϰ Wd͗ϮϭϮͲϬϲϵ W/͗ϱϬͲϮϴϯͲϮϬϭϲϱͲϬϬͲϬϬ ϮϬ͟ ϵͲϱͬϴ͟ ϳ͟ Z<ƚŽD^>сϵϰ͛Z<ƚŽ'>сϭϴ͘ϱ͛ dDсϳ͕ϱϱϯ͛dsс ϲ͕ϲϴϱ͛ WDсϳ͕ϰϱϴ͛Wdsсϲ͕ϱϵϭ͛ DĂǆŶŐůĞсϰϵ͘ϲĚĞŐΛϭ͕ϵϵϲ͛ dKΛϯ͕ϰϳϬ͛ Ϯ ϯ ϰ ϱ ϲ ϳ ϴ ϱϬϰϴ͛WĂĐŬĞƌ ϴ ϵ ϭϬ ϭϭͬϭϮ &ϭ &Ϯ &ϯ &ϰ 'ϭ 'Ϯ 'ϯ ^ϭͲ^Ϯ ^ϯͲ^ϰ 'ϰ 'ϱ 'ϲ 'ϳ 'ϴ 'ϵ 'ϭϬ 'ϭϭ 'ϭϮ 'ϭϯͲ'ϭϱ 'ϭϲ 'ϭϳ 'ϭϴ 'ϭϵ 'ϮϬ 'Ϯϭ 'ϮϮ 'Ϯϯ 'Ϯϰ 'Ϯϱ 'Ϯϲ 'Ϯϳ ĞůƵŐĂ Wϭ &ϱ &ϲ ϱϭϵϱ͛ WĂĐŬĞƌ ϱϳϭϭ͛ WĂĐŬĞƌ ϱϵϳϯ͛WĂĐŬĞƌ ϲϯϮϬ͛WĂĐŬĞƌ ϲϱϭϲ͛ WĂĐŬĞƌ ϲϱϵϴ͛ WĂĐŬĞƌ ĞůƵŐĂ&Ͳ' >ϱͲ >&ϭϬ ^/E'd/> ^ŝǌĞ dǇƉĞ td 'ƌĂĚĞ ŽŶŶ / ƚŵ ϮϬΖΖ ŽŶĚƵĐƚŽƌ ϭϲϱη ,ͲϰϬ tĞůĚ ϭϴ͘ϳϯΖΖ ϭϬϳΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬη >ͲϴϬ dͲD ϴ͘ϴϯϱΖΖ ϯ͕ϰϮϳΖ ϳΖΖ WƌŽĚƵĐƚŝŽŶ Ϯϲη >ͲϴϬ dͲD ϲ͘ϮϳϲΖΖ ϳ͕ϱϰϮΖ dh/E'd/>^ ϯ͘ϱΖΖ WƌŽĚƵĐƚŝŽŶ^ƚƌŝŶŐ ϵ͘ϯη >ͲϴϬ h Ϯ͘ϵϵϮΖΖ ϱ͕ϬϳϭΖ ϰΗ 'ƌĂǀĞůWĂĐŬΖΖ ϭϭ͘ϲη WͲϭϭϬ ^>,dZϮ ϯ͘ϰϮϴΖΖ ϱ͕ϮϬϭΖ ϰΖΖ 'ƌĂǀĞůWĂĐŬΖ&ͬ'Ζ ϭϭ͘ϲη WͲϭϭϬ ^>,dZϮ ϯ͘ϰϮϴΖΖ ϱ͕ϳϬϭΖ ϯ͘ϱΖΖ 'ƌĂǀĞůWĂĐŬ ϵ͘ϯη >ͲϴϬ /d Ϯ͘ϵϵϮΖΖ ϲ͕ϲϮϱΖ ϱ͘ϬϱΖΖ ^ƵŵƉWĂĐŬĞƌ ϴ^ ϰ͘ϭϵϱΖΖ ϱ͕ϳϭϬΖ :t>Zzd/> WƌŽĚƵĐƚŝŽŶ^ƚƌŝŶŐ /͘ĞƉƚŚ D͕Ĩƚ /;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ ϭ ϭϴ ϯ͘ϵ sĞƚĐŽ'ƌĂǇdƵďŝŶŐ,ĂŶŐĞƌ Ϯ ϮϮ ϯ yŽϰ͘ϱΗ/d;Ϳǆϯ͘ϱΗhϴƌĚ;ƉͿ ϯ ϰϵϴ Ϯ͘ϴϭϯ ĂŵĐŽdŵĂǆǆͲϱ^^^sͲyƉƌŽĨŝůĞ ϰ ϯ͕ϯϯϯ Ϯ͘ϵϮ ĂŵĐŽ<D'Ͳ>d^'>D ϱ ϰ͕ϵϳϱ Ϯ͘ϵϵϮ ĂĐŽ'>D͕KssĂůǀĞΘZ<W>ĂƚĐŚ ϲ ϱ͕ϬϮϱ Ϯ͘ϴϭϯ ,^yEŝƉƉůĞ ϳ ϱ͕Ϭϱϵ Ϯ͘ϵϭ >ŽĐĂƚŽƌWŽƉ>ŽĐ ϴ ϱ͕Ϭϲϭ Ϯ͘ϵϮ hŶŝƚ^ĞĂů ϵ ϱ͕Ϭϲϵ Ϯ͘ϵϭϮ DƵůĞƐŚŽĞ/ŶĚĞǆŝŶŐϰΗǁͬƐƉƌŝŶŐ ŐƵĂƌĚ 'ƌĂǀĞůWĂĐŬΖΖ/ŶƚĞƌǀĂů ϭ ϱ͕Ϭϰϴ ϰ WĂĐŬĞƌϳΗǆϰΗϮϲͲϯϮηE/ǁͬϱ͘ϭϮϱΗϴ ϯ ϱ͕Ϭϱϯ ϰ͘ϭϵϱ ǆƚĞŶƐŝŽŶ^ĞĂůŚŽƵƐĞ ϲ ϱ͕Ϭϲϴ ϯ͘ϰϬϯ ^ĞĂůŚŽƵƐĞǆƚĞŶƐŝŽŶ ϳ ϱ͕ϬϳϮ Ϯ͘ϴϭ >ŽĐĂƚŽƌǁͬϯ͘ϵϬϲΗͲϴ^ǆǆϱΗͲϴ^WŶ ϴ ϱ͕Ϭϴϲ Ϯ͘ϳϱ D^^ůĞĞǀĞŝƐϳΗǆϮ͘ϳϱΗ ϵ ϱ͕ϬϵϮ Ϯ͘ϴϵϯ /ŶĚŝĐĂƚŽƌŝƌĐ͘sĂůǀĞ ϭϬ ϱ͕ϭϬϯ ϯ͘ϰϭϯ ^ƵďyKϯ͘ϵϬϲΗϴ^ǆǆϰΗϭϭ͘ϲη^>,d ϭϭ ϱ͕ϭϲϵ Ϯ͘ϵϯϳ ^ĐƌĞĞŶ͕ϰΗϭϮ ϭϮ ϱ͕ϭϳϰ Ϯ͘ϴϯ ^ĐƌĞĞŶ͕ϰΗϭϮͲ'Ăϯϭϲ>͕ϭϬ͘ϵηWͲϭϭϬ 'ƌĂǀĞůWĂĐŬΖ&ͬ'Ζ/ŶƚĞƌǀĂů &ϭ ϱϭϴϲ ϯ͘ϯϴϱ yKϰΗϭϭ͘ϲη^>,dǆǆϯ͘ϵϬϲΗͲϴ^ &Ϯ ϱϭϴϳ Ϯ͘ϴϭ >ŽĐĂƚŽƌ͕ƵƚŽϳϬϮϳE/ĨͬD^d &ϯ ϱϭϵϱ Ϯ͘ϴϭϲ /ƐŽůĂƚŝŽŶWĂĐŬĞƌϳϬϮϳϮϲηs/&ͬD^d &ϰ ϱϮϬϭ Ϯ͘ϳϱ D^^ůĞĞǀĞůƐϳΗǆϮ͘ϳϱΗͬs/ΘE/Ĩ &ϱ ϱϮϬϳ Ϯ͘ϴϵϯ ŝƌĐ͘sĂůǀĞ/ŶĚŝĐĂƚŽƌϳϬϮϳϳ͘ϬϭΖ &ϲ ϱϮϭϳ ϯ͘ϰϭϯ yKϯ͘ϵϬϲΗͲϴ^ǆǆϰΗϭϭ͘ϲη &ϳ ϱϰϵϴ Ϯ͘ϵϯϳ ^ĐƌĞĞŶ͕dŽƉǇŶĂ&ůŽ &ϴ ϱϱϭϲ Ϯ͘ϴϯ ^ĐƌĞĞŶ͕ϰΗϭϮͲ'Ă͘ϯϭϲ>ϭϬ͘ϵηWͲϭϭϬ &ϵ ϱϱϰϵ Ϯ͘ϵϯϳ ^ĐƌĞĞŶ͕ϰΗϭϮͲ'Ă͘ϯϭϲ>ϭϬ͘ϵηWͲϭϭϬ &ϭϬ ϱϱϴϯ Ϯ͘ϵϯϳ ^ĐƌĞĞŶ͕ϰΗϭϮͲ'Ă͘ϯϭϲ>ϭϬ͘ϵηWͲϭϭϬ &ϭϭ ϱϲϭϳ Ϯ͘ϵϯϳ ^ĐƌĞĞŶ͕ϰΗϭϮͲ'Ăϯϭϲ>͕ϭϬ͘ϵηWͲϭϭϬ &ϭϮ ϱϲϱϭ Ϯ͘ϴϯ ^ĐƌĞĞŶ͕ϰΗϭϮͲ'Ăϯϭϲ>͕ϭϬ͘ϵηWͲϭϭϬ &ϭϯ ϱϲϴϭ ϯ͘ϯϴϱ yKϰΗ &ϭϰ ϱϲϴϮ Ϯ͘ϳϳϱ ĞͲƌŝƉƉůĞƌZŽĐŬĞƌ^ƚǇůĞϳϬϮϳs/ &ϭϱ ϱϲϴϵ Ϯ͘ϵϭ >ŽĐĂƚŽƌ͕WŽƉ>ĂĐǁͬϯ͘ϱΗϵ͘ϯη &ϭϲ ϱϲϵϭ Ϯ͘ϵϮ hŶŝƚ^ĞĂů &ϭϳ ϱϲϵϴ Ϯ͘ϵϭϱ ŝƐĂƉƉĞĂƌŝŶŐŚĞĐŬsĂůǀĞ &ϭϴ ϱϲϵϵ Ϯ͘ϵϭϮ DƵůĞƐŚŽĞ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB WŐ͘Ϯ hƉĚĂƚĞĚďǇ:>>ϬϰͬϬϲͬϮϮ WZKWK^ ĞůƵŐĂZŝǀĞƌhŶŝƚ tĞůů͗ZhϮϰϰͲϮϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϱͬϮϵͬϮϬϭϰ Wd͗ϮϭϮͲϬϲϵ W/͗ϱϬͲϮϴϯͲϮϬϭϲϱͲϬϬͲϬϬ 'ƌĂǀĞůWĂĐŬ /͘ ĞƉƚŚD;Ĩƚ͘Ϳ /;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ 'ϭ ϱ͕ϲϲϱ ϱ͘Ϯϱ ,Z>ŝŶĞƌ^ĞƚƚŝŶŐ^ůĞĞǀĞ 'Ϯ ϱ͕ϲϳϳ ϰ͘Ϯϲ Z^EŝƉƉůĞ 'ϯ ϱ͕ϲϴϬ ϰ͘Ϯϱ ϴϬͲϰϬ^ĞĂůŽƌĞ 'ϰ ϱ͕ϳϬϬ ϰ͘ϱ ƌŽƐƐŽǀĞƌϱΗǆϰ͘ϱΗ 'ϱ ϱ͕ϳϭϭ ϯ͘ϴϳ ϱϵϴͲϯϴϳWƌĞŵŝĞƌWĂĐŬĞƌ 'ϲ ϱ͕ϳϭϵ ϯ͘ϱ ƌŽƐƐŽǀĞƌϰ͘ϱΗǆϯ͘ϱΗ 'ϳ ϱ͕ϳϯϮ Ϯ͘ϴϭϯ yΖEŝƉƉůĞ 'ϴ ϱ͕ϳϳϳ Ϯ͘ϳϱ ,ĂůůŝďƵƌƚŽŶ&ƌĂĐŽŽƌ;ĐůŽƐĞĚϭϬͬϮϳͬϮϬϭϮͿ 'ϵ ϱ͕ϴϭϵ Ϯ͘ϵϵϮ ĂƌďŝĚĞůĂƐƚZŝŶŐƐϱ͕ϴϮϰΖͲϱ͕ϴϯϴΖ 'ϭϬ ϱ͕ϴϱϴ Ϯ͘ϳϱ ^ĞůĞĐƚĂ&ůŽǁ^ĐƌĞĞŶǁͬϮ͘ϳϱΗyWƌŽĨŝůĞKƉĞŶƐŽǁŶ 'ϭϭ ϱ͕ϵϳϯ Ϯ͘ϴϳϱ ϱϵϴͲϮϴϳWƌĞŵŝĞƌWĂĐŬĞƌƐƐĞŵďůǇ 'ϭϮ ϲ͕ϬϯϬ Ϯ͘ϳϱ ,ĂůůŝďƵƌƚŽŶ&ƌĂĐŽŽƌ;ĐůŽƐĞĚϭϬͬϮϳͬϮϬϭϮͿ 'ϭϯ ϲ͕ϬϰϮ Ϯ͘ϵϵϮ ĂƌďŝĚĞůĂƐƚZŝŶŐƐϲ͕ϬϰϳΖͲϲ͕ϬϲϲΖ 'ϭϰ ϲ͕Ϯϭϭ Ϯ͘ϵϵϮ ĂƌďŝĚĞůĂƐƚZŝŶŐƐϲ͕ϮϭϱΖͲϲ͕ϮϯϴΖ 'ϭϱ ϲ͕Ϯϱϲ Ϯ͘ϵϵϮ ĂƌďŝĚĞůĂƐƚZŝŶŐƐϲ͕ϮϲϬΖͲϲ͕ϮϳϱΖ 'ϭϲ ϲ͕Ϯϵϯ Ϯ͘ϳϱ ^ĞůĞĐƚĂ&ůŽǁ^ĐƌĞĞŶǁͬϮ͘ϳϱΗyWƌŽĨŝůĞKƉĞŶƐŽǁŶ 'ϭϳ ϲ͕ϯϬϬ Ϯ͘ϵϵϮ ĂƌďŝĚĞůĂƐƚZŝŶŐƐϲ͕ϯϰϰΖͲϲ͕ϯϲϲΖ 'ϭϴ ϲ͕ϯϮϬ Ϯ͘ϴϳϱ ϲϵϴͲϮϴϳWƌĞŵŝĞƌWĂĐŬĞƌƐƐĞŵďůǇ 'ϭϵ ϲ͕ϯϯϯ Ϯ͘ϳϱ ,ĂůůŝďƵƌƚŽŶ&ƌĂĐŽŽƌ;ĐůŽƐĞĚϭϬͬϮϳͬϮϬϭϮͿ 'ϮϬ ϲ͕ϯϯϵ Ϯ͘ϵϵϮ ĂƌďŝĚĞůĂƐƚZŝŶŐƐϲ͕ϯϰϰΖͲϲ͕ϯϲϲΖ 'Ϯϭ ϲ͕ϰϯϲ Ϯ͘ϳϱ ^ĞůĞĐƚĂ&ůŽǁ^ĐƌĞĞŶǁͬϮ͘ϳϱΗyWƌŽĨŝůĞKƉĞŶƐŽǁŶ 'ϮϮ ϲ͕ϱϭϲ Ϯ͘ϴϳϱ ϱϵϴͲϮϴϳWƌĞŵŝĞƌWĂĐŬĞƌƐƐĞŵďůǇ 'Ϯϯ ϲ͕ϱϯϴ Ϯ͘ϳϱ ,ĂůůŝďƵƌƚŽŶ&ƌĂĐŽŽƌ;ĐůŽƐĞĚϭϬͬϮϳͬϮϬϭϮͿ 'Ϯϰ ϲ͕ϱϱϬ Ϯ͘ϵϵϮ ĂƌďŝĚĞůĂƐƚZŝŶŐϯ͕ϱϱϴΖͲϲ͕ϱϳϲΖ 'Ϯϱ ϲ͕ϱϴϮ Ϯ͘ϳϱ ^ĞůĞĐƚĂ&ůŽǁ^ĐƌĞĞŶǁͬϮ͘ϳϱΗyWƌŽĨŝůĞKƉĞŶƐŽǁŶ 'Ϯϲ ϲ͕ϱϵϴ Ϯ͘ϴϳϱ ϱϵϴͲϮϴϳWƌĞŵŝĞƌWĂĐŬĞƌƐƐĞŵďůǇ 'Ϯϳ ϲ͕ϲϮϰ ϯ Ăůů^ĞĂƚ^ŚĞĂƌ^ƵďĨŽƌϭΗKĂůů͕ϱϬϬϬW^/нͬͲ^ŚĞĂƌZĞƋƵŝƌĞĚ ^ƵŵƉWĂĐŬĞƌ /͘ ĞƉƚŚD;Ĩƚ͘Ϳ /;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ ^ϭ ϱ͕ϲϴϵ ϰ ^,WͲ//ϳΗǆϰΗϮϲͲϯϮηE/ ^Ϯ ϱ͕ϲϵϰ ϰ͘ϭϵϱ ^ĞĂů,ŽƵƐĞǆƚĞŶƐŝŽŶϱΗϭϴηϳĨƚ͘>Ő͘ ^ϯ ϱ͕ϳϬϭ Ϯ͘ϵϳϱ yK^Ƶďϰ͘ϴϭϮΗͲϴ^ǆǆϯ͘ϱΗϵ͘ϯηhϴƌĚWŶͲ͘ϲϳΗ>Ő͘EZϭϭ<Ɛŝ^ƚĚ ^ϰ ϱ͕ϳϬϰ ϰ͘ϲϮϱ EŽŶ^ĞĂůŝŶŐKǀĞƌƐŚŽƚϮͬϱ͘ϵϯΖ^ǁĂůůŽǁ &ŝƐŚͬKƚŚĞƌ /͘ ĞƉƚŚD;Ĩƚ͘Ϳ /;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ Wϭ ϱ͕ϳϮϰ Ͳ ϯ͘ϱΗYƵŝŬƌŝůůŽŵƉŽƐŝƚĞWůƵŐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB WŐ͘ϯ hƉĚĂƚĞĚďǇ:>>ϬϰͬϬϲͬϮϮ WZKWK^ ĞůƵŐĂZŝǀĞƌhŶŝƚ tĞůů͗ZhϮϰϰͲϮϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϱͬϮϵͬϮϬϭϰ Wd͗ϮϭϮͲϬϲϵ W/͗ϱϬͲϮϴϯͲϮϬϭϲϱͲϬϬͲϬϬ WZ&KZd/KEd/> ^ĂŶĚƐͬŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ ŵƚ ĂƚĞ ^ƚĂƚƵƐ >ϱʹ >&ϭϬ цϱ͕ϬϴϮ цϱ͕ϱϵϭ цϰ͕Ϯϰϭ цϰ͕ϳϮϰ͛ цϱϬϵ͛ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ ĞůƵŐĂ ϱ͕ϭϮϯ͛ ϱ͕ϭϯϭ͛ ϰ͕Ϯϱϲ͛ ϰ͕Ϯϲϰ͛ ϴ͛ ϵͬϮϯͬϮϬϮϭ KƉĞŶ ĞůƵŐĂ ϱ͕ϭϴϮΖ ϱ͕ϭϵϭΖ ϰ͕ϯϭϱΖ ϰ͕ϯϮϰΖ ϵΖ ϲͬϴͬϮϬϭϰ KƉĞŶ ĞůƵŐĂ& ϱ͕Ϯϯϲ͛ ϱ͕ϮϰϮ͛ ϰ͕ϯϲϵ͛ ϰ͕ϯϳϱ͛ ϲ͛ ϵͬϮϯͬϮϬϮϭ KƉĞŶ ĞůƵŐĂ& ϱ͕Ϯϳϰ͛ ϱ͕Ϯϵϰ͛ ϰ͕ϰϬϴ͛ ϰ͕ϰϮϴ͛ ϮϬ͛ ϵͬϮϯͬϮϬϮϭ KƉĞŶ ĞůƵŐĂ& ϱ͕ϰϰϵ͛ ϱ͕ϰϱϲ͛ ϰ͕ϱϴϮ͛ ϰ͕ϱϴϵ͛ ϳ͛ ϵͬϮϯͬϮϬϮϭ KƉĞŶ ĞůƵŐĂ& ϱ͕ϰϲϳ͛ ϱ͕ϰϴϬ͛ ϰ͕ϲϬϬ͛ ϰ͕ϲϭϯ͛ ϭϯ͛ ϵͬϮϯͬϮϬϮϭ KƉĞŶ ĞůƵŐĂ& ϱ͕ϱϮϬ͛ ϱ͕ϱϮϳ͛ ϰ͕ϲϱϯ͛ ϰ͕ϲϲϬ͛ ϳ͛ ϲͬϴͬϮϬϭϰ KƉĞŶ ĞůƵŐĂ& ϱ͕ϱϯϴ͛ ϱ͕ϱϰϴ͛ ϰ͕ϲϳϭ͛ ϰ͕ϲϴϭ͛ ϭϬ͛ ϲͬϴͬϮϬϭϰ KƉĞŶ ĞůƵŐĂ& ϱ͕ϱϴϲ͛ ϱ͕ϱϵϮ͛ ϰ͕ϳϭϵ͛ ϰ͕ϳϮϰ͛ ϲ͛ ϵͬϮϯͬϮϬϮϭ KƉĞŶ ĞůƵŐĂ& ϱ͕ϲϬϵΖ ϱ͕ϲϯϭΖ ϰ͕ϳϰϮΖ ϰ͕ϳϲϰΖ ϮϮΖ ϲͬϴͬϮϬϭϰ KƉĞŶ ĞůƵŐĂ' ϱ͕ϲϰϰ͛ ϱ͕ϲϰϵ͛ ϰ͕ϳϳϳ͛ ϰ͕ϳϴϮ͛ ϱ͛ ϵͬϮϯͬϮϬϮϭ KƉĞŶ ĞůƵŐĂ' ϱ͕ϲϲϮΖ ϱ͕ϲϳϳΖ ϰ͕ϳϵϱΖ ϰ͕ϴϭϬΖ ϭϱΖ ϲͬϴͬϮϬϭϰ KƉĞŶ ĞůƵŐĂ' ϱ͕ϴϮϳΖ ϱ͕ϴϯϯΖ ϰ͕ϵϲϬΖ ϰ͕ϵϲϲΖ ϲΖ ϵͬϭϯͬϮϬϭϮ KƉĞŶ ĞůƵŐĂ, ϲ͕ϬϱϬΖ ϲ͕ϬϲϭΖ ϱ͕ϭϴϯΖ ϱ͕ϭϵϰΖ ϭϭΖ ϵͬϯͬϮϬϭϮ KƉĞŶ ĞůƵŐĂ, ϲ͕ϮϭϳΖ ϲ͕ϮϯϯΖ ϱ͕ϯϱϬΖ ϱ͕ϯϲϲΖ ϭϲΖ ϴͬϵͬϮϬϭϮ KƉĞŶ ĞůƵŐĂ, ϲ͕ϮϲϮΖ ϲ͕ϮϳϬΖ ϱ͕ϯϵϱΖ ϱ͕ϰϬϯΖ ϴΖ ϴͬϵͬϮϬϭϮ KƉĞŶ ĞůƵŐĂ, ϲ͕ϯϬϳΖ ϲ͕ϯϬϵΖ ϱ͕ϰϰϬΖ ϱ͕ϰϰϮΖ ϮΖ ϴͬϵͬϮϬϭϮ KƉĞŶ ĞůƵŐĂ, ϲ͕ϯϰϳΖ ϲ͕ϯϲϭΖ ϱ͕ϰϴϬΖ ϱ͕ϰϵϰΖ ϭϰΖ ϴͬϵͬϮϬϭϮ KƉĞŶ ĞůƵŐĂ, ϲ͕ϱϲϯΖ ϲ͕ϱϳϭΖ ϱ͕ϲϵϲΖ ϱ͕ϳϬϰΖ ϴΖ ϴͬϵͬϮϬϭϮ KƉĞŶ ĞůƵŐĂ/ ϲ͕ϲϴϲΖ ϲ͕ϳϬϬΖ ϱ͕ϴϭϵΖ ϱ͕ϴϯϯΖ ϭϰΖ ϵͬϯͬϮϬϭϮ KƉĞŶ ĞůƵŐĂ/ ϳ͕ϬϯϬΖ ϳ͕ϬϰϮΖ ϲ͕ϭϲϯΖ ϲ͕ϭϳϱΖ ϭϮΖ ϵͬϯͬϮϬϭϮ KƉĞŶ ĞůƵŐĂ/ ϳ͕ϬϵϲΖ ϳ͕ϭϬϴΖ ϲ͕ϮϮϵΖ ϲ͕ϮϰϭΖ ϭϮΖ ϵͬϭͬϮϬϭϮ KƉĞŶ ^d/Dh>d/KEd/> ^ĂŶĚƐͬŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ ŵƚ ĂƚĞ ^ƚĂƚƵƐ ĞůƵŐĂ ϱϭϴϮ ϱ͕ϭϵϭΖ ϰ͕ϯϭϱΖ ϰ͕ϯϮϰΖ ϵΖ ϲͬϭϯͬϮϬϭϰ ϮϬͲϰϬĂƌďŽůŝƚĞǁͬ ϲй<> ĞůƵŐĂ& ϱϱϮϬ ϱ͕ϲϳϳΖ ϰ͕ϲϱϯΖ ϰ͕ϴϭϬΖ ϭϱϳΖ ϲͬϭϮͬϮϬϭϰ ϮϬͲϰϬĂƌďŽůŝƚĞǁͬ ϲй<> ĞůƵŐĂ' ϱϴϮϳ ϱϴϯϯ ϰ͕ϵϲϬΖ ϰ͕ϵϲϲΖ ϲΖ ϵͬϭϯͬϮϬϭϮ ϮϬͲϰϬĞƌĂŵŝĐ ƉƌŽƉƉĂŶƚ ĞůƵŐĂ, ϲϬϱϬ ϲ͕ϯϬϵΖ ϱ͕ϰϰϬΖ ϱ͕ϰϰϮΖ ϮϱϵΖ ϵͬϭϯͬϮϬϭϮ ϮϬͲϰϬWŽůĂƌWƌŽƉƉĂŶƚ ĞůƵŐĂ, ϲϬϱϬ ϲ͕ϯϬϵΖ ϱ͕ϯϵϱΖ ϱ͕ϰϬϯΖ ϮϱϵΖ ϵͬϭϯͬϮϬϭϮ ϮϬͲϰϬWŽůĂƌWƌŽƉƉĂŶƚ ĞůƵŐĂ, ϲϬϱϬ ϲϯϬϵ ϱ͕ϯϵϱΖ ϱ͕ϯϵϲΖ ϮϱϵΖ ϵͬϭϯͬϮϬϭϮ ϮϬͲϰϬWŽůĂƌWƌŽƉƉĂŶƚ ĞůƵŐĂ, ϲϬϱϬ ϲ͕ϯϬϵΖ ϱ͕ϭϴϯΖ ϱ͕ϭϵϰΖ ϮϱϵΖ ϵͬϭϯͬϮϬϭϮ ϮϬͲϰϬWŽůĂƌWƌŽƉƉĂŶƚ ĞůƵŐĂ, ϲϯϰϳ ϲ͕ϯϲϭΖ ϱ͕ϰϴϬΖ ϱ͕ϰϵϰΖ ϭϰΖ ϵͬϭϮͬϮϬϭϮ ϮϬͲϰϬWŽůĂƌZĞƐŝŶͲ ŽĂƚĞĚWƌŽƉƉĂŶƚ ĞůƵŐĂ, ϲϱϲϯ ϳϭϬϴ ϲ͕ϮϮϵΖ ϲ͕ϮϰϭΖ ϱϰϱΖ ϵͬϳͬϮϬϭϮ ϮϬͲϰϬĞƌĂŵŝĐ WƌŽƉƉĂŶƚ ĞůƵŐĂ, ϲϱϲϯ ϳϭϬϴ ϱ͕ϴϭϵΖ ϱ͕ϴϯϯΖ ϱϰϱΖ ϵͬϳͬϮϬϭϮ ϮϬͲϰϬĞƌĂŵŝĐ WƌŽƉƉĂŶƚ ĞůƵŐĂ, ϲϱϲϯ ϳϭϬϴ ϱ͕ϲϵϲΖ ϱ͕ϳϬϰΖ ϱϰϱΖ ϵͬϳͬϮϬϭϮ ϮϬͲϰϬĞƌĂŵŝĐ WƌŽƉƉĂŶƚ цϱϬϵ͛ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/08/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BRU 244-23 (PTD 212-069) Perforation Record 09/24/2021 Please include current contact information if different from above. 37' (6HW Received By: 11/09/2021 By Abby Bell at 8:45 am, Nov 09, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7,553 feet N/A feet true vertical 6,685 feet N/A feet Effective Depth measured 7,458 feet See Schematic feet true vertical 6,591 feet See Schematic feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Gravel Pk Assembly Tubing (size, grade, measured and true vertical depth)3.5" 9.3# / L-80 5,071' MD 4,204' TVD Gravel Pk Iso Pkrs Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title:Contact Phone: 5,410psi 1,530psi 5,750psi 7,240psi Burst Collapse 520psi 3,090psi 107' 2,790' 6,675'7,542'7" measuredPlugs Junk measured N/A Length 83' 3,404' Size Conductor Surface Intermediate 20" 9-5/8" Production Liner 7,522' Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 212-069 50-283-20165-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL021127; ADL0017658 Beluga River/Undefined Gas Pool Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Beluga River Unit (BRU) 244-23 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 202,694 0 963 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 107' 3,247' 20 Structural TVD 321-446 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 26 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 740 Jake Flora, Operations Engineer jake.flora@hilcorp.com 907-777-8442Dan Marlowe, ASC Team Operations Manager, 907-283-1329 5048'(4177'), 5195'(4310'), 5711'(4750'), 5973'(5110'), 6320'(5445'), 6516'(5645'), 6598'(5686') t Fra O 6. A PG , R Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 8:13 am, Oct 20, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.10.19 14:44:59 -08'00' Dan Marlowe (1267) RBDMS HEW 10/21/2021 SFD 10/20/2021BJM 10/22/21 DSR-10/20/21 Rig Start Date End Date E-Line 9/23/21 9/23/21 09/23/2021 - Thursday PTW and safety meeting, arrive on location rig up arm gun 1 PT to 2,500#. RIH gun 1 (5' x 2-3/8") CCL -TS=16'. Correlate 5,628'. RIH shot depth 5,644' to 5,649' 5' shot on depth shot fired POOH (well psi 856) no change on pressure. OOH / MU Gun 2 (5' x 2-3/8') CCL-TS=16'. RIH correlate, log sent to town on depth 5,570' CCL depth, shot depth 5,586' to 5,592' shot fired POOH Well PSI 851, no change in pressure. OOH / MU gun 3 (13' x 2-3/8") CCL of 9'. RIH shot depth 5,458' CCL depth, correlate, log to town, shot 5,467' to 5,480' shot fired. POOH, well psi 857# jump to 870#. OOH / MU gun 4, 7' x 2- 3/8" CCL 11' shot depth 5,438' CCL depth. RIH. Correlate log to town shot 5,449'-5,456' shot fired. POOH, well psi 869# jumped to 871#. OOH / MU gun 5, 20' x 2-3/8" CCL of 9', shot depth 5,265' CCL depth. RIH correlate log to town 5,274'- 5,294' shot fired. POOH, well psi 886# jump to 895#. OOH / MU gun 6, 6' x 2-3/8" CCL 15'.2", shot depth 5,220.8' CCL depth. RIH correlate log to town 5,236'-5,242' shot fired. POOH, well psi 950# down to 944#. OOH / MU gun 7, 8' x 2- 3/8" CCL 10' shot depth 5,113' CCL depth. RIH, correlate log to town 5,123'-5,131' shot fired. POOH, well psi 893# 60 seconds psi to 1,000#. OOH / Rig down. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 244-23 50-283-20165-00-00 212-069 5,274'- 5,294' shot fired. 5,123'-5,131' shot fired. shot depth 5,586' to 5,592' 5,236'-5,242' shot fired. shot 5,449'-5,456' shot depth 5,644' to 5,649' 5 shot 5,467' to 5,480' _____________________________________________________________________________________ Pg.1 Updated by DMA 09-29-21 SCHEMATIC Beluga River Unit Well: BRU 244-23 Last Completed: 5/29/2014 PTD: 212-069 API: 50-283-20165-00-00 20” 9-5/8” 7” RKB to MSL = 94’ RKB to GL = 18.5’ TMD = 7,553’ TVD = 6,685’ PBMD = 7,458’ PBTVD = 6,591’ Max Angle = 49.6 deg @ 1,996’ TOC @ 3,470’ 2 3 4 5 6 7 8 5048’ Packer E8 E9 E10 E11/E12 F1 F2 F3 F4 G1 G2 G3 S1-S2 S3-S4 G4 G5 G6 G7 G8 G9 G10 G11 G12 G13-G15 G16 G17 G18 G19 G20 G21 G22 G23 G24 G25 G26 G27 Beluga E P1 F5 F6 5195’ Packer 5711’ Packer 5973’ Packer 6320’ Packer 6516’ Packer 6598’ Packer Beluga F - G CASING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 165#H-40 Weld 18.73''107' 9-5/8"Surface 40#L-80 BTC-M 8.835''3,427' 7''Production 26#L-80 BTC-M 6.276''7,542' TUBING DETAILS 3.5''Production String 9.3#L-80 EUE 2.992''5,071' 4"Gravel Pack 'E'11.6#P-110 SLHT R2 3.428''5,201' 4''Gravel Pack 'F/G'11.6#P-110 SLHT R2 3.428''5,701' 3.5''Gravel Pack 9.3#L-80 IBT 2.992''6,625' 5.05''Sump Packer 8SA 4.195''5,710' JEWELRY DETAIL Production String ID.Depth MD, ft ID (in.)Description 1 18 3.9 Vetco Gray Tubing Hanger 2 22 3 Xo 4.5" IBT(B) x 3.5" EUE 8rd(p) 3 498 2.813 Camco Tmaxx-5E SSSV - X profile 4 3,333 2.92 Camco KBMG-LTS GLM 5 4,975 2.992 Caco GLM, OV Valve & RKP Latch 6 5,025 2.813 HES X Nipple 7 5,059 2.91 Locator Pop Loc 8 5,061 2.92 Unit Seal 9 5,069 2.912 Muleshoe Indexing 4" w/ spring guard Gravel Pack 'E' Interval E1 5,048 4 Packer 7"x4" 26-32# NI w/5.125" 8 E3 5,053 4.195 Extension Seal house E6 5,068 3.403 Seal house Extension E7 5,072 2.81 Locator w/3.906"-8SA Bx x 5" - 8SA Pn E8 5,086 2.75 MS Sleeve Cis 7"x2.75" E9 5,092 2.893 Indicator Circ. Valve E10 5,103 3.413 Sub XO 3.906" 8SA Bx x 4" 11.6# SLHT E11 5,169 2.937 Screen,4" 12 E12 5,174 2.83 Screen, 4" 12-Ga 316L, 10.9# P-110 Gravel Pack 'F/G' Interval F1 5186 3.385 XO 4" 11.6# SLHT Bx x 3.906" - 8SA F2 5187 2.81 Locator, Auto 7027 NI f/MST F3 5195 2.816 Isolation Packer 7027 26# VI F/MST F4 5201 2.75 MS Sleeve Cls 7"x2.75" BD/VI & NI f F5 5207 2.893 Circ. Valve Indicator 7027 7.01' F6 5217 3.413 XO 3.906" - 8SA Bx x 4" 11.6# F7 5498 2.937 Screen, Top DynaFlo F8 5516 2.83 Screen, 4" 12-Ga. 316L 10.9# P-110 F9 5549 2.937 Screen, 4" 12-Ga. 316L 10.9# P-110 F10 5583 2.937 Screen,4" 12-Ga. 316L 10.9# P-110 F11 5617 2.937 Screen, 4" 12-Ga 316L, 10.9# P-110 F12 5651 2.83 Screen, 4" 12-Ga 316L, 10.9# P-110 F13 5681 3.385 XO 4" F14 5682 2.775 De-Crippler Rocker Style 7027 VI F15 5689 2.91 Locator, Pop Lac w/3.5" 9.3# F16 5691 2.92 Unit Seal F17 5698 2.915 Disappearing Check Valve F18 5699 2.912 Muleshoe _____________________________________________________________________________________ Pg.2 Updated by DMA 09-29-21 SCHEMATIC Beluga River Unit Well: BRU 244-23 Last Completed: 5/29/2014 PTD: 212-069 API: 50-283-20165-00-00 Gravel Pack ID. Depth MD (ft.) ID (in.) Description G1 5,665 5.25 HR Liner Setting Sleeve G2 5,677 4.26 RS Nipple G3 5,680 4.25 80-40 Seal Bore G4 5,700 4.5 Crossover 5"x4.5" G5 5,711 3.87 598-387 Premier Packer G6 5,719 3.5 Crossover 4.5"x3.5" G7 5,732 2.813 X' Nipple G8 5,777 2.75 Halliburton Frac Door (closed 10/27/2012) G9 5,819 2.992 Carbide Blast Rings 5,824'-5,838' G10 5,858 2.75 Selecta Flow Screen w/ 2.75" X Profile Opens Down G11 5,973 2.875 598-287 Premier Packer Assembly G12 6,030 2.75 Halliburton Frac Door (closed 10/27/2012) G13 6,042 2.992 Carbide Blast Rings 6,047'-6,066' G14 6,211 2.992 Carbide Blast Rings 6,215'-6,238' G15 6,256 2.992 Carbide Blast Rings 6,260'-6,275' G16 6,293 2.75 Selecta Flow Screen w/ 2.75" X Profile Opens Down G17 6,300 2.992 Carbide Blast Rings 6,344'-6,366' G18 6,320 2.875 698-287 Premier Packer Assembly G19 6,333 2.75 Halliburton Frac Door (closed 10/27/2012) G20 6,339 2.992 Carbide Blast Rings 6,344'-6,366' G21 6,436 2.75 Selecta Flow Screen w/ 2.75" X Profile Opens Down G22 6,516 2.875 598-287 Premier Packer Assembly G23 6,538 2.75 Halliburton Frac Door (closed 10/27/2012) G24 6,550 2.992 Carbide Blast Ring 3,558'-6,576' G25 6,582 2.75 Selecta Flow Screen w/ 2.75" X Profile Opens Down G26 6,598 2.875 598-287 Premier Packer Assembly G27 6,624 3 Ball Seat Shear Sub for 1" OD Ball, 5000 PSI +/- Shear Required Sump Packer ID. Depth MD (ft.) ID (in.) Description S1 5,689 4 CSHP-II 7"x4" 26-32# NI S2 5,694 4.195 Seal House Extension 5" 18# 7ft. Lg. S3 5,701 2.975 XO Sub 4.812"-8SA Bx x 3.5" 9.3# EU 8rd Pn-.67" Lg. NR 11Ksi Std S4 5,704 4.625 Non Sealing Overshot 2/5.93' Swallow Fish/Other ID. Depth MD (ft.) ID (in.) Description P1 5,724 - 3.5" Quik Drill Composite Plug _____________________________________________________________________________________ Pg.3 Updated by DMA 09-29-21 SCHEMATIC Beluga River Unit Well: BRU 244-23 Last Completed: 5/29/2014 PTD: 212-069 API: 50-283-20165-00-00 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Beluga E 5,123’ 5,131’ 4,256’ 4,264’ 8’ 9/23/2021 Open Beluga E 5,182' 5,191' 4,315' 4,324' 9' 6/8/2014 Open Beluga F 5,236’ 5,242’ 4,369’ 4,375’ 6’ 9/23/2021 Open Beluga F 5,274’ 5,294’ 4,408’ 4,428’ 20’ 9/23/2021 Open Beluga F 5,449’ 5,456’ 4,582’ 4,589’ 7’ 9/23/2021 Open Beluga F 5,467’ 5,480’ 4,600’ 4,613’ 13’ 9/23/2021 Open Beluga F 5,520’ 5,527’ 4,653’ 4,660’ 7’ 6/8/2014 Open Beluga F 5,538’ 5,548’ 4,671’ 4,681’ 10’ 6/8/2014 Open Beluga F 5,586’ 5,592’ 4,719’ 4,724’ 6’ 9/23/2021 Open Beluga F 5,609' 5,631' 4,742' 4,764' 22' 6/8/2014 Open Beluga G 5,644’ 5,649’ 4,777’ 4,782’ 5’ 9/23/2021 Open Beluga G 5,662' 5,677' 4,795' 4,810' 15' 6/8/2014 Open Beluga G 5,827' 5,833' 4,960' 4,966' 6' 9/13/2012 Open Beluga H 6,050' 6,061' 5,183' 5,194' 11' 9/3/2012 Open Beluga H 6,217' 6,233' 5,350' 5,366' 16' 8/9/2012 Open Beluga H 6,262' 6,270' 5,395' 5,403' 8' 8/9/2012 Open Beluga H 6,307' 6,309' 5,440' 5,442' 2' 8/9/2012 Open Beluga H 6,347' 6,361' 5,480' 5,494' 14' 8/9/2012 Open Beluga H 6,563' 6,571' 5,696' 5,704' 8' 8/9/2012 Open Beluga I 6,686' 6,700' 5,819' 5,833' 14' 9/3/2012 Open Beluga I 7,030' 7,042' 6,163' 6,175' 12' 9/3/2012 Open Beluga I 7,096' 7,108' 6,229' 6,241' 12' 9/1/2012 Open STIMULATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Beluga E 5182 5,191' 4,315' 4,324' 9' 6/13/2014 20-40 Carbolite w/ 6%KCL Beluga F 5520 5,677' 4,653' 4,810' 157' 6/12/2014 20-40 Carbolite w/ 6%KCL Beluga G 5827 5833 4,960' 4,966' 6' 9/13/2012 20-40 Ceramic proppant Beluga H 6050 6,309' 5,440' 5,442' 259' 9/13/2012 20-40 Polar Proppant Beluga H 6050 6,309' 5,395' 5,403' 259' 9/13/2012 20-40 Polar Proppant Beluga H 6050 6309 5,395' 5,396' 259' 9/13/2012 20-40 Polar Proppant Beluga H 6050 6,309' 5,183' 5,194' 259' 9/13/2012 20-40 Polar Proppant Beluga H 6347 6,361' 5,480' 5,494' 14' 9/12/2012 20-40 Polar Resin-Coated Proppant Beluga H 6563 7108 6,229' 6,241' 545' 9/7/2012 20-40 Ceramic Proppant Beluga H 6563 7108 5,819' 5,833' 545' 9/7/2012 20-40 Ceramic Proppant Beluga H 6563 7108 5,696' 5,704' 545' 9/7/2012 20-40 Ceramic Proppant Sands/Zone Top (MD) Btm (MD) Top (TVD)Btm (TVD)Amt Date Status Beluga E 5,123’5,131’ 4,256’4,264’8’9/23/2021 Open Sands/Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)Amt Date Status Beluga F 5,586’5,592’ 4,719’4,724’6’9/23/2021 Open 9/23/20215’4,782’4,777’5,649’ 5,644’Beluga G Open Beluga F 5,236’5,242’ 4,369’4,375’6’9/23/2021 Open Beluga F 5,274’5,294’ 4,408’4,428’20’9/23/2021 Open Beluga F 5,449’5,456’ 4,582’4,589’7’9/23/2021 Open Beluga F 5,467’5,480’ 4,600’4,613’13’9/23/2021 Open 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: _______N2__________ 2.Operator Name:4.Current Well Class:5. Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 7,553'NA Casing Collapse Structural Conductor 520psi Surface 3,090psi Intermediate Production 5,410psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng jake.flora@hilcorp.com 6,685'7,458'6,591'2,096 NA Gravel Pack Isolation Packers: 5048'(4177'), 5195'(4310'), 5711'(4750'), 5973'(5110'), 6320'(5445'), 6516'(5645'), 6598'(5686') Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL021127 212-069 50-283-20165-00-00 BRU 244-23 Beluga River Gas Length Size State Wide Spacing Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY L-80, 9.3# TVD Burst 5,071' 7,240psi MD 1,530psi 5,750psi 107' 2,790' 107' 3,427' 6,675'7" 20" 9-5/8" 83' 3,404' 7,542' Perforation Depth MD (ft): See Attached Schematic 7,522' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: September 11, 2021 3.5" (gravel pack assembly) Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 1:04 pm, Sep 03, 2021 /Undefined 321-446 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.03 11:48:53 -08'00' Taylor Wellman (2143) 10-404 DLB 09/03/2021 CO 658 grants a spacing exception for BRU 244-23. ; ADL0017658 DLB X SFD 9/7/2021 BJM 9/9/21 DSR-9/3/21 dts 9/9/2021 JLC 9/10/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.10 14:18:20 -08'00' RBDMS HEW 9/13/2021 Well Prognosis Well: BRU 244-23 Date: 08/26/2021 Well Name: BRU 244-23 API Number: 50-283-20165-00-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: 9/11/21 Rig: N/A Reg. Approval Req’d? 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 212-069 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 Second Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 Reg. Approval Req’d? 10-403 Date Reg. Approval Rec’vd: Maximum Expected BHP: ~ 2694 psi @ 5988’ TVD (Using 0.45psi/ft gradient) Max. Potential Surface Pressure: ~ 2096 psi (Gradient munis 0.1 psi/ft) Well Status: BRU 244-23 is currently shut-in 3-1/2” multistage gravel pack completion through the Beluga E-I sands sands. Brief Well Summary: Originally drilled and completed as a producer in the Beluga G, H, and I sand in 2012. It was fracture stimulated after the rig moved off. In 2014, it was worked over adding the Beluga E, F, and G sands and gravel packed within those intervals while keeping the lower Beluga completion that were originally perf'd. In January 2020, the well loaded/sanded up and died. The well has cum’d 6.8 BCF to date. Objective: In an effort to return BRU 244-23 production, it is recommended to drift/tag with slickline, possible bail, and add multiple beluga perfs thru tbg/gravel packs to bring the well back online. Well Notes: - Minimum ID is 2.75” within the 3-1/2” gravel pack completion - Last tag @ 5,664’ KB w/ 2.5” x 6’ DD bailer on 3/2/20. Fluid level detected at 5150’ KB. Procedure: 1. MIRU Slickline, PT Lubricator 3000 psi. 2. Tag top of fill, bail as deep as possible to uncover the below perfs. 3. MIRU E-line, PT lubricator to 250 psi low and 3000 psi high. 4. Perforate the below zones from the bottom up: Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom BELUGA E5 ±5,082’ ±5,089’ ±7’ ±4,215’ ±4,222’ BELUGA E6 ±5,123’ ±5,131’ ±8’ ±4,256’ ±4,264’ BELUGA F4 ±5,236’ ±5,242’ ±6’ ±4,369’ ±4,375’ BELUGA F4 ±5,274’ ±5,294’ ±20’ ±4,408’ ±4,428’ BELUGA F7 ±5,449’ ±5,456’ ±7’ ±4,582’ ±4,589’ BELUGA F7 ±5,467’ ±5,480’ ±13’ ±4,600’ ±4,613’ BELUGA F10 ±5,586’ ±5,592’ ±5’ ±4,719’ ±4,724’ BELUGA G1 ±5,644’ ±5,649’ ±5’ ±4,777’ ±4,782’ BELUGA G2 ±5,709’ ±5,718’ ±9’ ±4,841’ ±4,850’ BELUGA G3 ±5,722’ ±5,726’ ±4’ ±4,854’ ±4,858’ Well Prognosis Well: BRU 244-23 Date: 08/26/2021 BELUGA G3 ±5,733’ ±5,740’ ±7’ ±4,865’ ±4,872’ BELUGA G8 ±5,849’ ±5,853’ ±4’ ±4,981’ ±4,985’ BELUGA G9 ±5,862’ ±5,869’ ±8’ ±4,995’ ±5,003’ BELUGA H ±5,981’ ±5,990’ ±9’ ±5,114’ ±5,123’ BELUGA H1 ±6,023’ ±6,030’ ±7’ ±5,155’ ±5,162’ BELUGA H4 ±6,108’ ±6,116’ ±8’ ±5,240’ ±5,248’ BELUGA I ±6,654’ ±6,662’ ±8’ ±5,787’ ±5,795’ BELUGA I5 ±6,855’ ±6,865’ ±10’ ±5,988’ ±5,998’ a. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. b. Use GR/CCL to correlate against Open Hole Log provided by Geologist. Send the correlation pass to the following for confirmation. Reservoir Engineer Trudi Hallett 907.301.6657 Geologist Ben Siks 907.229.0865 c. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. d. The Beluga and Sterling sands can be co-mingled at BRU. 5. RD E-Line. 6. Turn well over to production. Nitrogen (Contingency) 1. If Nitrogen is required to pressure up well prior to perforating or push fluid away: 2. MIRU Nitrogen Unit, review Nitrogen SOP, pressure well to desired perforating pressure. E-line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 3. RIH and set 3-1/2” plug above the zone and dump 35’ of cement on top of the plug. Attachments: Current Well Schematic Proposed Well Schematic Standard Well Procedure – N2 Operations _____________________________________________________________________________________ Pg.1 Created By: JMF 8/26/2021 SCHEMATIC Beluga River Unit Well: BRU 244-23 Last Completed: 5/29/2014 PTD: 212-069 API: 50-283-20165-00 20” 9-5/8” 7” RKB to MSL = 94’ RKB to GL = 18.5’ TMD = 7,553’ TVD = 6,685’ PBMD = 7,458’ PBTVD = 6,591’ Max Angle = 49.6 deg @ 1,996’ TOC @ 3,470’ 2 3 4 5 6 7 8 E1 E2 E3 E4-E6 E7 E8 E9 E10 E11/E12 F1 F2 F3 F4 G1 G2 G3 S1-S2 S3-S4 G4 G5 G6 G7 G8 G9 G10 G11 G12 G13-G15 G16 G17 G18 G19 G20 G21 G22 G23 G24 G25 G26 G27 F13 F14 F15 F16 F17 F18 P1 Beluga Sands E Beluga Sands F F F G F5 F6 G H H H H H H I CASING DETAIL Size Type WT Grade Conn ID Btm 20'' Conductor 165# H-40 Weld 18.73'' 107' 9-5/8" Surface 40# L-80 BTC-M 8.835'' 3,427' 7'' Production 26# L-80 BTC-M 6.276'' 7,542' TUBING DETAILS 3.5'' Production String 9.3# L-80 EUE 2.992'' 5071' 4" Gravel Pack 'E' 11.6# P-110 SLHT R2 3.428'' 5201' 4'' Gravel Pack 'F/G' 11.6# P-110 SLHT R2 3.428'' 5,701' 3.5'' Gravel Pack 9.3# L-80 IBT 2.992'' 6,625' 5.05'' Sump Packer 8SA 4.195'' 5,710' JEWELRY DETAIL Production String ID. Depth MD, ft ID (in.) Description 1 18 3.9 Vetco Gray Tubing Hanger 2 22 3 Xo 4.5" IBT(B) x 3.5" EUE 8rd(p) 3 498 2.813 Camco Tmaxx-5E SSSV - X profile 4 3,333 2.92 Camco KBMG-LTS GLM 5 4,975 2.992 Camco GLM, OV Valve & RKP Latch 6 5,025 2.813 HES X Nipple 7 5,059 2.91 Locator Pop Loc 8 5,061 2.92 Unit Seal 9 5,069 2.912 Muleshoe Indexing 4" w/ spring guard Gravel Pack 'E' Interval E1 5,048 4 Packer 7"x4" 26-32# NI w/5.125" 8 E2 5,053 4.485 Coupling Comb E3 5,053 4.195 Extension Seal house E4 5,065 3.125 Union, Quick E5 5,067 3.456 Tubing Coupling E6 5,068 3.403 Seal house Extension E7 5,072 2.81 Locator w/3.906"-8SA Bx x 5" - 8SA Pn E8 5,086 2.75 MS Sleeve Cis 7"x2.75" E9 5,092 2.893 Indicator Circ. Valve E10 5,103 3.413 Sub XO 3.906" 8SA Bx x 4" 11.6# SLHT E11 5,169 2.937 Screen,4" 12 E12 5,174 2.83 Screen, 4" 12-Ga 316L, 10.9# P-110 Gravel Pack 'F/G' Interval F1 5186 3.385 XO 4" 11.6# SLHT Bx x 3.906" - 8SA F2 5187 2.81 Locator, Auto 7027 NI f/MST F3 5195 2.816 Isolation Packer 7027 26# VI F/MST F4 5201 2.75 MS Sleeve Cls 7"x2.75" BD/VI & NI f F5 5207 2.893 Circ. Valve Indicator 7027 7.01' F6 5217 3.413 XO 3.906" - 8SA Bx x 4" 11.6# F7 5498 2.937 Screen, Top DynaFlo F8 5516 2.83 Screen, 4" 12-Ga. 316L 10.9# P-110 F9 5549 2.937 Screen, 4" 12-Ga. 316L 10.9# P-110 F10 5583 2.937 Screen,4" 12-Ga. 316L 10.9# P-110 F11 5617 2.937 Screen, 4" 12-Ga 316L, 10.9# P-110 F12 5651 2.83 Screen, 4" 12-Ga 316L, 10.9# P-110 F13 5681 3.385 XO 4" F14 5682 2.775 De-Crippler Rocker Style 7027 VI F15 5689 2.91 Locator, Pop Lac w/3.5" 9.3# F16 5691 2.92 Unit Seal F17 5698 2.915 Disappearing Check Valve F18 5699 2.912 Muleshoe -00 DLB _____________________________________________________________________________________ Pg.1 Created By: JMF 8/26/2021 PROPOSED Beluga River Unit Well: BRU 244-23 Last Completed: 5/29/2014 PTD: 212-069 API: 50-283-20165-00 20” 9-5/8” 7” RKB to MSL = 94’ RKB to GL = 18.5’ TMD = 7,553’ TVD = 6,685’ PBMD = 7,458’ PBTVD = 6,591’ Max Angle = 49.6 deg @ 1,996’ TOC @ 3,470’ 2 3 4 5 6 7 8 5048’ Packer E8 E9 E10 E11/E12 F1 F2 F3 F4 G1 G2 G3 S1-S2 S3-S4 G4 G5 G6 G7 G8 G9 G10 G11 G12 G13-G15 G16 G17 G18 G19 G20 G21 G22 G23 G24 G25 G26 G27 Proposed Beluga: E5 - E6 P1 F5 F6 5195’ Packer 5711’ Packer 5973’ Packer 6320’ Packer 6516’ Packer 6598’ Packer Proposed Beluga: F4 - G1 Proposed Beluga: G2 – G9 Proposed Beluga: H1 – H4 Proposed Beluga: I – I5 CASING DETAIL Size Type WT Grade Conn ID Btm 20'' Conductor 165# H-40 Weld 18.73'' 107' 9-5/8" Surface 40# L-80 BTC-M 8.835'' 3,427' 7'' Production 26# L-80 BTC-M 6.276'' 7,542' TUBING DETAILS 3.5'' Production String 9.3# L-80 EUE 2.992'' 5071' 4" Gravel Pack 'E' 11.6# P-110 SLHT R2 3.428'' 5201' 4'' Gravel Pack 'F/G' 11.6# P-110 SLHT R2 3.428'' 5,701' 3.5'' Gravel Pack 9.3# L-80 IBT 2.992'' 6,625' 5.05'' Sump Packer 8SA 4.195'' 5,710' JEWELRY DETAIL Production String ID. Depth MD, ft ID (in.) Description 1 18 3.9 Vetco Gray Tubing Hanger 2 22 3 Xo 4.5" IBT(B) x 3.5" EUE 8rd(p) 3 498 2.813 Camco Tmaxx-5E SSSV - X profile 4 3,333 2.92 Camco KBMG-LTS GLM 5 4,975 2.992 Caco GLM, OV Valve & RKP Latch 6 5,025 2.813 HES X Nipple 7 5,059 2.91 Locator Pop Loc 8 5,061 2.92 Unit Seal 9 5,069 2.912 Muleshoe Indexing 4" w/ spring guard Gravel Pack 'E' Interval E1 5,048 4 Packer 7"x4" 26-32# NI w/5.125" 8 E3 5,053 4.195 Extension Seal house E6 5,068 3.403 Seal house Extension E7 5,072 2.81 Locator w/3.906"-8SA Bx x 5" - 8SA Pn E8 5,086 2.75 MS Sleeve Cis 7"x2.75" E9 5,092 2.893 Indicator Circ. Valve E10 5,103 3.413 Sub XO 3.906" 8SA Bx x 4" 11.6# SLHT E11 5,169 2.937 Screen,4" 12 E12 5,174 2.83 Screen, 4" 12-Ga 316L, 10.9# P-110 Gravel Pack 'F/G' Interval F1 5186 3.385 XO 4" 11.6# SLHT Bx x 3.906" - 8SA F2 5187 2.81 Locator, Auto 7027 NI f/MST F3 5195 2.816 Isolation Packer 7027 26# VI F/MST F4 5201 2.75 MS Sleeve Cls 7"x2.75" BD/VI & NI f F5 5207 2.893 Circ. Valve Indicator 7027 7.01' F6 5217 3.413 XO 3.906" - 8SA Bx x 4" 11.6# F7 5498 2.937 Screen, Top DynaFlo F8 5516 2.83 Screen, 4" 12-Ga. 316L 10.9# P-110 F9 5549 2.937 Screen, 4" 12-Ga. 316L 10.9# P-110 F10 5583 2.937 Screen,4" 12-Ga. 316L 10.9# P-110 F11 5617 2.937 Screen, 4" 12-Ga 316L, 10.9# P-110 F12 5651 2.83 Screen, 4" 12-Ga 316L, 10.9# P-110 F13 5681 3.385 XO 4" F14 5682 2.775 De-Crippler Rocker Style 7027 VI F15 5689 2.91 Locator, Pop Lac w/3.5" 9.3# F16 5691 2.92 Unit Seal F17 5698 2.915 Disappearing Check Valve F18 5699 2.912 Muleshoe -00 DLB _____________________________________________________________________________________ Pg.2 Created By: JJ 8/3/2016 SCHEMATIC Beluga River Unit Well: BRU 244-23 Last Completed: 5/29/2014 PTD: 212-069 API: 50-283-20165-00 Gravel Pack ID. Depth MD (ft.) ID (in.) Description G1 5,665 5.25 HR Liner Setting Sleeve G2 5,677 4.26 RS Nipple G3 5,680 4.25 80-40 Seal Bore G4 5,700 4.5 Crossover 5"x4.5" G5 5,711 3.87 598-387 Premier Packer G6 5,719 3.5 Crossover 4.5"x3.5" G7 5,732 2.813 X' Nipple G8 5,777 2.75 Halliburton Frac Door (closed 10/27/2012) G9 5,819 2.992 Carbide Blast Rings 5,824'-5,838' G10 5,858 2.75 Selecta Flow Screen w/ 2.75" X Profile Opens Down G11 5,973 2.875 598-287 Premier Packer Assembly G12 6,030 2.75 Halliburton Frac Door (closed 10/27/2012) G13 6,042 2.992 Carbide Blast Rings 6,047'-6,066' G14 6,211 2.992 Carbide Blast Rings 6,215'-6,238' G15 6,256 2.992 Carbide Blast Rings 6,260'-6,275' G16 6,293 2.75 Selecta Flow Screen w/ 2.75" X Profile Opens Down G17 6,300 2.992 Carbide Blast Rings 6,344'-6,366' G18 6,320 2.875 698-287 Premier Packer Assembly G19 6,333 2.75 Halliburton Frac Door (closed 10/27/2012) G20 6,339 2.992 Carbide Blast Rings 6,344'-6,366' G21 6,436 2.75 Selecta Flow Screen w/ 2.75" X Profile Opens Down G22 6,516 2.875 598-287 Premier Packer Assembly G23 6,538 2.75 Halliburton Frac Door (closed 10/27/2012) G24 6,550 2.992 Carbide Blast Ring 3,558'-6,576' G25 6,582 2.75 Selecta Flow Screen w/ 2.75" X Profile Opens Down G26 6,598 2.875 598-287 Premier Packer Assembly G27 6,624 3 Ball Seat Shear Sub for 1" OD Ball, 5000 PSI +/- Shear Required Sump Packer ID. Depth MD (ft.) ID (in.) Description S1 5,689 4 CSHP-II 7"x4" 26-32# NI S2 5,694 4.195 Seal House Extension 5" 18# 7ft. Lg. S3 5,701 2.975 XO Sub 4.812"-8SA Bx x 3.5" 9.3# EU 8rd Pn-.67" Lg. NR 11Ksi Std S4 5,704 4.625 Non Sealing Overshot 2/5.93' Swallow Fish/Other ID. Depth MD (ft.) ID (in.) Description P1 5,724 - 3.5" Quik Drill Composite Plug -00 DLB _____________________________________________________________________________________ Pg.3 Created By: JJ 8/3/2016 SCHEMATIC Beluga River Unit Well: BRU 244-23 Last Completed: 5/29/2014 PTD: 212-069 API: 50-283-20165-00 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status Beluga E 5,182' 5,191' 4,315' 4,324' 9' 21 6/8/2014 IPERF Beluga F 5,520' 5,527' 4,653' 4,660' 7' 21 6/8/2014 IPERF Beluga F 5,538' 5,548' 4,671' 4,681' 10' 21 6/8/2014 IPERF Beluga F 5,609' 5,631' 4,742' 4,764' 22' 21 6/8/2014 IPERF Beluga G 5,662' 5,677' 4,795' 4,810' 15' 21 6/8/2014 IPERF Beluga G 5,827' 5,833' 4,960' 4,966' 6' 6 9/13/2012 IPERF Beluga H 6,050' 6,061' 5,183' 5,194' 11' 6 9/3/2012 IPERF Beluga H 6,217' 6,233' 5,350' 5,366' 16' 6 8/9/2012 IPERF Beluga H 6,262' 6,270' 5,395' 5,403' 8' 6 8/9/2012 IPERF Beluga H 6,307' 6,309' 5,440' 5,442' 2' 6 8/9/2012 IPERF Beluga H 6,347' 6,361' 5,480' 5,494' 14' 6 8/9/2012 IPERF Beluga H 6,563' 6,571' 5,696' 5,704' 8' 6 8/9/2012 IPERF Beluga I 6,686' 6,700' 5,819' 5,833' 14' 6 9/3/2012 IPERF Beluga I 7,030' 7,042' 6,163' 6,175' 12' 6 9/3/2012 IPERF Beluga I 7,096' 7,108' 6,229' 6,241' 12' 6 9/1/2012 IPERF STIMULATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Beluga E 5182 5,191' 4,315' 4,324' 9' 6/13/2014 20-40 Carbolite w/ 6%KCL Beluga F 5520 5,677' 4,653' 4,810' 157' 6/12/2014 20-40 Carbolite w/ 6%KCL Beluga G 5827 5833 4,960' 4,966' 6' 9/13/2012 20-40 Ceramic proppant Beluga H 6050 6,309' 5,440' 5,442' 259' 9/13/2012 20-40 Polar Proppant Beluga H 6050 6,309' 5,395' 5,403' 259' 9/13/2012 20-40 Polar Proppant Beluga H 6050 6309 5,395' 5,396' 259' 9/13/2012 20-40 Polar Proppant Beluga H 6050 6,309' 5,183' 5,194' 259' 9/13/2012 20-40 Polar Proppant Beluga H 6347 6,361' 5,480' 5,494' 14' 9/12/2012 20-40 Polar Resin-Coated Proppant Beluga H 6563 7108 6,229' 6,241' 545' 9/7/2012 20-40 Ceramic Proppant Beluga H 6563 7108 5,819' 5,833' 545' 9/7/2012 20-40 Ceramic Proppant Beluga H 6563 7108 5,696' 5,704' 545' 9/7/2012 20-40 Ceramic Proppant - 00 DLB STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2‘2 0CD°) 2-Cc:A,02 WELL LOG TRANSMITTAL DATA LOGGED 4/11/2015 ;I.K.BENDER To: Alaska Oil and Gas Conservation Comm. July 16, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 AUG 3 2 RE: Leak Detect Log (LDL): BRU 244-23 Run Date: 6/20/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU 244-23 Digital Field Log Image file, LAS files, Processed Log Image Files 1 CD Rom 50-283-20165-00 p'^a� }S PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Mobile: 907-350-8453 FRS_ANC@halliburton.com Date: Signed: /2L4t ZdZ,, , 6..emxert Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Jg::2 - 0 k)(/ Well History File Identifier Organizing(done) Vfwo-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: olor Items: ❑ Maps: ip/ rayscale Items: ig'rogs: ❑ Poor Quality Originals: E Other: ❑ Other: BY: Maria Date: //r ..j/5' /s/ 4 Project Proofing rri° BY: aft Date: / • /s/ Scanning Preparation I-f- x 30 = 1 O + i 3 =TOTAL PAGES 6 3 (Count does not include cover sheet) 11/1 BY: Maria Date: (0.//,5-7 /s/ Production Scanning Stage 1 Page Count from Scanned File: 131+ (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES fnNO�J BY: OW Date: (01:: .../ kr ls/ Y V I 1 111 Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: dIP NO TOTAL PAGES: (107 Digital version appended by: Meredith/ 6Michal Date: 6l3 /s/ L Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 1 (03 Scanning is complete at this point unless rescanning is required. 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Lp > 77. Cn CO E 0 p N Y 0 N z ~ c - U 2 ` Q O O U C co w 'U O U 0) ,t c — U a a p ,I E a Ip y o 2 y o 0 a M w 3 z 0 a 0 10 c.� 77<0 I" ry 4,w \\I%%%s,A THE STATE Alaska Oil and Gas 41...a.....1--ir.--4%... -••••• 7,,, ofA T. AsKA Conservation Commission .1,i _ _ s# _�y:_ 333 West Seventh Avenue k. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main' 907.279 1433 �FALAs�� Fax 907.276 7542 www.aogcc alaska.gov Jay Maquire 0 � 7Wells Engineer a,_sp--- ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Beluga River Field, Undefined Gas Pool, BRU 244-23 Sundry Number: 315-304 Dear Ms. Maquire: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this 27 day of May, 2015 Encl. STATE OF ALASKA k (A OIL AND GAS CONSERVATION COMP. ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Ferforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r After Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Mill out plug • 17 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r • Development F7 212-069 • 3.Address. Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-283-20165-00 • 7.If perforating, 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No BRU 244-23 9.Property Designation(Lease Number): 10 Field/Pool(s)• ADL 17658,21127• Beluga River Undefined Gas Pool • _ 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft) Effective Depth TVD(ft). Plugs(measured): Junk(measured). 7553 • 6685 • 7458' - 6591' • 5724' none Casing Length Size MD TVD Burst Collapse Conductor 83' 20" 107' 107' Surface 3404' 9.625" 3427' 2790' RECEIVED Production 7522' 7" 7542' 6675' MAY 1 8 2015 errs s/ 2.-r ( l S AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft)• Tubing Size: Tubing Grade. Tubing MD(ft): from 5182'-7108' 4315'-6241' 3.5 L-80 5071 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft) 8 total packers-see schematic for details SSSV-CAMCO TMAXX-5E MD=498 TVD=498 12.Attachments: Description Summary of Proposal J7 13. Well Class after proposed work: - Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development Fi Service r 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work: 5/28/2015 OIL r VVINJ r WDSPL r' Suspended r 16.Verbal Approval: Date: GAS • r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. Jay Maguire @ 263-4551 Email. Jay.Maquire@conocophillips.com Printed Name lir" Maguire Title: Wells Engineer '/ Signature �Y� Phone:263-4551 Date i��{��5),S" Commission Use Only Sundry Number Conditions of approval: Notify Commission so that a representative may witness 3‘5-30q Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required' /O Li Q tf APPROVED BY Approved by: �4/67r COMMISSIONER THE COMMISSION Date:`srz7—Ls Approved application is v.lis f r 12 months from the date of approval. Submit Form and Form 10-403 Revised 5/2015 K I ' ' A Attachments in Duplicate ii."(:;'114)/ : . \\ MAY 2 8 1015/0.3764— ,�i. 5. :?, /I— SAK PROD BRU 244-23 ConocoPhillips i-'D'hiWell Attributes Max Angle&MD TD Alaska,SIC. Wellbore API/UWI Field Name Wellbore Status incl(°) MD(ftKB) Act Btm(RKB) Crmdn.ngw 502832016500 BELUGA RIVER UNIT PROD 5.824 00 7,553.0 .-- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-BRU 244-23.3/5/201593429 AM SSSV:TRDP Last WO: 5/29/2014 17.00 8/15/2012 Vemcal schema.(actual, Annotation Depth(ftKB) End Date Annotation Last Mod By End Date . RANGER.t•"•t c ` Last Tag:RKB 7,280.0 1272013 Rev Reason:ADD PLUG haggea 3/5/2014 V - -Casing Strings • Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth)ND)... Wt/Len(I...Grade Top Thread -,A-,aolduoTOR;Ad-li7:0-I a ( CONDUCTOR 20 18.730 24.0 107.0 107.0 165.00 H-40 WELDED SAFETY VLV;493.4 a Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Mt/Len(1...Grade Top Thread a SURFACE 95/8 8.835 23.1 3,427.0 2,789.8 40.00 L-80 BTC-M INNIN- VALVE;3,333.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread i PRODUCTION 7 6.276 20.3 7,541.9 6,674.5 26.00 L-80 BTCM SURFACE;23.1-3,427.0- Tubing Strings Tubing Description (String Ma...)10(in) ITop)ftKB) !Set Depth(ft..1 Set Depth(ND))...IWt(Ib/ft) !Grade 'Top Connection TUBING WO 3 1/21 2.992 17.7 5,070.8 4,203.7 9.30 L-80 EUE Completion Details Nominal ID Top(ftKB) Top)ND)(ftKB) Top not(°) (tem Des Com (in) 17.7 17.7 0.00 HANGER VETCO GRAY TUBING HANGER 3.900 21.9 21.9 0.01 XO Reducing XO 4 1/2"IBT(B)x 3 1/2"EUE 8rd(p) 3.000 498.4 498.4 0.32 SAFETY VLV CAMCO TMAXX-5E SSSV 2.813"-X profile 2.813 3,333.3 2,723.7 44.76 VALVE CAMCO KBMG-LTS w/CM-40R Chem valve#1000 psi 2.920 illBK-5 latch GAS LIFT;4,974.3 _ 5,025.1 4,158.1 0.83 NIPPLE HESXNIPPLEw/2.813" 2.813 5,059.0 4,191.9 0.89 LOCATOR LOCATOR Pop Loc-Located.74 off fully located 2.910 NIPPLE;5,025.1 5,060.7 4,193.6 0.89 SEAL ASSY UNIT SEAL 2.920 ;5 PACKER; 5,068.7 4,201.6 0.91 MULE SHOE MULESHOE INDEXING 4w/s ringuard 2.912 X0 CKER;5,059.1 " P 9 9 SEAL ASSY;5,053.1 ■�r. Tubing Description I String Ma. ID(in) !Top(ftKB) Set Depth(ft..1Set Depth(ND)(...Wt(Ib/ft) (Grade Top Connection LOCATOR;5.060.7 CONNECT;5,065.7 GRAVEL PACK"E" 4 3.428 5,048.1 5,20081 4,333.7 11.60 P-110 SLHT R2 CONNECT;5,065.1 a ef Interval SEAL ASSY;5.067.7•` MULE SHOE;5,063.7 p Com letion Details LOCATOR;5,071.7 -1 1ftKBoTop Ind)') Item Des Corn Nominal ID Top( SLEEVE;5,086.31 ) Top_ ?ND( )(ftKB) I (in) VALVE;5,092.4 5,048.1 4,181.1 0.86 PACKER PACKER,7"x 4"26-32#NI w/5.125"8SA Pn 10Ksi Std 4.000 SLEEVE-O;5.174.2 5,052.5 4,185.5 0.87 COUPLING Coupling,Comb.5.125"-8SA Bxx 4.812"-8SA Be VI 4.485 0.58'Lg.13.5Ksi Std IPERF;5,182.0.6191.0 FRAC;5,182.0 ".. 1 5,053.1 4,186.1 0.88 SEAL ASSY EXTENSION SEAL HOUSE 5"18.0#12 ft.Lg.w/4.812" 4.195 LOCATOR;5,196A PACKER;5,194.7 ,10'•I 5,065.1 4,198.0 0.90 CONNECT UNION,QUICK 7027 VIwBUf/MSTw/4.812"-8SA Bxx 3.125 3.906"-8SA Pn 13.5Ksi Std SLEEVE:5.201.0 ,Mt 5,067.0 4,199.9 0.91 COUPLING Coupling,Tubing 3.906"-8SA Bx x Bx VI 0.67'Lg. 3.456 VALVE;5,207.1 P 9• 4M 11.5Ksi Std SCREEN;5,497.5 5,067.7 4,200.6 0.91 SEAL ASSY EXTENSION,SEAL HOUSE 4"11.6#4 ft.Lg.w/3.906"- 3.403 Tubing Pup;5,513.0 8SA Pn x 3.906"-8SA Pn 11 Ksi Std IPERF;5.520.05,527.0 SLEEVE-0;5,516.1 _ 5,071.7 4,204.6 0.92 LOCATOR LOCATOR,Auto 7027 NI t/MST w/3.906"-8SA Bxx 2.810 IPERF;5,539.05,548.0 5.000"-8SA Pn 12Ksi Std Tubing Pup;5,546.21 - SCREEN;5,549.2 5,086.3 4,219.2 0.95 SLEEVE SLEEVE,MS CIs 7"x 2.75"BDNI&NI f/MST w/3.906" 2.750 Tubing Pup;5,530.0 FRAC;5,520.0 - 8SA Bx x 3.906"-8SA Pn 12Ksi Std SCREEN;5.583.0 5,092.4 4,225.4 0.96 VALVE INDICATOR,CIRC.VALVE 7027 7.01'NI w/BU w/3.906" 2.893 Tubing Pup;5,614.1,1 s IPERF;5.609.0.5.631.0 1 � 8SA Bx x 3.906"ESA Pn 11.5Ksi Std SCREEN;5,617.1 5,102.5 4,235.4 0.96 XO Enlarging Sub,XO 3.906"-8SA Bo x4"11.6#SLHT Pn-0.41'Lg. 3.413 Tubing Pup;5.648.1 12Ksi Std SLEEVE-O;5,651.1 IPERF;5,662.0.5,677.0 •( I" 5,168.9 4,301.8 0.89 XO Reducing Adapter,SCS Terminator 4"w/4"11.6#SLHT Bx x 4.000" 2.937 i_ -8SA Pn 11Ksi DE-CRIPPLER;5,681.4 5,174.2 4,307.1 0.89 SLEEVE-0 Screen,Bottom Proweld ST 4"12-Ga 316L,10.98 P-110 2.830 LOCATOR;5,689.31 PACKER;5,689.0 w/MSV"0"Position 2-29.3'OAL w/4"8SA box x 4" SEAL;5,690.5lipe 10.98 SLHT Pin SEAL ASSY;5,694.0 lip, Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..� Set Depth(ND) bnt) Grade Top Connection VALVE;5.667.5 GRAVEL PACK FIG 4 3.428 5,185.7 5,700.8 (...Wt O 4,833.71 11.60 P-110 (SLHT R2 MULE SHOE;5,898.7 I/.' Interval OVERSHOT;5703.8 •fig PACKER;5,710.7 a Completion Details Nominal ID PLUG;5,724.0 NM Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) NIPPLE;5.731.9 L 5,185.7 4,318.6 0.90 XO Reducing Sub,XO 4"11.6#SLHT Bxx 3.906"-8SA Pn-0.67'Lg. 3.385 12.5Ksi Std FRAC PORT;5,776.7 FRAC;5,927.0 5,186.4 4,319.3 0.90 LOCATOR LOCATOR,Auto 7027 NI f/MST w/3.906"-8SA Bxx 2.810 IPERF;5,827.0-5.833.0 I-. a # 5.000"-8SA Pn 12Ksi Std SCREEN;5,858.1 5,194.7 4,327.6 0.91 PACKER PACKER,ISOLATION 702726.0#VI f/MST w/4.125"8SA 2.816 AIM Bx x 3.906"8SA Pn 10Ksi Std ma PACKER;5,873.2 MEM 5,201.0 4,333.9 0.91 SLEEVE SLEEVE,MS CIs 7"x 2.75"BDNI 8 NI f/MST w/3.906" 2.750 8SA Bxx 3.906"-8SA Pn 12Ksi Std FRAC PORT;6030.0, T ii FRAC;5050.0 5207.1 4,340.1- 0.92 VALVE INDICATOR CIRC.VALVE 7027 7.01'NI w/BU w/3.906" 2.893 IPERF;6.050.0-6061.0 Ir ! • 8SA Bx x 3.906"6SA Pn 11.5Ksi Std IPERF;6,217.0-6,233.0.. ! 5217.2 4,350.2 0.93 XO Increasing Sub,XO 3.906"-8SA Bx x 4"11.6#SLHT Pn-0.41'Lg. 3.413 FRAC;6,217.0 F I 12Ksi Std FRAC;6,262.0 5,497.5 4,630.4 0.87 SCREEN SCREEN,TopDynaFlo DB 4"12-Ga 316L,10.98 P-110- 2.937 IPERF;6,2 ,262.0 Y SCREEN;6.293.2- at 15.3'OAL w/4"10.9#SLHT Box x 4"8SA Pin FRAC;6,307.0 111 5,516.1 4,648.9 0.89 SLEEVE-0 SCREEN,Middle Proweld ST 4"12-Ga 316L,10.9#P- 2.830 IPERF;6.307.0.6,309.0-til a 110 w/MSV"0"Position 4-29.8'OAL w/4"8SA Box x 4" i PACKER;6,3263 -- -- BSA Pin d FRAC PORT;6332.8, a= 5,549.2 4,682.1 0.91 SCREEN SCREEN,Middle Proweld ST 4"12-Ga 316L,10.90 P- 2.937 IPERF;6,347.05,361.0 110-30.8'OAL w/4"8SA Box x 4"8SA Pin FRAC;6,347.0" I' 8 far 5,583.0 4,715.9 0.92 SCREEN SCREEN,Middle Proweld ST 4"12-Ga 316L,10.90 P- 2.937 SCREEN;8,436.2 : 110-30.8'OAL w/4"8SA Box x 4"8SA Pin 8.8 an 5,617.1 4,750.0 0.94 SCREEN SCREEN,Middle Proweld ST 4"12-Ga 316L,10.9#P- 2.937 PACKER;6,516.2 110-30.8'OAL w/4"8SA Box x 4"8SA Pin FRAC PORT;6537.9, 4t IPERF;6563.0.6,571.0 t 5,651.1 4,784.0 0.95 SLEEVE-0 SCREEN,Bottom Proweld ST 4.12-Ga 316L,10.98 P- 2.830 FRAC;6,563.0E--I- a e 110 w/MSV"0"Position 4-29.3'OAL w/4"8SA Box x 4" SCREEN;6.581.9 Ali 10.99 SLHT Pin PACKER;6,598.2 = 5,680.8 4,813.7 0.96 XO Reducing Sub,XO 4"11.6#SLHT Bxx 3.906"-8SA Pn-0.67'Lg. 3.385 SOS;6,704.0 12.5K51 Std IPERF;3,836.0-8,700.0 ra FRAC;6,686.0 5,681.4 4,814.3 0.96 DE- DE-CRIPPLER ROCKER STYLE 7027 VI w/BU w/3.906" 2.775 IPERF;2096.0-T108.0- CRIPPLER -8SA Bxx 3-1/2"9.3#BTS-8 Pn 11.5Ksi Std FRAC;7696. 8 ( , PRODUCTION;2037,541.9 t SAK PROD BRU 244-23 ConocoPhillips Alaska,Inc. Co.a.AuiliI$ DEVIATED-BRU 244-23.3/52015 9'.34.30 AM Vertmal schematic(actual) HANGER;t77r-•r o r Completion Details Nominal ID -M,CONDUCTOR;24.0.107,0'I Top(MB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) SAFETY VLv;498.4 5,688.8 4,821.7 0.96 LOCATOR LOCATOR,Pop Loc 7"&7-5/8"x 4"VI w/BU w/3-1/2" 2.910 OMR9.3#BTS-8 Bx 10Ksi Std VALVE;9333.3 -- 5,690.5 4,823.3 0.96 SEAL UNIT SEAL 4"x 1'-BD/NI w/3.437"-SSA Bx x Pn 10Ksi 2.920 Std SURFACE;23.1-3.427.0- ' 5,697.5 4,830.3 0.97 VALVE VALVE,Disappearing Check 7027 NI w/Glass Disk f/MST 2.915 w/3.437"8SA Bx x 3.437"8SA Pn Std 5,698.7 4,831.6 0.97 MULE SHOE 'MULESHOE,Indexing 4"w/Spring Guard w/3.437"-8SA 2.912 Bx Std Tubing Description String Ma...ID(in) Top(ftKB) Bet Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection GRAVEL PACK- 312 2.992 5,665.0 6,625.0 5,757.7 9.30 L-80 IBT Original Completion Details Nominal ID Top(ftKB) Top(WD)(ftKB) Top Incl(°) Item Des Corn (in) 5,665.0 4,797.8 0.95 SLEEVE HR LINER SETTING SLEEVE 5.250 GAS LIFT;4,974.8 - 5,6772 4,810.0 0.96 NIPPLE RS NIPPLE 4260 5,680.1 4,813.0 0.96 SBE 80-40 SEAL BORE 4250 NIPPLE;5.025.1 5,699.5 4,832.3 0.97 XO Reducing CROSSOVER 5"x 4.5" 4.500 PACKER;5,048.11 5,710.7 4,843.6 0.97 PACKER 598-387 PREMIER PACKER 3.870 XO Thread;5.058.51 Il. ® SEAL ASSY;5,053.1 5,718.8 4,851.6 0.98 XO Reducing CROSSOVER 4.5"x 3.5" 3.500 LOCATOR;5,059.0 SEAL ASSY;5,060.7 ' 5,731.9 4,864.7 0.99 NIPPLE X PROFILE NIPPLE 2.813 CONNECT;5,065.1 SEAL ASSY;5,067.7 ' 5,776.7 4,909.5 1.03 FRAC PORT HALLIBURTON FRAC DOOR(CLOSED 10/27/2012) 2.750 MULE SHOE;5,068.7 Opens Down LOCATOR;5,071.7 SLEEVE;5,0863 5,818.7 4,951.6 1.00 BLAST RING CARBIDE BLAST RING(LOWER G PERFS 5827'-5833') 2.992 VALVE;5,092.4 (RINGS 5824'-5838') 5,858.1 4,991.0 0.97 SCREEN SELECTA FLOW SCREEN w/2.75"X PROFILE Opens 2.750 SLEEVE-O;5.174.2 Down IPERF;5,182.0-5191.0 FRAC;5,182.0 .. I. I 5,9732 5,106.0 1.03 PACKER 598-287 PREMIER PACKER ASSEMBLY 2.875 LOCATOR;5,186.4 PACKER;5,194.7 6,030.0 5,162.8 0.96 FRAC PORT HALLIBURTON FRAC DOOR(CLOSED 10/27/2012) 2.750 SLEEVE;5.281.0 ,II�y 6,0422 5,175.0 0.94 BLAST RING CARBIDE BLAST RINGS(UPPER H PERF 6050'-6061') 2.992 VALVE;5,207.1 (RINGS 6047-6066') 6,210.8 5,343.6 0.83 BLAST RING CARBIDE BLAST RING(UPPER H PERFS 6217'-6233') 2.992 SCREEN;5.497.5 (RINGS 6215'-6238') Tubing Pup;5,513.0 IPERF;5,520.0-5,527.0 6,255.5 5,388.3 0.92 BLAST RING CARBIDE BLAST RINGS(UPPER H PERFS 6262'-6270) 2.992 SLEEVE-O;5,516.1 (RINGS 6260'-6275) IPERF;5,538.05,5480 Tubing Pup;5,546.21 '� 6,293.3 5,426.0 1.04 SCREEN SELECTA FLOW SCREEN w/2.75"X PROFILE Opens 2.750 SCREEN;5,549.2 Down Tubing Pup;5,580.0 FRAC;5,520.0 It= 6,299.9 5,432.7 1.04 BLAST RING CARBIDE BLAST RING(MID H PERF 6307-6309) 2.992 SCREEN;5.583.0Lamm (RINGS 6305'-6310) Tubing Pup 5,614.1 !:_ IPERF;5.6090-5.631.01 s 6,320.3 5,453.1 1.05 PACKER 698-287 PREMIER PACKER ASSEMBLY 2.875 SCREEN;5,617.1 Tubing Pup;5.648.1 6,332.8 5,465.6 1.05 FRAC PORT HALLIBURTON FRAC DOOR(CLOSED 10/27/2012) 2.750 SLEEVE-O;5,651.1 Opens Down IPERF;5.662.0-5,677.06,338.5 5,471.3 1.05 BLAST RING CARBIDE BLAST RINGS(MID H PERFS 6347'-6361) 2.992 11 1 RINGS 6344'-6366') DE-CRIPPLER;5,681.4 LOCATOR;5,688.81 ?r_ 6,4362 5,569.0 1.03 SCREEN SELECTA FLOW SCREEN wl 2.75"X PROFILE Opens 2.750 PACKER;5,689.0 - Down SEAL;5690.5 SEAL ASSY;5,6940 II'. 6,516.2 5,648.9 1.02 PACKER 598-287 PREMIER PACKER ASSEMBLY#2 2.875 VALVE;5,697.51 LE MULE SHOE;5,6987 6,537.9 5,670.6 0.96 FRAC PORT HALLIBURTON FRAC DOOR(CLOSED 10/27/2012) 2.750 Opens Down OVERSHOT;9703.8 Mimi 6,550.0 5,682.7 0.95 BLAST RING CARBIDE BLAST RING(LOWER H PERFS 6563'-6571' 2.992 PACKER;5710.7 �. ) PLUG;5.724.0 to (RINGS 3558-6576') NIPPLE;5,731.9 7.g: 6,581.9 5,714.6 0.93 SCREEN SELECTA FLOW SCREEN w/275"X PROFILE Opens 2.750 am= Down FRAC PORT;5,776.7 1 6,598.2 5,731.0 0.92 PACKER 598-287 PREMIER PACKER ASSEMBLY#1 2.875 FRAC;5827.0 ant IPERF;5,827.95,833.0 7 6,624.1 5,756.8 0.94 SOS BALL SEAT SHEAR SUB FOR 1"OD BALL,5000 PSI+/- 3.000 SCREEN;5,858.1 SHEAR REQUIRED la Tubing Description String Ma...110 11"1 .101161 Top(ftKB) Set Depth(ft.{Set Depth(WD)(. WI(Ib/ft) 'Grade Top Connection PACKER;5,973.2 a SUMP PACKER 5.05 4.195 5,689.0 571001 4842.9 J8SA Completion Details ` FRAC PORT;6,030.0, ‘1‘::.' .- """' �' ' '.° W Nominal IDs FRAC;AC;6.050.0 Top(ftKB) Top(WD)(ftKB) Top Inc!I IPERF;50 051.0-� 1 (°) Item Des Com (In) 5,689.0 4,821.8 0.96 PACKER PACKER,CSHP-II 7"x 4"26-320 NI w/5.125"8SA Pn 4.000 IPERF;6,217.05.233.0 10Ksi Std FRAC;6,217.0 5,694.0 4,8268 0.97 SEAL ASSY Extension, . Seal House 5"180#7ft Lg.w/4.812"-BSA 4.195 FRAC 6,262.0 s . IPERF;6,262.0-6270.0 it Pnx4.812-8SA Pn 11 Ksi Std SCREEN;6,293.2-, 5,700.9 4,833.8 0.97 XO Increasing Sub,XO 4.812'-8SA Bx x 3-1/2"9.3#EU 8rd Pn-0.67" 2.975 FRAC;6,307.0 Lg.NR 11 Ksi Std IPERF;6307.0-9309.0-N 5,703.8 4,836.6 0.97 OVERSHOT Non Sealing OVERSHOT w/5.93'SWALLOW 4.625 PACKER;6,320.3iiwi FRAC PORT;6,332.8, ''Sr Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) IPERF;6.347.0-6.361.0 # Top(WD) Top Incl FRAC;6,347.0 Il I Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) SCREEN;6,4362 5,724.0 4,856.9 0.98 PLUG SET 3.50"QUIK DRILL COMPOSITE PLUG 5/25/2014 0.000 omm Imi Perforations&Slots PACKER;6,516.2 -_ Shotns FRAC PORT;6,537.9 o IPERF;6,563.0-6,571.0 Top(WD) Btm(WD) (shots"( FRAC;6.563.0 a Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SCREEN;6,581.9 5,182.0 5,191.0 4,314.9 4,323.9 BELUGA E, 6/8/2014 21.0 IPERF Schlumberger 5"HSD PACKER;6,598.2-, ® BRU 244-23 21 SPF 4621 PF SOS;6,624.1 IPERF;6,686.0.8,700.01 5,520.0 5,527.0 4,652.9 4,659.9 BELUGA F, 6/8/2014 21.0 IPERF Schlumberger 5"HSD FRAC;6,686.01 BRU 244-23 21 SPF 4621 PF IPERF;7,096.0-7,108,0�Y I I 1 FRAC;7,096.0 PRODUCTION;2037,541.9 I I SAK PROD BRU 244-23 COnOCOPIiIIIp5 Alaska,Inc. 1'ren eni.hiilips DEVIATED-BRU 244-23,3/5/20159.34:31 AM Vertical schematic(actual) HANGER,17.7- 'erforations&Slots Shot -A-Ai CONDUCTOR;24.0-107.0 'I Dens SAFETY VO/.498.4 'r Top(TVD) Btm(ND) (shots/f Ia Top(ftKB) Btm(RKB) (RKB) VDU)) Zone Date t) Type Com _ 5,538.0 5,548.0 4,670.9 4,680.9 BELUGA F, 6/8/2014 21.0 IPERF Schlumberger 5"HSD VALVE;3,333.3 BRU 244-23 21 SPF 4621 PF SURFACE;23.1-3,427.0 5,609.0 5,631.0 4,741.9 4,763.9 BELUGA F, 6/8/2014 21.0 IPERF Schlumberger 5"HSD BRU 244-23 21 SPF 4621 PF 5,662.0 5,677.0 4,794.9 4,809.9 BELUGA G, 6/8/2014 21.0 IPERF Schlumberger 5"HSD BRU 244-23 21 SPF 4621 PF 5,827.0 5,833.0 4,959.8 4,965.8 BELUGA G, 8/9/2012 6.0 IPERF 4 5/8-5 SPF Millenium BRU 244-23 39 gram • • • 6,050.0 6,061.0 5,182.8 5,193.8 BELUGA H, 8/9/2012 6.0 IPERF 45/8-5 SPF Millenium • BRU 244-23 39 gram • • 6,217.0 6,233.0 5,349.8 5,365.8 BELUGA H, 8/9/2012 6.0 IPERF 4 5/8-5 SPF Millenium • BRU 244-23 39 gram U 6,262.0 6,270.0 5,394.8 5,402.8 BELUGA H, 8/9/2012 6.0 IPERF 4 5/8-5 SPF Millenium GAS LIFT;4,974.8 BRU 244-23 39 gram a' 6,307.0 6,309.0 5,439.8 5,441.8 BELUGA H, 8/9/2012 6.0 IPERF 45/8-5 SPF Millenium BRU 244-23 39 gram NIPPLE;5,025.1 6,347.0 6,361.0 5,479.8 5,493.8 BELUGA H, 8/9/2012 6.0 IPERF 45/8-5 SPF Millenium PACKER;5,048.1 BRU 244-23 39 gram XO Thread;5,058.5 SEAL ASSY;5.053.1t.1.111.1! 6,563.0 6,571.0 5,695.7 5,703.7 BELUGA H, 8/9/2012 6.0 (PERF 45/8-5SPF Millenium LOCATOR;5,169.0 SEAL ASSY;5,060.7 BRU 244-23 39 gram CONNECT;5,087.1 - MEAL SHOASSY;5,068.7 g 6,686.0 6,700.0 5,818.7 5,832.7 BELUGA I, 9/3/2012 "1 IPERF 45/8-5 SPF Millenium MULE SHOE;5.068.7 � BRU 244-23 39 gram LOCATOR;5,071.7 Ii 7,096.0 7,108.0 6,228.7 6,240.7 BELUGA I, 9/1/2012 "4 IPERF 4 5/8-5 SPF Millenium SLEEVE;8.006.31 -"'_l• BRU 244-23 39 gram VALVE;5,092.4 Stimulations&Treatments SLEEVE-0;5,174.2 Min Top Max Btm FRAC; (PERF;5.1 AC;5.782.0 • 5,181Depth Depth Top(ND) Btm(ND) LOCATOR;5,186.1 ' (106) (RKB) (RKB) (RKB) Type Date Com PACKER;5.t%.7 iMP d 6,563.0 7,108.0 5,695.7 5,703.7 FRAC 9/7/2012 20-40 Ceramic Proppant 6,563.0 7,108.0 5,818.7 5,832.7 FRAC 9/7/2012 20-40 Ceramic Proppant SLEEVE;5,201.0` 6,563.0 7,108.0 6,228.7 6,240.7 FRAC 9/7/2012 20-40 Ceramic Proppant VALVE;5.207.1 1�� PP 6,347.0 6,361.0 5,479.8 5,493.8 FRAC 9/12/2012 20-40 Polar Prop Resin-Coated Proppant SCREEN;5,497.5 6,050.0 6,309.0 5,182.8 5,193.8 FRAC 9/13/2012 20-40 ZG Polar Proppant Tubing Pup:5.513.0 6,050.0 6,309.0 5,349.8 5,395.8 FRAC 9/13/2012 20-40 ZG Polar Proppant IPERF;5,520.0-5,527.0 SLEEVE-O;5.516.1 6,050.0 6,309.0 5,394.8 5,402.8 FRAC 9/13/2012 20-40 ZG Polar Proppant IPERS Pup up;5,5.516546.2.1 2 6,050.0 6,309.0 5,439.8 5,441.8 FRAC 9/13/2012PP 20-40 ZG Polar Proppant TS 5 SCREEN;5,549.2, 5,827.0 5,833.0 4,959.8 4,965.8 FRAC 9/13/2012 20-40 RC Ceramic Proppant Tubing Pup;5,5e0.0 5,520.0 5,677.0 4,652.9 4,809.9 FRAC 6/12/2014 P&G-sand interval,1st stagepump. um FRAC;5,583.0 pumping 3515 lbs SCREEN;5.583.0 of(20,00 CarbolNe),with 6%KCL.Continually Tubing Pup;5,614.1, increasing sand concentration from 0.5-0.75 PPA. IPERF;5.609.0.5631.0, - Rate max 7.5 BPM SCREEN;5,617.1 Tubing Pup;5,648.1 5,182.0 5,191.0 4,314.9 4,323.9 FRAC 6/13/2014 E-sand interval,2nd stage pump.pumping 5764 lbs of SLEEVE-O;5,651.1 (20-40 carbolate),with 6%KCL.Continually increasing IPERF;5.6620-5,677.0 Lir sand concentration. I Mandrel Inserts DE-CRIPPLER;5,681.4 at LOCATOR;5,688.8 ati PACKER;5,689.0 on Top(1VD) Valve Latch Port Size TRO Run SEAL:5,690.5 • N Top(ROB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com SEAL 0501,5594.0 6../ a '( 4,974.8 4,107.7 CAMCO MMG 1 GAS LIFT OV RKP 0.500 0.0 6/19/2014 SHEA VALVE;5,697.5 MULE SHOE;5,698.7 R OVERSHOT;5703.8 :s1 Notes:General&Safety PACKER;5,710.7 End Date Annotation PLUG:5.724.0 529/2014 NOTE:WORKOVER NIPPLE;5,731.9 4.s FRAC PORT;5,770.7 �� FRAC;5,827.0 IPERF;5527.0.5.833.0-gaI WSCREEN;5,858.1 a PACKER;5,973.2 a FRAC PORT;6,030.0-- 14s FRAC;6,050.0 *T IPERF;6,050.06061.0-I a a Ian IPERF;6,217.04233.0 f FRAC;6,217.0 FRAC;6,262.0 IPERF;6,262.0-6,270.0 SCREEN;6,293.2` FRAC;6,307.0 IPERF;6.307.0-6.309.0-g 0 II PACKER;6,320.3 �' FRAC PORT;6.332.8, gm, IPERF;6,347.0-6,361.0 FRAC;6,347.0 • SCREEN;6,436.2 a. smos PACKER;6.516.2 FRAC PORT;6,537.9 , , IPERF;5563.06,571.0 s FRAC;6,563.0 a SCREEN;6,581.9 ill. PACKER;6.598.2-, SOS;8,624.1 IPERF;6,686.0-6,700.0 FRAC;6,686.0 IPERF;7,096.0.7,108.0 I FRAC;7,096.0 PRODUCTION;203-7,541.9 , The objective of this procedure is to utilize coiled tubing to mill out a Baker 3.5" millable composite bridge plug in the 3.5" tubing at 5725.0'MD,the middle of a 5.83' pup located below the 4.5"x3.5" crossover at 5720.6'MD (4855'TVD). Milling the plug will give us production from Beluga G,H and I sands after working the well over in 2014. Slickline 1. Mobilize Pollard slick line unit to job site,conducting PJSM with personnel. 2. RIH and shift sleeves closed at 4974', 5086', 5201', 5516'and 5651'. Coiled Tubing P 3. Mobilize coiled tubing unit with N2 unit to job site. r,�T s.71 p- 4. Conduct PJSMs with all personnel involved. MIRU CTU and N2 unit. 5. PUH to pick-up weight and line-up to pump down the CT. 6. Start motor and increase to optimum pump rate as per tool hand guidelines and motor specs. 7. Slowly RIH until pump pressure increase is noted; stay within the operational differential pressure rating for the motor. Do not exceed maximum set down weight allowed for the motor. 8. The plug will equalize before milling of top slips is complete. As soon as plug equalizes, pull . up to 5705'MD until returns resume in order avoiding sticking pipe or BHA. 9. RDMO coiled tubing. Slickline 10. RIH and shift sleeves open at 4974', 5086', 5201', 5516' and 5651'. • , STATE OF ALASKA i ALAS )IL AND GAS CONSERVATION COMM!: 1N REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate rOther p Gravel Pack Alter Casing r Pull Tubing rJ Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: ' 4.Well Class Before Work: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. Development r Exploratory r 212-069 3 Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-283-20165-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 17658,21127 BRU 244-23 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Beluga River Undefined Gas Pool 11.Present Well Condition Summary: Total Depth measured 7553 feet Plugs(measured) 5724' true vertical 6685 feet Junk(measured) none Effective Depth measured 7458 feet Packer(measured) 8 total packers true vertical 6591 feet (true vertical) Casing Length Size MD ND Burst Collapse Conductor 83' 20" 107' 107' Surface 3404' 9.625" 3427' 2790' Production 7522' 7" 7542' 6675' REC Perforation depth: Measured depth: from 5182'-7108' IEMED True Vertical Depth: 4315'-6241' 6 j 0 14 AOGCC Tubing(size,grade,MD,and ND) 4.5 x 3.5, L-80, 6626 MD, 5759 ND Packers&SSSV(type,MD,and ND) 8 total packers from 5051'to 6600'MD,4184'-5733'ND SSSV-Camco TRMAXX-5E @ 498'MD and 498'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2200 Subsequent to operation 8100 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development rg Service r Stratigraphic r 16.Well Status after work: Oil r Gas rr WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt 314-259 Contact Drew Huck 0 265-6828 Email Andrew.Huck0conocophillips.com Printed Name Drew Huck Title Sr. Drilling Engineer Signature c49-.....-- /214 /J Phone:265-6828 Da telly'/I ii RBDMS JUL 16 201A. ?e_--7-46- /`I Form 10-404 Revised 10/2012r, /,/. Submit Original Only 4 *Red and green are BRU 244-23 Huck 7-15-2014 new equipment Production Well Actual Schematic = __ Conductor: 4 i ; i 20" 165#H-40 @ 107'MD ® Camco TRMAXX-5E Safety Valve w/DB Profile @ 498'MD w/'/4"control line - /i Surface Casing: 5 9-5/8",40#,L-80,BTCM r. j Set @ 3,427'MD/2,790'TVD Top of"Good"Cement above 4,000'MD ACE 8/8/12 i i i r Camco KBMG-LTS CIM @ 3,333'MD w/318" T :: encapsulated injection line Camco MMG GLM @ 4,975'MD Production Tubing: HES X Nipple with 2.813"profile @ 5,025'MD p O 3-W,9.3#,L-80,EUEM-8rd @ 5,060'MD _ --._.-::.: Superior CSHP-II Packer @ 5,051'MD 1.1_._.'i Superior MS CIs Sleeve @ 5,089'MD 4iiiiiiill iiiiiii , Beluga E Perforations i l." ill. 0.i1111 Superior Screen @ 5,172-5,199'MD 5,182'-5,191' i i!i,, `:0' 11 ' MSV Position 2 @ 5,186' " i Superior 7027 Isolation Packer @ 5,210'MD i Superior MS Cls Sleeve @ 5,216'MD .:.• 'V M`•`ii fa i!i " MSV Position 4 5,540' Beluga F Perforations MIN •rJd��o 5,520'-5,527',5,538'-5,548',5,609'-5,631' Superior Screen @ 5,513-5,681'MD Beluga G Perforations ""`"'= -c. 1011111110.--",o- MSV Position 4 @ 5,668' 5,662'-5,677' iX " ' Superior CSHP-II Sump Packer @ 5,689 MD 5= ,; a; Baker Poor Boy Overshot @ 5,710'MD over cut 10'pup joint Composite Bridge Plug @-5,727'MP t .. ■' Premier Packer @ 5,713'MD G Sand Peforations , = Halliburton Frac Door @5,779'MD C @ 5,827'-5,833'MD(5 spf) 11 7 Carbide Blast Rings @ 5,824'-5,833' Frac'd w/140 K lbs 20/40 RCC [ ;+? Baker Selecta Flow Screen,2.75"X-Profile,Opens Down @5,860'MD �,. •; Premier Packer @ 5,975'MD H Sand Peforations Halliburton Frac Door @6,032'MD @ 6,050'-6,061',6,217'-6,233'(5 spf) Carbide Blast Rings @ 6,047'-6,066',6,215'-6,238',6,260'-6,275'MD 6,262'-6,270',6,307-6,309'MD C r' Baker Selecta Flow Screen,2.75"X-Profile,Opens Down @6,295'MD Premier Packer @ 6,322'MD,BR 6,305'-6,310'MD H Sand Peforations i------- Halliburton Frac Door @6,335'MD @ 6,347'-6,361'MD(5 spf) Carbide Blast Rings @ 6,344'-6,366'MD Frac'd w/55 K lbs 20/40 RCC [_. i Baker Selecta Flow Screen,2.75"X-Profile,Opens Down @6,438'MD • ■i Premier Packer @ 6,518'MD H Sand Peforations r I 5 ©6,563'-6,571' MD(5 spf) [- Halliburton Frac Door @6,540'MD Frac'd w/68 K lbs 20/40 RCC F:-• i Carbide Blast Rings @ 6,558'-6,576'MD Baker Selecta Flow Screen,2.75"X-Profile,Opens Down @6,584'MD I Sand Peforations Ii Premier Packer @ 6,600'MD @ 6,686',6,700'MD(6 spf) i Frac'd w/92 K lbs 20/40 RCC C, Tubing tail and SOS @ 6,626'MD I Sand Peforations @ 7,030'-7,042'MD(5 spf) 7,096'-7,108'MD(6 spf) Aill IP' 111110`- Frac'd Frac'd w/90 K lbs 20/40 RCC Production Casing: i 7",26.00#,L-80,BTC-Mod Set©7,542'MD/6,675'TVD 1 / ConocoPhillips Time Log & Summary We/fvfew Web Reporting Report Well Name: BRU 244-23 Rig Name: DOYON ARCTIC FOX Job Type: RECOMPLETION Rig Accept: 5/29/2014 12:00:00 AM Rig Release: 6/16/2014 12:00:00 PM Time Logs. Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 35/29/2014 24 hr Summary Accept Doyon Arctic Fox©00:01 hrs on 5-29-14. RU and Test BPV in direction of flow to 1,000 psi. ND Tree and NU BOPE 00:00 12:00 12.00 MIRU MOVE RURD P Continue to fill upright tanks with fresh water from water well. Clean and inspect BOPE bolts, Prep for N/D Tree and N/U BOPE. Clean and Organize Rig (Scrub), Function all valves on rig floor, mud pits and pump room. RU washing machine pump to slop tank. Clean and inspect all hydraulic lines in skate. Offload Barge-7 frac tanks, 2 storage tanks for injection skid, 2 trailers of mud product, 3 landing jts, MI WB tools. Conduct walk thru with Mike Kneal (CPAI)and commission Doyon Arctic Fox-All was accepted 12:00 14:00 2.00 MIRU WHDBO PRTS P Locate hard iron and RU to IA valve. PT pump lines, and PT Type'H' BPV in direction of flow at 1,000 psi for 10 minutes-Good test 14:00 18:00 4.00 MIRU WHDBO NUND P ND Vetco Gray 11"5M tree and Install Test plug w/(15-1/2 RH turns and 10 LH turns to release off) 18:00 00:00 6.00 MIRU WHDBO NUND P NU 11"5M Shaffer Class III BOP Stack with Doyon crew. Load rig pits with 100 bbl's of fresh water. Cycle thru pit system and all three pumps. 05/30/2014 Continue to NU BOPE and conduct Initial BOP test @ 250/3,500 psi with 3-1/2 and 4-1/2 Test joints. 24 hr notice was given on 5-26-14 @ 11:30 hrs. Test was witnessed by Lou Grimaldi. 00:00 04:00 4.00 MIRU WHDBO NUND P Continue to NU 11"5M Shaffer Class III BOP Stack with Doyon crew. Continue to set Rain for Rent tanks 04:00 10:15 6.25 MIRU WHDBO NUND P Continue to RU to Test BOPE Page 1 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 19:30 9.25 MIRU WHDBO BOPE P Conduct Initial BOP test with 3-1/2 and 4-1/2 Test joints at 250/3,500 psi. Tests were witnessed by Lou Grimaldi. Test w/3-1/2 Test Joint #1 -Annular, HCR Choke, HCR Kill #2-UPR's, CM Valves 5,9,14 and TIW valve. #3-CM Valves 1,4,8 and Dart Valve. #4-CM Valves 3,7,13 and Lower IBOP(F/P-serviced CM Valves) #5-CM Valves 2,6,12 and Upper I BOP #6-CM Valve 11, Manual Kill, Manual Choke, and Kill Line valve 18 and LPR's. Koomey Test. Change out test joints from 3-1/2 to 4-1/2 and test UPR's and LPR's as per Alaska State Req. 19:30 21:00 1.50 MIRU WHDBO RURD P RD BOPE test equipment. Blow down lines and CM. 21:00 00:00 3.00 MIRU RPCOM OTHR P Empty pits of fresh water used for state function testing. Continue to clean pits and load pipe shed with 200 joints of 3-1/2 12.95#, P-110, WTS-6 Tubing 35/31/2014 Prepare 100 bbl caustic wash,flush thru pits twice, removed large amount of residual. Neutralize to a ph of 7, and offload pits. Held Pre spud w/crews on location and conduct work site hazard hunt. Review findings. 00:00 02:00 2.00 MIRU RPCOM OTHR P Continue to clean pits and load pipe shed with 200 joints of 3-1/2 12.95#, P-110,WTS-6 Tubing 02:00 12:00 10.00 MIRU RPCOM OTHR P PJSM, Prepare to wash pits with 3 Ib/bbl Caustic wash. Load pit with 100 bbl's of Fresh water and mix in 6 sxs of Caustic, 1 Drum of Safe Surf W along with 1 can of DefoamX. Wash all of the pit and circulating system with caustic wash x 2. Neutralization all fluid in mud pits back to PH of 7. 12:00 14:00 2.00 MIRU RPCOM SFTY P Held Pre Spud for the RWO with AM/PM Doyon crews, and misc Contractors on location for the operation. 14:00 16:00 2.00 MIRU RPCOM SFTY P Conducted a Hazard hunt and held a discussion with all vendors at rig site on the findings,observations and mitigations of the results of the _ hazard hunt. 16:00 00:00 8.00 MIRU RPCOM OTHR P Flush lines in preparation of loading the pits with fresh water, continue to mitigate findings in hazard hunt and prep rig floor for POOH. Page 2 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/01/2014 24 hr Summary Continue to offload pits, Reload with 500 bbl's of fresh water. Attempt to pull seals from SBE-no luck. RU Eline and prep for RCT cutter-shoot 11 circ holes @ 4 spf. RU RCT cutter. 00:00 05:45 5.75 COMPZ RPCOM OTHR P PJSM, Continue to off load pits, and bring on 500 bbl's of fresh water. Mobile cross over's and 4-1/2 thread protectors to rig floor. 05:45 06:45 1.00 COMPZ RPCOM RURD P PJSM, Load WFT tongs and equipment to rig floor. RU the same. 06:45 08:00 1.25 COMPZ RPCOM THGR P PJSM, Pull Type H BPV, MU 4-1/2 landing joint w/4.909"MCA Pin into Vetco Gray MB 230 10.875 x 4.5 Tubing hanger as per Vetco Rep. MU cross over subs and screw in top drive. BOLDS, Unland hanger© 135k. 08:00 18:00 10.00 COMPZ RPCOM PULL T Attempt to pull seals from SBE @ 5,681-ft to 5,701-ft. Work Tubing from 175k(65k osw)in 25 k increments to 225k(115k osw). No movement. Pull to 240k(130k osw) x3-no luck. Call out Eline for cut- Clean rig, complete derrick inspection and work on test pump. 18:00 00:00 6.00 COMPZ RPCOM ELNE T Spot and RU eline, RIH w/1-11/16" tubing punch,discuss perf depth with Town engineers and shoot from 5,707-ft to 5,704.5-ft ELM as per CCL correlations. POOH, at 23:00 hrs MU RCT cutter. 06/02/2014 Attempt to pass thru 3-1/2 tbg with 2.992"ID w/2.938"OD RCT cutter assy--No go. correlate and attempt to make cut in middle of 1st full joint of 4-1/2, 12.6#, L-80 R3 TBG @ 5,649-ft with ccl @ 5,645-ft. Seen tool function but no signs of cut pipe on rig floor. Pass thru and show sign of cut on CCL. POOH and lay down cutter. MU to landing joint with top drive. Attempt to pull free-no luck. Break circulation w/40k over pull and increase pump rate to 10 bpm @ 750 psi, returning sand at shaker,seen weight loss on indicator continue to work over pull and seen signs of free pipe movement. Continue to change hole over to fresh water. 229 bbl's pumped and 221 bbl's recovered. POOH w/4-1/2"De completion all components of upper completion recovered. PU and RIH w/BHA#1 3-1/8—MSC assy to 233-ft. PU and RIH w/BHA#1, PU 3-1/2 PH-6 work string to 2,360-ft. 00:00 01:30 1.50 COMPZ RPCOM ELNE T Attempt to pass thru 3-1/2 tbg with 2.992"ID w/2.938"OD RCT cutter assy--No go. correlate and attempt to make cut in middle of 1st full joint of 4-1/2, 12.6#, L-80 R3 TBG @ 5,649-ft with ccl @ 5,645-ft. Seen tool function but no signs of cut pipe on rig floor. Pass thru and show sign of cut on CCL. POOH and lay down cutter. RD Eline sheave. Page 3 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:15 0.75 5,705 5,683 COMPZ RPCOM OTHR T MU to landing joint with top drive. Attempt to pull free-no luck. Break circulation w/40k over pull and increase pump rate to 10 bpm @ 750 psi, returning sand at shaker,seen weight loss on indicator continue to work over pull and seen signs of free pipe movement. Continue to change hole over to fresh water. 229 bbl's pumped and 221 bbl's recovered 02:15 03:00 0.75 5,683 5,683 COMPZ RPCOM OWFF P Monitor well fro flow for 30 minutes. Static. 03:00 18:00 15.00 5,683 0 COMPZ RPCOM PULD P PJSM,Terminate SSSV and Chemical injection control lines at TBG hanger. Remove hanger and begin de completing well. POOH all components of the upper completion 138 jts of 4-1/2 12.6#, L-80; IBT-M R3 Tubing 143-cannon clamps 286-Pins 18:00 18:30 0.50 0 0 COMPZ WELLPF OTHR P Secure well and shut down for lunch. 18:30 20:30 2.00 0 233 COMPZ WELLPF PULD P PJSM, PU, MU and RIH w/3-1/8" Cutter BHA as per Baker Fishing Rep.to 233-ft. 20:30 00:00 3.50 233 2,360 COMPZ WELLPF PUTB P Continue to RIH w/BHA#1 (3-1/8" Mech. Cutter Assy)on 3-1/2", 12.95 lb/ft, P-110, PH-6 Work String from 233-ft to 2,360-ft Up wt-53k, SOW 48k. 36/03/2014 Continue to PU work string and RIH from 2,360-ft to 5,665-ft. Clean out to 5,687-ft and unable to clean out any deeper. POOH for C/O assembly.-MU&RIH w/CO assembly-clean out to 5730'(pipe measruement)- Circ&Pump hi-vis sweep 00:00 04:15 4.25 2,360 5,665 COMPZ WELLPF PUTB P Continue to RIH w/BHA#1 (3-1/8" Mech. Cutter Assy)on 3-1/2", 12.95 lb/ft, P-110, PH-6 Work String from 2,360-ft to 5,665-ft Up wt-110k, SOW 63k. 04:15 05:45 1.50 5,665 5,687 COMPZ WELLPF FCO P Tag up @ 5,665-ft,Attempt to work into Liner Top several times setting down 3k max. no success. Bring pumps on line and circulate @ 3 bpm 375 psi, wash down to 5,687-ft -unable to work past. Make several attempts. Pull above LT to 5640' 05:45 06:15 0.50 5,640 5,640 COMPZ WELLPF OWFF P Monitor well for 30 mins-static 06:15 09:45 3.50 5,640 233 COMPZ WELLPF TRIP T PJSM on POOH-f/5640'to 233'- Calc fill 25.5 bbls-Actual fill 26.2 bbls 09:45 11:00 1.25 233 0 COMPZ WELLPF PULD T PJSM-on LD BHA-LD cutter BHA 11:00 11:15 0.25 0 0 COMPZ WELLPF OTHR T Set wear bushing( 10.5"OD-6.375" ID) 11:15 11:45 0.50 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor Page 4 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:45 12:00 0.25 0 0 COMPZ WELLPF PULD T Prep to PU BHA#2 clean out assembly 12:00 18:00 6.00 0 0 COMPZ WELLPF PULD T PJSM-MU BHA#2-clean out- Wait on OX's to complete MU of asssembly-Conduct hazard hunt- Service rig-Monitor well while waiting on OX subs 18:00 22:30 4.50 0 5,717 COMPZ WELLPF TRIP T PJSM-Finish MU BHA-Install air slips&stripping rubber-RIH w/BHA #2 w/PH6 workstring f/derrick f/278' to 5717'-Made top drive connection on std#87-Wash down f/5687' @ 6 bbls/min @ 1100 psi- PU wt. 98 SO wt 92 Note-Had to change out Weatherford tongs- 1 1/2 hr down time 22:30 23:00 0.50 5,717 5,723 COMPZ WELLPF WASH T Pu single&wash down f/5730'pipe measurement(tagged composite plug)-Pick up to 5723' 23:00 23:30 0.50 5,723 5,723 COMPZ WELLPF CIRC T Circ btms up @ 326 gpm @ 1150 psi -Observed very little sand @ shakers 23:30 00:00 0.50 5,723 5,723 COMPZ WELLPF CIRC T Pumped hi-vis sweep @ 326 gpm @ 1150 psi&circ out of hole 06/04/2014 Finish circulation-Flow ck-POOH w/CO assembly-MU Cutter assembly-RIH to RIH to 5606'-Held Pre-Spud meeting-RIH w/cutter to 5721'-PU to 5717'-Made cut-POOH w/cutter assembly(good indication on blades of cut)LD assembly-MU spear assembly-RIH to 2469' 00:00 00:15 0.25 5,723 5,723 COMPZ RPCOM CIRC T Finish circulating out hi-vis sweep @ 6 bbls/min @ 650 psi(Observed large amount of frac sand with sweep) 00:15 00:30 0.25 5,723 5,691 COMPZ RPCOM RURD T PJSM-LD single of work string-RU &reverse circ 00:30 01:45 1.25 5,691 5,691 COMPZ RPCOM CIRC T Reverse circ @ 3 bbls/min @ 180 psi -umped surface to surface volume (4500 stks)Observed small amount of frac sand @ shakers-cleaned near 1/2 of volume pumped 01:45 02:00 0.25 5,691 5,691 COMPZ RPCOM OWFF T Flow ck-well static 02:00 05:30 3.50 5,691 278 COMPZ RPCOM TRIP T PJSM-POOH w/CO assembly f/ 5691'to 278'-Calc.fill 28.5 bbls- Actual 27.7 bbls 05:30 06:30 1.00 278 0 COMPZ RPCOM TRIP T PJSM-Pull&std back 4 3/4"DC's- LD jars/bumper-bit sub-scraper& XO subs 06:30 06:45 0.25 0 0 COMPZ RPCOM RURD T Clean up&clear rig floor 06:45 07:15 0.50 0 233 COMPZ RPCOM PULD T PJSM-MU BHA#3-Bull nose- multi string cutter-pony DC's-XO- 3 1/8"DC-XO subs-Run in w/(6)4 3/4"DC's to 233' 07:15 10:30 3.25 233 5,606 COMPZ RPCOM TRIP T PJSM-RIH w/BHA f/233'to 5606' on 3 1/2"PH6 work string-Calc dispalcement-28.5 bbls Actual-28 bbls. Page 5 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 11:00 0.50 5,606 5,606 COMPZ RPCOM SVRG P Service rig 11:00 12:00 1.00 5,606 5,606 COMPZ RPCOM SFTY P Secure well and shut down for Pre- Spud meeting 12:00 13:30 1.50 5,606 5,717 COMPZ RPCOM TRIP P PJSM-RIH w/cutter assembly to 5721'-PU to 5717'-PU wt. 112 SO wt 68 13:30 15:30 2.00 5,717 5,717 COMPZ RPCOM CPBO P PJSM-Make cut @ 5717'-w/20 RPM-pumping 126 gpm @ 400 pis- Observed reduction in torque but not pressure 15:30 16:00 0.50 5,717 5,717 COMPZ RPCOM OWFF P Monitor well-Static-PJSM on POH 16:00 20:00 4.00 5,717 232 COMPZ RPCOM TRIP P PSJM-LD 2 singles of PH6 work string-POOH w/cutting assembly 20:00 21:00 1.00 232 0 COMPZ RPCOM PULD P PJSM-Monitor well static-LD cutting BHA 21:00 21:30 0.50 0 0 COMPZ RPCOM RURD P Clean&clear rig floor of BHA tools 21:30 23:00 1.50 0 219 COMPZ RPCOM PULD P PJSM-MU BHA#4-Spear(5.21 grapple)XO-Spear stop(6"OD)- Bumper-jars-(6)4 3/4"DC's-Acc. jar-XO sub to 219' 23:00 00:00 1.00 219 2,469 COMPZ RPCOM TRIP P RIH w/spear assembly f/219'to 2469'-PU wt 53 SO wt 50 06/05/2014 Cont. RIH w/spear-Engage fish-Circ-POOH-LD fish-MU BHA#5-RIH&Dress off cut-POOH w/9 std -PU&RIH w/15 jts 2 3/8"wash pipe to 5688'-Perform caustic wash 00:00 02:00 2.00 2,469 5,658 COMPZ RPCOM TRIP P PJSM-Cont. RIH w/spear assmebly f/2469'to 5658'-PU wt 115 SO wt 65 02:00 02:30 0.50 5,658 5,658 COMPZ RPCOM FISH P Slcak off to 5681'-Set down 15 k (No-Go)w/pump @ 3 bbls/min @ 180 psi-engaged fish-PU 10'- Observed no over pull-Set down& PU 2 more times 02:30 03:45 1.25 5,658 5,658 COMPZ RPCOM CIRC P Pumped 38 bbls-hi vis sweep @ 4 bbls/min @ 350 psi-pumped 2 X btms up(6500 stks-292 bbls) 03:45 04:00 0.25 5,658 5,658 COMPZ RPCOM OWFF P Flow ck-well static 04:00 08:00 4.00 5,658 219 COMPZ RPCOM TRIP P PJSM-LD top single-POOH f/ 5658'to 219'-Calc fill 28 bbls- Actual 27.5 bbls 08:00 08:45 0.75 219 0 COMPZ RPCOM PULD P Pull&std back 4 3/4" DC's-LD BHA-recovered fish 08:45 09:00 0.25 0 0 COMPZ WELLPF PULD P Clean&clear rig floor-Bring next BHA components to rig floor 09:00 10:00 1.00 0 214 COMPZ WELLPF PULD P MU BHA#5( Dress mill)-RIH w/ (6)4 3/4"DC's f/derrick to 214' 10:00 12:00 2.00 214 4,086 COMPZ WELLPF TRIP P PJSM-RIH w/BHA#5 f/214'to 4086'-PU wt 85 SO wt 53 -Calc disp. 20.5 bbls Actual-19.2 bbls. 12:00 14:30 2.50 4,086 5,715 COMPZ WELLPF TRIP P PJSM-Continue RIH w/BHA#5 f/ 4086'to 5715'-Wash down to 5719' @ 6 bbls/min @ 460 psi w/70 rpm's w/7.5 k torque-dress off top of cut 14:30 15:30 1.00 5,715 5,715 COMPZ WELLPF SFTY P PJSM on for tripping(PU 2 3/8"wash pipe) Page 6 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:30 1.00 5,715 5,121 COMPZ WELLPF TRIP P PJSM-POOH f/5715'to 5121' 16:30 20:00 3.50 5,121 5,688 COMPZ WELLPF PULD P PJSM-PU&RIH w/15jts 2 3/8" Hyd.wash pipe to perform pickle job on work string-PU XO&1 jt. 3 1/2" PH6 to 5688' 20:00 22:00 2.00 5,688 5,688 COMPZ WELLPF CIRC P PJSM-Perform caustic wash as follows: pumped 20 bbls Hi-vis sweep -Mix 70 bbls caustic wash-Pumped caustic wash followed by 100 bbls water @ 3 bbls/min @ 280 psi 22:00 22:30 0.50 5,688 5,688 COMPZ WELLPF CIRC P PJSM-Pumped 100 bbls water @ 3 bbls/min @ 280 psi to clear caustic wash f/well-taking returns to slop tank 22:30 00:00 1.50 5,688 5,688 COMPZ WELLPF OTHR P PSJM-Clean pit#6&TT-Mix 20 bbls Hi-vis sweep in pill!pit 06/06/2014 Pumped pickle&acid-reverse circ each out of hole-Pumped filtered waer to clean up well-Observed 48 NUT reading-Changed over to 9.1 ppg brine-POOH-LD BHA RU&begin BOP test 00:00 00:45 0.75 5,688 5,688 COMPZ WELLPF RURD P PJSM-Cont. preperation for pumping Safe-T Pickle 00:45 02:00 1.25 5,688 5,688 COMPZ WELLPF CIRC P PSJM Pumped 20 bbls Hi-vis sweep followed by 385 gals. of MI Safe-T pickle f/Vac truck-chased w/30 bbls fresh water @ 3 bbls/min @ 250 psi-Shut down&let soak for 15 mins.-Reverse circ out Safe-T pickle @ 3 bbls/min @ 220 psi w/100 bbls fresh water taking returns to slop tank 02:00 03:15 1.25 5,688 5,688 COMPZ WELLPF RURD P PJSM-Making preprations to pump acid-Pulled down slop tank-Mixed &pumped 40 bbls soda ash pill into slop tank for acid netrualize acid- Loaded 500 gals. 7.5%HCL acid into vac truck-hook up line f/vac truck to rig pump 03:15 05:30 2.25 5,688 5,688 COMPZ WELLPF CIRC P PJSM-Pumped acid pickle as follows: Pumped 500 gals. 7.5% HCL followed by 30 bbls fresh water @ 3 bbls/min @ 250 psi-Shut down& let soak for 15 mins.-Reverse circulate out acid pickle w/75 bbls filtered water @ 3 bbl/min @ 275 psi -Shut down&switched to circ long • way-Continue to circ filtered water @ 6 bbls/min @ 1000 psi until NUT reading of 48 05:30 06:45 1.25 5,688 5,688 COMPZ WELLPF CIRC P PJSM-Displaced well f/filtered fresh water to 9.1 ppg brine @ 6 bbls/min @ 1200 psi 06:45 07:00 0.25 5,688 5,688 COMPZ WELLPF OWFF P Flow ck-well static 07:00 12:00 5.00 5,688 214 COMPZ WELLPF TRIP P PJSM-POOH f/5688'to 214' -LD top single of 3 1/2"PH6-LD 15 jts 2 3/8"CS Hydril wash pipe- Page 7 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 214 0 COMPZ WELLPF PULD P PJSM-Std. back(6)4 3/4" DC"S& LD remaining compnoente of BHA# 5 13:30 14:00 0.50 0 0 COMPZ WELLPF RURD P PSJM-Clean&clear rig floor of BHA tools 14:00 16:00 2.00 0 0 COMPZ WHDBO RURD P PJSM-Pull wear bushing-Install test plug w/3 1/2"test jt-RU test equipment 16:00 22:00 6.00 0 0 COMPZ WHDBO BOPE P Tested BOPE as follows:tested Annular to 250&3500 psi-Tested upper pipe rams-choke&kill line valves-Choke manifold valves-4" kill line valve-Auto&manual TD IBOP's-Floor safety&dart vlaves to 250&3500 psi all tests were held for 5 mins.-Performed accumulator recovery test-Tested blind rams to 250&3500 psi- All test were w/3 1/2"testjt.Witnessing of test waived by Jim Reggs AOGCC 22:00 00:00 2.00 0 0 COMPZ WHDBO BOPE T Attempted to test lower pipe rams w/ 3 1/2"terst jt.Unable to get test- Checked for leaks(test plug holdiing no fluid coming f/annular valve below test plug-Changed valves on test manifold-Still unable to get low or high tests to stabize-Changed test jts. laid down 3 1/2"&picked up 4"- attempted to test lower pipe rams- still unable to get test 0 COMPZ 36/07/2014 Finish BOP test-Set WB-LD 4 3/4"DC's f/derrick-MU PB Overshot&Sump packer-RIH-Set packer& release-Circ-POOH 00:00 03:30 3.50 0 0 COMPZ WHDBO BOPE T Pulled 4"test jt.&test plug(had to pull test plug w/TD pulled 10 k)Test plug covered w/frac sand-Wash stack w/water hose-MU test plug w/4"test jt. RIH&set plug-Tested lower pipe rams to 250&3500 psi- Pulled 4"testjt. PU&MU 3 1/2" test jt.Tested lower pipe rams to 250 &3500 psi 03:30 04:00 0.50 0 0 COMPZ WHDBO RURD P Pulled test plug(had to pull w/TD 10 k) LD test jt&test plug-Set wear bushing-Run in lock downs 04:00 06:00 2.00 0 0 COMPZ WELLPF PULD P PJSm-LD(6)4 3/4"DC's f/derrick 06:00 08:00 2.00 0 217 COMPZ WELLPF PULD P PJSM-MU Poor Boy Overshot& Superior Sump packer assembly- PU 6 singles of 3 1/2"PH6 work string f/pipe shed 08:00 12:00 4.00 217 2,715 COMPZ WELLPF TRIP P PJSM-RIH w/packer assembly f/ 217'to 2715'-running 3 1/2"PH6 work string f/derrick 12:00 17:30 5.50 2,715 5,658 COMPZ WELLPF TRIP P Continue RIH w/PB OS&Sump packer f/2715'to 5658'-PU wt 100 SO wt 62 Page 8 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 18:30 1.00 5,658 5,710 COMPZ WELLPF PACK P PJSM-Space out to set packer( top of packer @ 5689-btm of Poor Boy Over shot @ 5710'-Drop 2" setting ball-Pressure up on tbg to 1200 psi(observed 1 st shear on packer setting)-Pressure up to 3500 psi(2nd shear not observed) 18:30 19:30 1.00 5,710 5,710 COMPZ WELLPF PACK P PJSM-Set packer @ 5689'-Test tbg to 3500 psi-Pull up to 20 K over (pull test Good)packer set 19:30 21:00 1.50 5,710 5,710 COMPZ WELLPF PACK P PJSM-RU to pump down back side -Close upper pipe rams-Presssure up to 500 psi-pressure bleed off- Unscrew f/TD-pressure up on annulus to 1500 psi-pressure bleeding off-pressure up to 750 psi to shear annular release valve-bleed off annulus-Open pipe rams- Attempt to pull setting tool- Observed 25 k over pull-No release -Slack off to 25 k-Close pipe rams pressure up on annulus to 1500 psi- bleeding off at slower rate than 1 st time-bleed off annulus to 0-Open rams-PU on string 25 k over pull- slack off to 25 k-Close pipe rams& pressure up on annulus to 1525 psi- Held for 10 mins. lost 13 psi(Good packer test)-Open pipe rams- Pressure test lines to 4350 psi- Pressure up on tbg to 4500 psi and held for 5 mins to shear ball seat- Bleed off pressure-PU on string 30 K over-No release-Held over pull and observed wt dropping off to 10 K over-PU on string pulling setting toolf/packer- PU wt 100 SOwt62 -Pu,mp down tbg @ 1/2 bbls/min- Observed returns 21:00 21:30 0.50 5,710 5,680 COMPZ WELLPF CIRC P Circ 20 bbls @ 3 bbls/min @ 200 psi -Line up&close pipe rams- Reverse circ 40 bbls to clean all fresh water pumped during packer setting operation 21:30 22:00 0.50 5,680 5,680 COMPZ WELLPF RURD P PJSM-Blow down injection pump- RD pump and lines 22:00 00:00 2.00 5,680 2,410 COMPZ WELLPF TRIP P PJSM-LD 1 single-POOH f/5657' to 2410' 36/08/2014 Cont. POOH w/work string& Sump packer setting tool-LD RT-RU&PU TCP guns-RIH w/guns-Space out to get on depth-Set sump packer plug-Drop bar&fire guns-Moniotr pressure 815 psi-RU&reverse circ-Line up&circ long way-Flow ck well dead-Monitor well on TT-Static loss rate<4 bbls/hr-RD surface equpiment-POOH 00:00 02:00 2.00 2,410 196 COMPZ WELLPF TRIP P Cont. POOH w/3 1/2"work string& Sump packeer setting tool 02:00 03:00 1.00 196 0 COMPZ WELLPF PULD P PJSM-LD 6 jts. 3 1/2"PH6 tbg& sump packer setting tool(Observed frac sand on running tool ) Page 9 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:00 1.00 0 0 COMPZ RPCOM RURD P PJSM-RU to pick up TCP guns 04:00 08:00 4.00 0 633 COMPZ PERF PULD P PJSM-PU Superior packer plug- (21)4 1/2"perf guns-Firing head-2 jts. 2 7/8"spacer out tbg-packer- safety jt-XO 08:00 12:00 4.00 633 2,944 COMPZ PERF TRIP P PJSM-RIH w/TCP assembly on 3 1/2"PH 6 work string f/633'to 2944' -(Filled 1st 42 stds w/9.1ppg brine) PU wt 45 SO wt 40 12:00 17:00 5.00 2,944 5,689 COMPZ PERF TRIP P PJSM-Cont. RIH w/TCP assembly f/2944'to 5634'-PU std.#81 - Stack off&space out to set packer plug into Sump packer @ 5689'as per Superior service hand 17:00 18:30 1.50 5,689 5,689 COMPZ PERF RURD P PJSM-RU surface lines for circulating after firing perf guns-Test lines to 2500 psi 18:30 19:00 0.50 5,689 5,689 COMPZ PERF PACK P PJSM-Set packer 5053'as per Schlumberger service hands 19:00 20:30 1.50 5,689 5,689 COMPZ PERF PERF P PJSM-Drop bar to fire guns-Guns fired @ 1931 hrs.-Tbg pressure stablized @ 815 psi-Line up to reverse out perfed 21 SPF @ 5662'to 5677' - 5604'to 5631'-5538'to 5548'-5520' to 5527'-5182'to 5191' 20:30 21:00 0.50 5,689 5,689 COMPZ PERF CIRC P PJSM-PU 3'to open by-pass on packer @ 5053'-Reverse circ to kill well-pump down kill line taking returns thru choke to gas buster- Circ @ 3 bbls/min @ 100 psi-Shut down&flow ck. slight flow thru gas buster-Shut in choke-pressured up to 90 psi 21:00 22:00 1.00 5,689 5,689 COMPZ PERF CIRC P PJSM-Line up to circ down tbg- Circ btms up @ 3 bbls/min @ 126 psi taking returns thru choke and gas buster-Intinal loss rate 36 bbls/hr- final loss rate 24 bbls/hr.-Shut down 22:00 23:30 1.50 5,689 5,689 COMPZ PERF RURD P Check for folw well dead-Open annular-fluid level dropping-Monitor well on TT-RD surface lines& equipment-Static loss rate<4 bbls/hr 23:30 00:00 0.50 5,689 5,443 COMPZ PERF TRIP P POOH w/work string&TCP assembly f/5689' to 5443'on TT 36/09/2014 Finish POOH w/perf guns-LD guns-MU MI clean up assembly w/Superior packer plug pulling tool-RIH to 5145'-Circ&rotate CO assembly f/5145'to 5673'-Unable to work assembly below 5673'-Pump out to 5145' 00:00 06:00 6.00 5,443 633 COMPZ PERF TRIP P PJSm-Continue POOH w/perf guns f/45443'to 633'(top of guns) 06:00 10:00 4.00 633 0 COMPZ PERF PULD P PJSM-LD safety jt-packer-2 jts 2 7/8"tbg-fire head-21 perf guns(all shots fired) 10:00 10:30 0.50 0 0 COMPZ RPCOM PERF P PJSM-Clear floor of perf gun handling equipmet Page 10 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 11:00 0.50 0 0 COMPZ RPCOM SVRG P Service rig&TD 11:00 12:00 1.00 0 0 COMPZ RPCOM RURD P Move spent perf guns f/pipe shed- load pipe shed w/MI clean out tools Note: monitored well on TT for 2 hrs. -lost 3 1/2 bbls 12:00 15:00 3.00 0 644 COMPZ RPCOM PULD P PJSM-MU perf clean up assembly- Superior packer plug pulling tool-MI 7"Ridge Back Burr Mill-7" Magnostar-8 stds 3 1/2"PH 6 work string- Well Scavenger btm sub-3 Well scavenger Debis Chamber Modules-Well Scavenger Debris Screening module-Well Scavenger Engine Module-XO to 644' 15:00 19:00 4.00 644 5,145 COMPZ RPCOM TRIP P PJSM-RIH w/De-Burr assembly on 3 1/2"PH 6 work string o 5145'- Establsih torque valve 60 rpm's @ 4.2 k-Pump rates-3 bbls/min 220 psi-3 1/2 bbls/min @ 295 psi-4 bbls/min @ 380 psi-4 1/2 bbls/min @ 470 psi-5 bbls/min @ 575 psi-5 1/2 bbls/min @ 680 psi-6 bbls/min @815 psi-PUwt92 SOwt60 19:00 23:30 4.50 5,145 5,673 COMPZ RPCOM CIRC P PJSM- Circ @ 4.8 bbls/min @ 525 psi w/60 rpm's @ 4.2 k ft/lbs torque -wash&ream f/5145'to 5673'w/ DeBurr mill-magnet&debris chambers to clean up f/perfarating 7"casing f/5145'to 5673'-Unable to wash down below 5673'-Worked string serveral times with high pump rate-still no progress-Well Scavenger modules possibly full Lost 64 bbls 9.1 ppg brine to formation while work assembly 23:30 00:00 0.50 5,673 5,145 COMPZ RPCOM TRIP P PJSM-POOH w/pump @ 3 bbls/min @ 195 psi f/5673'to 5145'- PU wt 100 So wt 60 06/10/2014 POOH-LD MI clean out assembly-MU Superior packer plug pulling tool-RIH 00:00 05:00 5.00 5,145 644 COMPZ RPCOM TRIP P PJSM-POOH f/5145'to 644'w/MI perf clean out assembly 05:00 08:00 3.00 644 0 COMPZ RPCOM PULD P PJSM-LD MI pert clean out assembly-Pull and checked screen f/debris screening module-observed quit a bit of fine sand packed on surface on screen and fine metal shavings on the magnet 08:00 10:00 2.00 0 80 COMPZ RPCOM PULD T PJSM-MU Superior packer plug pulling BHA-Debris free pulling tool -XO- 1 std PH 6 tbg-XO-unloader valve-XO to 80' 10:00 12:00 2.00 80 4,269 COMPZ RPCOM TRIP T PJSM-RIH w/packer plug pulling BHA on 3 1/2"PH 6 work string f/80' to 4269'-PUwt64 SOwt54 Page 11 of 17 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:00 13:30 1.50 4,269 5,569 COMPZ RPCOM TRIP T PJSM-Cont. RIH w/packer plug pulling BHA f/4269'to 5569'-PU wt 102 SOwt62 13:30 15:30 2.00 5,569 5,668 COMPZ RPCOM CIRC T PJSM-Wash down f/5569' -@ 3 bbls/min @ 155 psi-tag up on hard fill @ 5669' increase rate to 6 bbls/min @ 620 psi-increase rate to 8 bbls/min @ 1010 psi-broke thru wash down&latch into plug @ 5699' -Pulled 50 k over to pull plug Pull up to 5668'-Circ-RU&reverse circ 182 bbls 15:30 16:00 0.50 5,668 5,060 COMPZ RPCOM TRIP T POOH f/5668'to 5060'-(above perfs) PU wt 93 SO wt 58 16:00 16:30 0.50 5,060 5,060 COMPZ RPCOM OWFF T Monitor well on TT for 30 mins 16:30 20:00 3.50 5,060 80 COMPZ RPCOM TRIP T PJSm-POOH w/PPP assembly f/ 5060'to 80'(top of BHA) Calc hole fill 25.2 bbls-Actual 41.7 bbls-hole took 16.5 bbls over on trip 20:00 20:30 0.50 80 0 COMPZ RPCOM PULD T PJSM-LD packer plug pulling BHA (recovered plug) 20:30 21:00 0.50 0 20 COMPZ RPCOM PULD T PJSM-Clear rig floor of PPP BHA components-PU Superior seal bore washing assembly to 20' 21:00 00:00 3.00 20 COMPZ RPCOM TRIP P PJSM-RIH w/Superior washing assembly f/20'to 06/11/2014 RIH w/wash latch assembly-Wash down&latch into sump packer 2 X-Circ btms-POOH LD assembly- MU&RIH w/gravel apck assembly 00:00 01:30 1.50 5,232 5,709 COMPZ RPCOM TRIP P Cont. RIH f/5232'to 5708'-PU single RIH to 5709(Btm of 2 3/8" stinger)Attemoted to locate top of smup packer w/latch pop lock- Unable to confirm latch up 01:30 03:00 1.50 5,709 5,712 COMPZ RPCOM CIRC P Wash down w/2 3/8" stinger f/5709' to 5712'@ 3 bbls/min© 150 psi increased rate to 5 bbls/min ©700 psi-circulated btms up 03:00 03:30 0.50 5,715 5,712 COMPZ RPCOM CIRC P Slacked off&latched into sump packer w/latch pop lock-PU& obseverd 10 K over pull to unlatch- Attempted to latch up again-unable to relatch-wash back down to 5712' -shut down pump&slack off observed latch up-PU to unlatch 55 K over pull work string and unlatched f/packer w/55 k over-PU to 5709' w/stinger-Btm of 2 3/8"stinger @ 5715'-Latch pop lock @ 5699'(top of sump packer) 03:30 04:30 1.00 5,712 5,712 COMPZ RPCOM CIRC P Circ btms up @ 5 bbls/min 485 psi 04:30 09:30 5.00 5,712 0 COMPZ RPCOM TRIP P PSSM-POOH w/wash assembly- LD latch tool 09:30 11:30 2.00 0 0 COMPZ RPCOM RURD P PJSM-Clear rig floor of tools-Prep for gravel pack tool run Page 12 of 17 Time Logs ,Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 0 0 COMPZ RPCOM SVRG P Lub&service TD&crown 12:00 17:30 5.50 0 500 COMPZ RPCOM PULD P PJSM-PU Superior gravel pack tools as per detail&Superior service hands 17:30 19:00 1.50 500 500 COMPZ RPCOM PRTS P Attempt to test lower screen& packer assembly-Packer leaking- LD packer&PU back up packer- retest to 500 psi(GOOD) 19:00 00:00 5.00 500 613 COMPZ RPCOM PULD P Cont. to PU&RIH w/Gravel packer assembly 06/12/2014 Cont. PU GP inner string-PU top packer&MU to inner string-RIH w/GP assembly on 3 1/2"PH 6 work string-Sting into Sump packer w/locator Pop loc-Set upper packer-perform tests on tool string 00:00 02:45 2.75 0 615 COMPZ RPCOM PULD P PJSM-Cont. MU gravel pack inner string f/264'to 615' 02:45 06:30 3.75 615 615 COMPZ RPCOM PULD P Decripple opening tool-worked tool to obtain shear out up&down worked tool several times-Test to 500 psi good test-PU &open sleeve -pump down string w/test pump got returns-closed sleeve&tested to 500 psi-PU glass break jt.-RIH& break glass-Observed fluid level drop-LD glass break jt-PU&MU top packer to inner string 06:30 07:30 1.00 615 615 COMPZ RPCOM RURD P PJSM-Clear rig floor of BHA handling equipment 07:30 12:00 4.50 615 3,532 COMPZ RPCOM RUNL P PJSM-RIH w/gravel packing assembly on 3 1/2"PH6 work string f/615'to 3532' 12:00 14:00 2.00 3,532 4,846 COMPZ RPCOM RUNL P PJSM-Cont. RIH w/grqavel pack assembly on 3 1/2"work string f/ 3532'to 4846' 14:00 15:00 1.00 4,846 4,846 COMPZ RPCOM RURD P PJSM-RU&test TIW valve for GP string to 250&3500 psi(Good test) RD 15:00 15:30 0.50 4,846 4,846 COMPZ RPCOM PULD P PJSM-PU single 3 1/2"PH 6-MU TIW valve-pup jt. &pump in sub& torque up-LD jt in shed 15:30 17:30 2.00 4,846 5,668 COMPZ RPCOM RUNL P Cont. RIH w/GP assembly on 3 1/2" work string f/4846'to 5668'-PU wt 111 SO 65 17:30 18:30 1.00 5,668 5,668 COMPZ RPCOM RURD P PJSM-Remove elevators-Change bails on TD to 16' for GP operation 18:30 19:30 1.00 5,668 5,668 COMPZ RPCOM PULD P PJSM-PU 2 jts 3-1/2"PH6 f/shed 2nd jt(w/pump in sub- MU 3"low torque valve&cmt line 19:30 20:00 0.50 5,668 5,711 COMPZ RPCOM RUNL P PJSM-Slack off&sting into sump packer w/locator pop loc @ 5699'w/ tail of GP string @ 5711' 20:00 21:00 1.00 5,711 5,711 COMPZ RPCOM PACK P PJSM-RU&drop packer setting ball-Test lines to 4000 psi-Drop packer setting ball let fall&then pump down Page 13 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 5,711 5,711 COMPZ RPCOM PACK P PJSM-Set upper packer-Pressure up to 1500 psi (observed 1st shear) pressure up to 2600 psi(Observed 2nd shear)-Pull test packer pulled 40 k over&slack off w/20 k down- Pressure test annulus to 100 psi f/5 mins.-Pressure up to 3500 psi for 5 mins.(Good test)-Pressure up on tbg to 4500 psi to release running tool-PU&reverse out setting ball @ 4 bbls/min @ 980 PSI-pumped 52 bbls. -PU 29'to open&slack off 10' -opened MSV-Close pipe rams& perform pump in test-Pressure up to 500 psi-pressure bleed off to 60 psi in 5 mins. 06/13/2014 Pull up w/GP string f/5658'to 5284'-locate position on GP tool-Open frac sleeve&do pump-in test-Close sleee&test-Position tools in set mode-RU BJ for GP job 00:00 01:00 1.00 5,711 5,711 COMPZ RPCOM RURD P PJSM-LD pump sub jt. &1 more jt. POOH f/5658 to 5284'w/inner string tools 01:00 01:30 0.50 5,711 5,711 COMPZ RPCOM RURD P Find position on GP tool-set ISO packer w/4500 psi 01:30 03:00 1.50 5,711 5,711 COMPZ RPCOM RURD P PU&break out pump sub&TIW valve-MU space out pups-Slack off &locate GP sleeve-Open sleeve& perform injection test-3 bbls/min @ 1550 psi for 6.7 bbls w/3.7 bbls returns-MU TIW valve&pump sub to top of space out pups-MU swivel &head to pump in sub 03:00 03:30 0.50 5,711 5,711 COMPZ RPCOM RURD P PU&close GP sleeve&test to 1000 psi for 5 mins. 03:30 08:00 4.50 5,711 5,711 COMPZ RPCOM RURD P PJSM-Rig up BJ GP lines 08:00 09:45 1.75 5,711 5,711 COMPZ RPCOM RURD P PJSM on testing lines-Test surface line&equipment 09:45 10:45 1.00 5,711 5,711 COMPZ RPCOM CIRC P Line up BJ to pump-perform circulation @ 1.6 bbls/min, 3.9 bbl/min,@ 20000 psi 5.9 bbls/min.@ 2600 psi , 8.1 bbls/min @3600 psi 9.4 bbls/min @ 4400 psi&injection test- 1.7 bbls/min @ 1200 psi-2.9 bbls/min @ 1800 psi-6 bbls/min @ 2800 psi-8.1 bbls/min @ 3800 psi- Shut down pump 10:45 11:00 0.25 5,711 5,711 COMPZ RPCOM OTHR P PU string(strip thru annular)to reverse position&simualte reverse out sequence w/rig pump-slack off string to set down position w/wt down 11:00 11:15 0.25 5,711 5,711 COMPZ RPCOM SFTY P Held PJSM w/all service hands&rig crew on pumping GP job Page 14 of 17 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 13:00 1.75 5,711 5,711 COMPZ RPCOM GRVL P Pumped gravel pack job in lower zone-Shut down pumps @ sand out-PU&reverse out w/rig pumps @ 6 bbls/min @ 1600 pis(pumped 2 X string vlo.w/8.5 ppg brine-Shut down pumps 13:00 15:00 2.00 5,711 5,711 COMPZ RPCOM PRTS P RIH&function sleeves closed- POOH and pressure test to 2500 psi for 5 mins. (good) 15:00 16:00 1.00 5,711 5,711 COMPZ RPCOM PRTS P POOH&LD 1 single&pup jts- Pressure test to 3000 psi for 5 mins. (Good) Lower sleeves closed 16:00 19:00 3.00 5,711 5,711 COMPZ RPCOM GRVL P MU 1 jts.&pup jts f/shed-RIH& set tool-RU pumping assembly- Perform circ&injection test w/BJ- Pumped GP job for upper zone @ screen out-PU&reverse out w/rig pumps @ 7 bbls/min @ 1960 psi w/ 9.1 ppg brine circ 2X string vol.- Shut down pumps 19:00 21:00 2.00 5,711 5,711 COMPZ RPCOM CIRC P RIH&close GP sleeves-Pressure test to 2500 psi for 5 mins.-Reverse circ w/rig pumps @ 4 bbls/min @ 650 psi(pumped 40 bbls-POOH std back to stds& LD 1 single&pup jts -(tail of inner tool string @ 5021'40' above top of packer) 21:00 22:00 1.00 5,711 5,711 COMPZ RPCOM RURD P PJSM-RU&blow down BJ lines- RD BJ lines&remove f/rig floor-RU to LD pipe(cleaning pits) Monitor well on TT-well static no losses 22:00 00:00 2.00 5,711 5,711 COMPZ RPCOM PULD P POOH f/5021' to 3919'-laying down workstring 06/14/2014 Cont. POOH&LD work string-LD 2 3/8"inner string&GP tools-LD 20 stds work string f/derrick-Prep 3 1/2"tbg-RIH 3 1/3"upper completion 00:00 03:30 3.50 5,711 624 COMPZ RPCOM PULD P PJSM-POOH LD 3 12"work string f/3919'to inner string 03:30 06:30 3.00 624 0 COMPZ RPCOM PULD P PJSM-POOH &LD 2 3/8"wash pipe&Superior GP tools 06:30 09:00 2.50 1,240 0 COMPZ RPCOM PULD P PJSM-RIH w/20 stds 3 1/2"PH-6 workstring-POOH&LD same 09:00 09:30 0.50 0 0 COMPZ RPCOM RURD P PJSM-RU&Pull wear bushing 09:30 15:00 5.50 0 0 COMPZ RPCOM RURD P PJSM-Load pipe shed w/3 1/2" EUE tbg-Drift&strap-Spot Camce spools w/injection line&control line -Hang sheaves Page 15 of 17 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 00:00 9.00 0 2,090 COMPZ RPCOM RCST P PJSM-Ran 3 1/2"9.3#L-80 EUE 8RD upper completion as follows: Superior seal assembly-1 jt tbg- Halliburton X nipple- 1 jt tbg-Camco GLM assembly-51 jts.tbg-Camco Chem. injection mandral -37 jts tbg to 2920'(90 jts total in hole) Note: Had to lay down 10 jts.of tbg galled boxes&pins 06/15/2014 Cont. RIH w/3 1/2"upper completion-Pumped inhibited brine-Landed tbg-Tested tbg&IA-Set TWC& test-Flush pumps&lines-Begin ND BOP stack 00:00 08:00 8.00 2,920 4,984 COMPZ RPCOM RCST P 1PJSM-Cont. RIH w/3 1/2"upper completion f/2920'to 4984'-PU SSSV-MU control line&test connection to 5000 psi for 10 mins. ( 141 jts total in hole) LD 4 jts tbg w/galled pins&boxes on make up-Stopped w/111 jts in hole cleaned&inspected remaining tbg in pipe shed 08:00 12:00 4.00 4,984 4,984 COMPZ RPCOM RCST T Estimated Trouble Time for total of 22 galled joints(pins/boxes)that had to be laid down. 12:00 14:30 2.50 4,984 5,053 COMPZ RPCOM RCST P PJSM-Cont. RIH w/3 1/2" completion 155 jts-PU 2 jts& obtain space out measurements-LD space out jts.-MU space out pups 10.22'-4.11'-2.27'&2.28')-MU landing jt&hanger 14:30 15:30 1.00 5,053 5,053 COMPZ RPCOM RCST P PJSM-Temrinate control&injection lines through tbg hanger--RU to pump inhibited brine 15:30 16:00 0.50 5,053 5,053 COMPZ RPCOM CRIH P PJSM-line up to pump down tbg- pumped 150 bbls 9.1 ppg flitered brine followed by 50 bbls.9.1 ppg inhibited brine-dispalced inhitited brine f/tbg w/30 bbls/9.1 ppg filtered brine @ 7 bbls/min @ 820 psi -Shut down bleed off lines&RD 16:00 16:30 0.50 5,053 5,062 COMPZ RPCOM THGR P PJSM-Land tbg hanger in wellhead w/tbg tail @ 5061.98'-PU wt 74 So wt 52-Locator spaced out.74'f/ fully located Used 107 Cannon clamps& 16 stainless steel bands to secure injection&control lines to tbg 16:30 16:45 0.25 5,062 5,062 COMPZ RPCOM THGR P RI lock down screws-Test tbg hanger seals to 5000 psi for 10 mins. 16:45 17:00 0.25 5,062 5,062 COMPZ RPCOM RURD P RD Weatherford tongs and equipment and LD f/rig floor Page 16 of 17 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 17:00 19:00 2.00 5,062 5,062 COMPZ RPCOM PRTS P Pressure up on tbg to 2500 psi and test for 15 mins(Good test)-Bleed tbg down to 2000 psi-pressure up on IA to 2500 psi&test for 30 mins. (Good Test)-Bleed annulus&tbg to 0 psi sheared SOV in GLM-Bleed off pressure f/tbg&IA to 0 psi- Monitor well for 30 mins.Well static 19:00 20:00 1.00 5,062 5,062 COMPZ WELCTI.MPSP P LD landing jt-Set TWC-Pressure test TWC in direction of flow to 1000 psi for 10 mins. (Good Test) 20:00 21:00 1.00 5,062 5,062 DEMOB MOVE RURD P PJSM-Flush mud pumps , mud lines, BOP stack, - jet flow line- Blow down all lines-RD controls line &injection line sheaves and clear floor of all equipment 21:00 00:00 3.00 5,062 5,062 DEMOB MOVE RURD P PJSM-RD flow line&riser-choke &kill lines-bleed Accmuulator lines &disconnect lines-Install spud masher on top of annular for ND stack-Rig down equipment in pits and disconnect jumpers for rig move 06/16/2014 ND BOPE-NU&tested tree-Pull TWC-Set BPV 00:00 10:00 10.00 5,062 5,062 DEMOB MOVE NUND P PJSM-ND BOPE-terminate control &chem injection lines thru well head -NU tree-Test void to 5 000 for 10 mins.-Test tree to 5000 -Good Tests 10:00 12:00 2.00 5,062 5,062 DEMOB MOVE RURD P PJSM-Prep pits and rig for move. Released rig @ 12:00 hrs. 6/16/2014 Move to BRU 242-04 12:00 00:00 12.00 DEMOB MOVE RURD P Rig down and Move out the following equipment Pipe shed, Power Plant, 2-Boiler houses, Rig fuel tank, Pump room and Pit Modules. Rig down Top Drive and offload with crane Bridal Up and scope down Derrick Remove Gas Buster Continue to PU and move available rig mats and load trucks 06/17/2014 Continue to tear down rig and secure and move off well 00:00 06:00 6.00 DEMOB MOVE RURD P PJSM, Rig Down Tubing Board, Prep Derrick for lay over, Unstring Blocks, Lay derrick over, Rig Down Work Floor, Lower Dog house into water tank and remove from area. Crane off derrick and load out, Remove sub and Pony sub. Lower pit mod roofs. Clean up location and secure BRU 244-23 1 Page 17 of 17 ...••••••••••••••• rill1111111111111.111.111111111.1111.11Mil").M....11.1.11111.111.1111mm, `, APV OF'Tye THE STATE :'.LaE I'T ' 333 Wesi Seventh A venue GOVERNOR SEAN P \RNELL Anchorage, Alaska 99501-3572 r _ VCln q07 27Q Drew Huck a/a._ Sr. Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, BRU 244-23 Sundry Number: 314-259 Dear Mr. Huck: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair l�- DATED this Zy' day of April, 2014. Encl. 44 • STATE OF ALASKA • • AL •<A OIL AND GAS CONSERVATION COMMIbSION APPLICATION FOR SUNDRY APPROVALS • 44 Z4/i4_, 20 AAC 25.280 '.1i 'i: -;! .i.� 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate pa Rill Tubing r Time Extension r Operational Shutdown r Re-enter Susp Well r Stimulate r Alter casing r Other: Gravel Pack .17 2.Operator Name: 4.Current Well Class. 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r• 212-069 • 3 Address: Stratigraphic r Service r 6.API Number. P 0 Box 100360,Anchorage,Alaska 99510 50-283-20165-00 7 If perforating, 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No I BRU 244-23 • 9 Property Designation(Lease Number): PO 10.Field/Pool(s). ADL 17658, c,211.Z7- Beluga River Undefined Gas Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft) Plugs(measured): Junk(measured): 7553 • 6685 . 7458' • 6591'N none none Casing Length Size MD TVD Burst Collapse Conductor 83' 20" 107' 107' Surface 3404' 9 625" 3,427' 2,790' 5,750 psi 4,230 psi Production 7522' 7" 7,542' 6,675' 7,240 psi 5,410 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade. Tubing MD(ft): from 5827'to 7108';See Attached • 4960'-6241' 4.5 x 3.5 L-80 5680', 6626' Packers and SSSV Type• Packers and SSSV MD(ft)and TVD(ft) 1 Premier Production Packer and 4 isolation packers 5712',5975',6322',6518',6600'MD and 4845',5108',5455',5651',5733'TVD SSSV-WRSSSV SSSV-459'MD/ND • 12.Attachments: Description Summary of Proposal • F13 Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development F - Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2014 Oil r Gas r . WDSPL r Suspended r 16.Verbal Approval: Date. VVINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Drew Huck @ 265-6828 Email. Andrew.Huck@conocophillips.com Printed Name Drew I-1(y'//f Title. Sr. Drilling Engineer Signature �� ✓(/ Phone:265-6828 Date '/2'i/19. Commission Use Only Sundry Number Conditions of approval. Notify Commission so that a representative may witness -)j\y-2SCk Plug Integrity r BOP Test r✓ Mechanical Integrity Test r Location Clearance r Other: , 350o PS;, BOI° l s RBDM MAY U 8 2014 Spacing Exception Required? Yes ❑ No Subsequent Form Required /d - y 0 y APPROVED BY Approved by: 9COMMISSIONER THE COMMISSION Date: 4'Z4�1 'yit/PA application Is valid for 12 moontiki_hs from he� date of approval. 1 Form 10-403 evised 10/2012) oRIGINAI T 1 I 'cI Submit Form and Attachments in Duplicate Y /y yV •'`t r ConocoPhillips Alaska P.O. BOX 100360 . ANCHORAGE,ALASKA 99510-0360 April 21st,2014 Commissioner Dan Seamount State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Beluga River Unit Producer 244-23 (PTD#212-069). BRU 244-23 was originally drilled & completed as a producer in the Beluga G, H and I sands in 2012 jt was subsequently fracture stimulated after the rig moved off and has since been produced. The purpose of this workover is to add perforations in 5 intervals in the Beluga E, F, and G sands and gravel pack those intervals in 3 zones while keeping the existing lower completion to maintain production of the Beluga G, H and I sands already perforated. If you have any questions or require any further information, please contact me at 343-9790 or Andrew.Huck@cop.com. Please keep in mind proposed completion depths are approximate. Sincerely, 211,7" Drew Huck - Workover Engineer CPAI Drilling and Wells BRU 244-23 Rig Re-complete: Pull 4-1/2" completion, perforate and gravel pack Beluga E, F, G, run 3-1/2" completion (PTD# 212-069) Current Status: The well is currently producing from sand in the Beluga G,H,and I. Scope of Work: Pull the existing gas lift upper completion, cut off part of the lower completion above the top packer, perforate 5 intervals and gravel pack in 3 separate intervals,run 3-1/2"gas lift upper completion. General Well info: MASP: 2,478 psi(using 0.1 psi/ft gas gradient and Beluga I @ 7,048'MD) Max.Reservoir pressures/TVD: From 2012 RDT data: Beluga I @ 7,048' MD/6,170' TVD=3,095 psi/9.7 ppg Max Exposed above Pre-Rig plug during RWO(after TCP): Beluga E @ 5,188' MD/4,321' TVD=2,044 psi/9.1 ppg KWF will be 9.4 ppg, which is a 0.3 ppg overbalance. Wellhead type/pressure rating: VetcoGray MB-230/5,000 psig Arctic Fox BOP Configuration: Annular/Pipe Rams/Blind Rams/Flow Cross/Pipe Rams Well Type: Gas Producer Estimated Start Date: June 1st,2014 Workover Engineer: Drew Huck(265-6828/343-9790,Andrew.Huck@cop.com) Completion Engineer: Austin Shields(263-4523,Austin.J.Shields@cop.com) Proposed Pre-Rig Work: 1. MIRU slickline. 2. Pull WRDP. 3. Set plug in completion below top packer. 4. Dump bail sand atop plug. 5. Pull DMY valve from GLM at 5591' and leave open. 6. Circulate water into tubing and IA. 7. Monitor tubing and IA and bleed off any gas. Perform combo-MIT (TxIA) to confirm casing and tubing integrity. 8. Set BPV. 9. Prep site and pad as needed for the rig. Proposed Procedure: 10. MIRU. Pull BPV. Ara�'ii 11. Conduct no-flow test. Install BPV. ND tree. 12. Install blanking plug. NU BOPE. Function and PT BOPE to 3,500 psig Pull blanking plug. Pull the BPV. 13. POOH w/4 '/2" completion. (If the seal assembly will not pull free, cut tubing above the SBE and POOH w/ tubing.) 14. Cut 4-1/2"pup joint above packer at 5,707' MD. Fish HR setting sleeve, SBE,and top part of cut pup joint. 15. RIH with sump packer and overshot. Space out and set sump packer with overshot over cut pup joint. • 16. Tubing conveyed perforate 5 target intervals in the Beluga E,F,and G sands,pumping a fluid loss control pill if necessary. 17. Cleanout debris and perforation burrs to sump packer. 18. RIH with 3 zone gravel pack system and inner string, latch into sump packer and set isolation packers. 19. Pump gravel pack in 3 zones successively. POOH with inner string and workstring. 20. RIH with 3-1/2"upper completion, circulate in CI brine,space out, stab into top packer, and set hanger. 21. PT tubing and IA. 22. Set BPV. 23. ND BOP. NU tree. PT tree and tubing hanger packoffs. 24. RDMO. 25. Turn well over to operations 244-23 Existing Perforation Depths MD(ft) TVD(ft) 5,8271-5,833' 4,960'-4,966' 6,050'-6,061' 5,183'-5,194' 6,217'-6,233' 5,350'-5,366' 6,262'-6,270' 5,395'-5,403' 6,307'-6,309' 5,440'-5,442' 6,347'-6,361' 5,480'-5,494' 6,563'-6,571' 5,696'-5,704' 6,686'-6,700' 5,819'-5,833' 7,030'-7,042' 6,163'-6,175' 7,096'-7,108' 6,229'-6,241' .. •. SAK BRU 244-23 e. C� illips `* = Well Attributes Max Angle&MD TD Alaska,he. Wellbore AP WWI Field Name Well Status Incl(°) ME(ftKB) Act Btm(kKB) uro<oP!vn,ps r..£ 502832016500 BELUGA RIVER UNIT PROD 5,824.00 _ 7,553.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:WRDP Last WO: 8/152012 Well Contg:DEVIATED-BRU 244-23,4/102013 9:54:13 AM Schematic-Actual Annotation Depth(kKB) End Date Annotation Last Mod By End Date Last Tag:RKB 7,280.0 1/27/2013 Rev Reason:Pull Plug,delete ball seats osborl 4/10/2013 HANGER,16Casing Strings ems , , _ Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd _ CONDUCTOR 20 18.730 24.0 107.0 107.0 165.00 H-40 WELDED CasingD sedI png Top((MB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd P SURFACE 95/8 8.835 23.1 3,427.0 2,789.8 40.00 L-80 BTC-M ption _Strieg '.Top(MB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd PRODUCTION 70... 6.276gD20.3 7,541.9 6,674.5 26.00 L-80 BTCM ill Tubing Strings CONDUCTOR. 24-107 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd WRDP. ME TUBING 41/2 39581,705.3 4,838.1 12.60 L-80 IBTM Mkt,. SAFETY VLV, z 459 `= Completion Details Top Depth (ND) Top Incl Nomi... Top(RKB) (kKB) (') Item DesedptIon Comment ID(In) SURFACE. 17.6 17.6 0.00 HANGER VETCO MB-230 HANGER 4.500 233.427 459.0 459.0 -0.21 SAFETY VLV CAMCO BP6I SAFETY VALVE w/DB PROFILE 3.812 5,529.6 4,662.5 0.91 NIPPLE 'CAMCO 4.5"CHECMICAL INJECTION SUB 3.863 5,617.5 4,750.4 0.93 NIPPLE HALLIBURTON XN NIPPLE 3.813"SEAL BORE 3.725 5,668.6 4,801.4 0.95 XO Reducing CROSSOVER 4.5"x 3.5" 3.500 Ali at. 5,680.4 4,813.2 0.96 LOCATOR BAKER GBH-22 LOCATOR SUB 3.000 NIPPLE,5,530 Ba 5,681.6 4,814.5 0.96 SEAL ASSY BAKER GBH-22 SPACER TUBE 8 SEAL ASSEMBLY 3.000 In 4! 5,704.8 4,837.6 0.97 MULE SHOE SEAL ASSEMBLY MULE SHOE 3.000 GAS LIFT. �` 5591 . Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd NIPPLE.5618 ,pre GRAVEL PACK 31/2 2.992 5,666.8 6,626.8 5,759.5 9.30 L-80 IBT - Completion Details II Top Depth SLEEVE,5,667 = (ND) Top Incl Nomi... NIPPLE.5.679 1 a■ Top(MB) ( B) (") Item Description Comment 113(In) LOCATOR. 5,666.8 4,799.6 0.95 SLEEVE HR LINER SETTING SLEEVE 5.250 5.OR. sBE,5662` t. 5,679.0 4,811.8 0.96 NIPPLE RS NIPPLE 4.260 SEAL ASSY, 6 taw 5,681.9 4,814.8 0.96 SBE 80-40 SEAL BORE 4.250 MULE SHOE, oft_ 0705 -AO 5,701.3 4,834.1 0.97 XO Reducing CROSSOVER 5"x 4.5" 4.500 PACKER,5,713 - 5,712.5 4,845.4 0.97 PACKER 598-387 PREMIER PACKER 3.870 OF S 5,720.6 4,853.4 0.98 XO Reducing CROSSOVER 4.5"x 3.5" 3.500 NIPPLE,5,734 - Itl i 5,733.7 4,866.5 1.10 NIPPLE X PROFILE NIPPLE 2.813 WIN 5,778.5 4,911.3 1.05 FRAC PORT HALLIBURTON FRAC DOOR(CLOSED 10272012)Opens Down 2.750 FRAC PORT. 778 - 5,820.5 4,953.4 1.00 BLAST RING CARBIDE BLAST RING(LOWER G PERFS 582T-5833)(RINGS 2.992 IPERF. 5624'-5638) 5,827-5,833 FRAC,5,827 m ■ 5,859.9 4,992.8 0.88 SCREEN SELECTA FLOW SCREEN w/2.75"X PROFILE Opens Down 2.750 5,975.0 5,107.8 1.04 PACKER 598-287 PREMIER PACKER ASSEMBLY 2.875 SCREEN.5,860 6,031.8 5,164.6 0.95 FRAC PORT HALLIBURTON FRAC DOOR(CLOSED 10/27/2012) 2.750 S 6,044.0 5,176.8 0.94 BLAST RING CARBIDE BLAST RINGS(UPPER H PERF 6050'-6061)(RINGS 2.992 6047'-6066') PACKER,5,975-- . -- -_' 6,212.6 5,345.4 0.83 BLAST RING CARBIDE BLAST RING(UPPER H PERFS 621T-6233)(RINGS 2.992 6215-6238) FRAC PORT._ M. 6,257.3 5,390.1 1.03 BLAST RING CARBIDE BLAST RINGS(UPPER H PERFS 6262-6270)(RINGS 2.992 6,032 6260'-6275) (PERF, e,osa6,O6t" I I 6,295.1 5,427.8 1.04 SCREEN SELECTA FLOW SCREEN w/2.75"X PROFILE Opens Down 2.750 FRAC,6,050 - I • I 1 I I 6,301.7 5,434.5 1.04 BLAST RING CARBIDE BLAST RING(MID H PERF 6307-6309)(RINGS 6305'-6310) 2.992 6,322.1 5,454.9 1.05 PACKER 698-287 PREMIER PACKER ASSEMBLY 2.875 IPERF, 6,217-6,233 [- _' 6,334.6 5,467.4 1.05 FRAC PORT HALLIBURTON FRAC DOOR(CLOSED 10/27/2012)Opens Down 2.750 FRAC,6,217 11 II I 6,340.3 5,473.1 1.06 BLAST RING CARBIDE BLAST RINGS(MID H PERFS 6347-6361)RINGS 2.992 IPERF. • L _ 1 6344'-6366') 6,2620270 i -.: FRAC,6,262 t _ 6,438.0 5,570.8 1.03 SCREEN SELECTA FLOW SCREEN w/2.75"X PROFILE Opens Down 2.750 [ 6,518.0 5,650.7 0.96 PACKER 598-287 PREMIER PACKER ASSEMBLY#2 2.875 SCREEN,6,295 IPERF, 6,539.7 5,672.4 0.95 FRAC PORT HALLIBURTON FRAC DOOR(CLOSED 10/27/2012)Opens Down 2.750 IiA7c 6,307 s ■ al ■r g ■ 6,551.8 5,684.5 0.95 BLAST RING CARBIDE BLAST RING(LOWER H PERFS 6563'-6571)(RINGS 2.992 f 3558-6576) a ■ 6,583.7 5,716.4 0.93 SCREEN SELECTA FLOW SCREEN w/2.75"X PROFILE Opens Down 2.750 PACKER.6.322 w 6,600.0 5,732.8 0.92 PACKER 598-287 PREMIER PACKER ASSEMBLY#1 2.875 FRAC PORT.6. _ 6,625.9 5,758.6 1.05 SOS BALL SEAT SHEAR SUB FOR 1"OD BALL,5000 PSI+/-SHEAR 3.000 IPERF, a REQUIRED 6,347-6,361 E FRAC,6,347 ■ ■ I Other In Hole [reline retrievable plugs,valves,pumps,fish,etc.) - S Top Depth If (TVD) Top Incl SCREEN.6438 Top MKS) (ftKB) (") Description Comment Run Date ID(1M_ N. =I- 459.0 459.0 -0.21 WRDP CAMCO WRDP(S/N:N12L-1011) 12/10/2012 i i Perforations&Slots PACKER.6,518 -- Shot FRAC PORT, Top(ND) Btm(TVD) Dens 6540Top(MB)131m(RKB) MEI) MKS) Zone Date (ah.,, Type Comment IPERF, 5,827.0 5,833.0 4,959.8 4,965.8 BELUGA G,BRU 8/9/2012 6.0 IPERF 45/8-5SPF Millenium 39gram 6563$571 244-23 FRAC,6,563 • r.4�, ■ 6,050.0 6,061.0 5,182.8 5,193.8 BELUGA H,BRU 8/9/2012 6.0 IPERF 458-5 SPF Millenium 39 gram SCREEN.6.584 244-23 6,217.0 6,233.0 5,349.8 I 5,365.8 BELUGA H,BRU 8/9/2012 6.0 IPERF 45/8-5 SPF Millenium 39 gram PACKER.6600 244-23 SOS,6826 IPERF, Mandrel Details 6,6866,700N ; '41 Top Depth Top Port FRAC,IPERF S (ND) Incl OD Valve Latch Size TRO Run 7.09&7ROF8� I e a , N...Top(ftKB) (RKB) CI Make Model (In) Sery Type Type (In) _ (ps9 Run Date Com... FRAC,7,096 1 = 2' 5,591.1 4,724.0 0.93 CAMCO KBG-2 1 GAS LIFT DMY 0.000 0.0 10272012 PRODUCTION, r J 20.7,542 , ` TD,7,553 *Red is proposed new BRU 244-23 Huck 4-21-2014 equipment Production Well ii Proposed SchematicDrilling P.! &Wells Conductor: 4 i � i ConocoPhillips 20" 165#H-40 @ 107'MD , Camco TRMAXX-5E Safety Valve w/DB Prof.. a ; / @-500'MD w/'/4"control line r i i i Surface Casing: 1 9-5/8",40#, L-80, BTCM i Set @ 3,427'MD/2,790'TVD ; f Top of"Good"Cement above 4,000'MD ACE 8/8/12 i i i . .''; Camco KBMG-LTS CIM @-4,960'MD w/3/8" Lencapsulated injection line Camco MMG GLM @-5,000'MD i - Production Tubing: HES X Nipple with 2.813"profile @ -5,'ou r. ; D Q 3'/z",9.3#, L-80, EUE-8rd 5,060'MD/X,XXX'TVD i Superior CSHP-II Packer @ 5,060'MD i i:::::, Superior MS Cls Sleeve @ 5,099'MD i:li>:< "i;€{ Beluga E Perforations ilii: 5,182'-5,191' .E r :iliiii. Superior 5,177-5,207'MD ,'ilii:. p @ �ilii:.• ::. i ilii:... <: �'' ` Superior 7027 Isolation Packer @ 5,216' MD i.ilii iii:r_--=: ' ii= .,:. :;:s = Superior MS Cls Sleeve @ 5,222'MD .11:18 BIII' IIIiii5i i? Beluga F Perforations F yi p�iii 5,520'-5,527',5,538'-5,548',5,609'-5,631' r,:iii IS Inl 'i ,,:.i, . I� .I _. Superior Screen @ 5,513-5,679'MD iiii ai milli iliits mi's,_ iiii- ,'„.. OR Beluga G Perforations ::-- .ii 5,662'-5,677 , s1' , ''% -``"` Superior CSHP-II Sump Packer @ 5,688'MD i Baker Overshot with Seals @ 5,707'MD over cut 10'pup joint y Premier Packer @ 5,713'MD G Sand Peforations 0 4 Halliburton Frac Door @5,779'MD @ 5,827'-5,833'MD(5 spf) Carbide Blast Rings @ 5,824'-5,833' Frac'd w/140 K lbs 20/40 RCC i i Baker Selecta Flow Screen,2.75"X-Profile,Opens Down @5,860'MD �e: ; Premier Packer @ 5,975'MD H Sand Peforations • Halliburton Frac Door @6,032'MD @ 6,050'-6,061',6,217'-6,233'(5 spf) _ Carbide Blast Rings @ 6,047'-6,066',6,215'-6,238',6,260'-6,275'MD 6,262'-6,270',6,307-6,309'MD Baker Selecta Flow Screen,2.75"X-Profile,Opens Down @6,295'MD Premier Packer @ 6,322'MD, BR 6,305'-6,310'MD H Sand PeforationsI Halliburton Frac Door @6,335'MD @ 6,347'-6,361'MD(5 spf) i I,1 Carbide Blast Rings @ 6,344'-6,366'MD Frac'd w/55 K lbs 20/40 RCC ' LI. I Baker Selecta Flow Screen,2.75"X-Profile,Opens Down @6,438'MD i m Premier Packer @ 6,518'MD H Sand Peforations 0. @ 6,563'-6,571' MD(5 spf) Halliburton Frac Door @6,540'MD Frac'd w/68 K lbs 20/40 RCC , r..- 1 Carbide Blast Rings @ 6,558'-6,576'MD % L• Baker Selecta Flow Screen,2.75"X-Profile,Opens Down @6,584'MD I Sand Peforations 0. - Premier Packer @ 6,600'MD @ 6,686',6,700'MD(6 spf) 0 Frac'd w/92 K lbs 20/40 RCC Tubing tail and SOS @ 6,626'MD I Sand Peforations -sail @ 7,030'-7,042'MD(5 spf) SI 7,096'-7,108'MD(6 spf) Frac'd w/90 K lbs 20/40 RCC Production Casing: 7",26.00#, L-80, BTC-Mod Set @ 7,542'MD/6,675'TVD STATE OF ALASKA DEC 0 7 2012 ALASKA OIL AND GAS CONSERVATION COMm,.,SION GAS WELL OPEN FLOW POTENTIAL TEST REPORT AOGCC la.Test: U Initial U Annual Lf Special lb.Type Test: U Stabilized U Non Stabilized U Multipoint ❑ Constant Time ❑ Isochronal ❑ Other: _ _ 2.Operator Name: 5.Date Completed: 11.Permit to Drill Number: ConocoPhillips Alaska Inc. 8/15/2012 212-069 3.Address: 6.Date TD Reached: 12.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 July 27,2012 50- 283-20165-00-00 4a.Location of Well(Governmental Section): 7.KB Elevation above MSL(feet): 13.Well Name and Number: Surface: 482'FSL,2619'FWL,Sec.23,T13N,R10W,SM 94' BRU 244-23 Top of Productive Horizon: 8.Plug Back Depth(MD+TVD): 14.Field/Pool(s): 661'FSL,586'FEL,Sec.23,T13N,R10W,SM 7458'MD/6591'TVD Beluga River Field Total Depth: 643'FSL,327'FEL,Sec.23,T13N,R1 OW,SM 9.Total Depth(MD+TVD): Sterling-Beluga Gas Pool 7553'MD/6686'ND 4b.Location of Well(State Base Plane Coordinates NAD 27): 10.Land Use Permit: 15.Property Designation: Surface: x- 320636 y- 2630875 Zone-4 n/a ADL-17658 TPI: x- 322713 y- 2631022 Zone-4 16.Type of Completion(Describe): Total Depth: x- 322971 y- 2631000 Zone-4 Cased,Cemented,Perforated,and Frac'ed 17.Casing Size Weight per foot,lb. I.D.in inches Set at ft. 19.Perforations: From To 7" 26 6.276 7541.9 10 intervals from 5827'to 7108'MD 18.Tubing Size Weight per foot,lb. I.D.in inches Set at ft. 4.5" 12.6 3.958 5705.3 20.Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): 5713 N/A N/A 0.559 24a.Producing through: 24b.Reservoir Temp: 24c.Reservoir Pressure: 24d.Barometric Pressure(Pa): Q Tubing ❑ Casing 117 F° 2887 psia @ Datum 5457 TVDSS 12.2 psia 25.Length of Flow Channel(L): Vertical Depth(H): Gg: r %CO2: %N2: %H2S: Prover: Meter Run: Taps: 50 0.565 0.298 0.348 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw F° psig F° psig F° Hr. Size(in.) Size(in.) 1. 3.862 X 1 60 775 60 6 2. 3.862 X 0.84375 54 898 54 6 3. 3.862 X 0.76563 49 1010 49 6 4. 3.862 X 0.73438 47 1102 47 6 5. X Basic Coefficient Flow Temp. Super Comp. No. (24-Hour) hw Pressure Gravity Factor Rate of Flow Pm Factor Fg Q1 Mcfd Fb or Fp Ft 9 Fpv 1. 5100 2. 4600 3. 4300 4. 3700 5. Temperature for Separator for Flowing No. PrT Tr z Gas Fluid Gg G 1. 2. 3. Critical Pressure 4. w Critical Temperature 5. cfcRii_G leN/2A9L RBDriVIS DE__....i. VER E SIDE Submit in Duplicate Pc 2144 pct 459673, p{2 No. Pt Pt2 Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Ps2 Pf-Ps2 1. 775 600625 3996107 867 751689 3845043 2. 898 806404 3790328 990 980100 3616632 3. 1010 1020100 3576632 1102 1214404 3382328 4. 1102 1214404 3382328 1194 1425636 3171096 5. 25. AOF (Mcfd) 7150 n 0.1 Remarks: I hereby certiolo - %e fo 4;, ing is true and correct to the best of my knowledge. Signed �' 4i ___— Title i Date /2 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producin 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= 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 Pt 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. Form 10-421 Revised 7/2009 Side 2 WELL LOG TRANSMITTAL To: State of Alaska November 7, 2012 Alaska Oil and Gas Conservation Commission Attn: Makana Bender 333 W. 7th Ave., #100 Anchorage, AK 99501-3539 RE: MWD Formation Evaluation Logs: BRU 244-23 AK-MW-0009501602 API #: 50-283-20165-00 BRU 244-23 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5" TVDss TRIPLE COMBO Logs: 1 Color Log 2" x 5" MD TRIPLE COMBO+BAT Sonic Logs: 1 Color Log 2" x 5" TVDss TRIPLE COMBO+BAT Sonic Logs: 1 Color Log Digital Log Images & LAS Data; . .1, b S- ) 1 CD Rom PLEASE NOTE: DUE TO SOFTWARE PROBLEMS, WE ARE PROVIDING LAS DATA INSTEAD OF LIS/LDWG FORMATTED DATA. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3539 Fax: 907-273-3535 Buster.Bryant@halliburton.com Date: et P t J 411— Signed: L WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 7, 2012 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: BRU 244-23 Run Date: 10/26/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU 244-23 Digital Data in LAS format, Digital Log, Interpretation Report 1 CD Rom 50-283-20165-00-00 Production Profile (Field Print) 1 Color Log 50-283-20165-00-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com / Date: C t S Signed: ) - � '22_ RECEIVED STATE OF ALASKA 0 C T 19 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND Z CC la.Well Status: Oil ❑ Gas O • SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25 105 20AAC 25 110 Development M• Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name. 5 Date Comp.,Susp., 12 Permit to Drill Number. ConocoPhillips Alaska, Inc.' or Aband• September 22,2012 •212-069/312-328 3.Address: 6.Date Spudded 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 July 13,2012 50-283-20165-00• 4a Location of Well(Governmental Section): 7.Date TD Reached 14.Well Name and Number Surface: • 482'FSL,2619'FWL,Sec.23,T13N, R1OW,SM July 27,2012 BRU 244-23 Top of Productive Horizon: 8. KB(ft above MSL): 94'RKB. 15.Field/Pool(s): 661'FSL,586'FEL,Sec.23,T13N,R1OW,SM GL(ft above MSL): 75.5'AMSL Beluga River Field• Total Depth: 9.Plug Back Depth(MD+ND) 643'FSL,327'FEL,Sec.23,T13N,R1OW,SM 7458'MD/6591'ND; Undefined Gas Pool. 4b.Location of Well(State Base Plane Coordinates,NAD 27) 10.Total Depth(MD+ND): 16 Property Designation: • Surface: x-320635.7 ' y- 2630874.6 • Zone-4, 7553'MD/6686'TVD• ADL 21127, 17658 TPI: x-322713 y- 2631022 Zone-4 11 SSSV Depth(MD+ND) 17 Land Use Permit: Total Depth: x-322971 • y- 2631000• Zone-4• SSSV @ 459'MD/459'ND n/a 18.Directional Survey: Yes ❑� • No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/ND: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) not applicable 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25 071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res,CBL na 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 104# — 18.5' 90' 18.5' 90' na driven 9.625" 40# L-80 23' 3427' 23' 2801' 12.25" 849 sx Class G 7" 26# L-80 21' 7542' 21' 6674' 8.75" 345 sx Class G 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25 TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number) SIZE DEPTH SET(MD) PACKER SET(MD/TVD) • 5827'-5833'MD 4960'-4966'ND 4.5 x 3.5 5680'x 6626' 5 packers total-see attached schematic '6050'-6061'MD 5183'-5194'ND • 6217-6233'MD 5350'-5366'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. •6262'-6270'MD 5395'-5403'ND Was hydraulic fracturing used during completion? Yes n No n • 6307-6309'MD 5440'-5442'ND . DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED '6347-6361'MD 5480'-5494'ND " '"• �;...— 5827'-5833' 140171#of 20/40 RC Ceramic proppant 6563'-6571'MD 5696-5704'ND ' 0.�� 6347'-6361' 54540#of 20/40 RC ceramic proppant •6686-6700'MD 5819'-5833'ND ,,,y� 6563'-6571' 68000#of 20/40 RC Ceramic proppant • 7030'-7042'MD 6163'-6175'ND I_/ • 6686-6700' 91642#of RC Ceramic proppant 7096'-7108'MD 6229'-6241'ND 7030'-7042'and 7096-7108' 90253#of 20/40 RC Ceramic proppant 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) October 12,2012 flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10/12/2012 24 hours Test Period--> na 5629 233 42/64 na Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press 563 psi 770 24-Hour Rate-> na 5629 233 na 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No a • Sidewall Cores Acquired? Yes ❑ No ❑✓ - If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25 071 NONE R8DMS OCT 191011A Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only 28. GEOLOGIC MARKERS(List all formations and marnms encountered) 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface bnefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom not applicable not applicable needed,and submit detailed test information per 20 AAC 25.071. Sterling A 4057' 3249' Sterling B 4261' 3421' Sterling C 4430' 3574' Beluga D 4594' 3730' Beluga E 4862' 3995' Beluga F 5199' 4332' Beluga G 5633' 4766' Beluga H 5959' 5092' Beluga I 6632' 5765' Beluga J 7355' 6488' N/A Formation at total depth: Sterling A 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca @ 263-4180 Email: Hank.Baca(a)conocophillips.com Printed Name Alvord Title: Alaska Drilling Manager Signature "�- Phone 265-6120 Date (0((-1(2`-'(4— INSTRUCTIONS r7(2�/LINSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases 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. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.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. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level 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. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 BRU 244-23 Grassroots Well As Built Completion Schematic 9-17-12 20",Conductor 5",APII 5L GRB, Full vx ? U -� Upper Completion MD TVD Grvd, R3 Driven to Refusal 90' j ', r 1) BP6i SCSSSV w/'A"SS control line 459' 459' Below Pad Grade 6-9-'2 $ 1 1111 1 2) BP6i Inj.Sub w/DCV&3/8"SS control line 5,529' 4,662' 3) 4-'/2"Camco KBG-2 GLM w/DCK-2(2,500 psi) 5,591' 4,724' Cannon Coupling Protectors j ;' ll Tubing clamp protector,over j : r 4)XN Profile, 3.725"ID 5,618' 4,751' coupling type,w/channel for(left to 1 right):0.375"bare line,0.250"bare j ; I i 5) 80-40 GBH-22 Seal Assembly 5,680' 4,813' line. Low carbon steel.25.25"long. % I1 III Lower Completion II f 6) Liner Setting Sleeve, RS Nipple,4"Seal Bore 5,667' 4,800' Surface Casing: I t 9-5/8",40#, L-80, BTC �, 7) 3 1/2"x 7"Premier Production Packer 5,712' 4,845' Set @ 3,426'MD/2,786'TVD % I , y 4 8) X Profile,2.813 ID 5,734' 4,867' TOC+/-3,430'MD/2,804'TVD I l 5I 1 r 9) 3 1/2"Halliburton Frac Door 5,778' 4,911' 1 10) 3 1/2"Carbide Blast Rings 5,824' 4,957' l r C 11) 3 1/2"Selecta Flow Screen w/2.75"X profile 5,860' 4,993' l 12) 3 1/2"x 7"Premier Isolation Packer 5,975' 5,108' r 1 2 13) 3 1/2"Halliburton Frac Door 6,032' 5,165' Production Tubing: :' 4'/2',12.6#, L-80, IBT-M to 5 GL 1 3 14) 3 1/2"Carbide Blast Rings 6,047' 5,180' 5,667'MD/4,800'TVD ., 3'/2",9.3#L-80, IBT-M to - - 4 6,620'MD,5,753'TVD 15) 3 1/2"Carbide Blast Rings 6,215' 5,348' 6 5 7 _ '' i 16) 3 1/2"Carbide Blast Rings 6,260' 5,393' r 8 9 - - G Sand Peforations - :_-_- - - @ 5,827'-5,833'MD(5 spf) / (_-.•_--. r 10 11 r-�. 17) 3 1/2"Selecta Flow Screen w/2.75"X profile 6,295' 5,428' Frac'd w/140 K lbs 20/40 RCC 12 18) 3 1/2"Carbide Blast Rings 6,305' 5,438' j.= 13 IIIIIME- H Sand Peforations - 74 18 r19) 3 1/2"x 7"Premier Isolation Packer 6,322' 5,455' @ 6,050'-6,061',6,217'-6,233'(5 spf) - 6,262'-6,270',6,307-6,309'MD / lw. 18 17 9 M� • 20) 3 1/2"Halliburton Frac Door 6,335' 5,468' _- -i -,_.......- 20 H Sand Peforations 21 - �� 21) 3 1/2"Carbide Blast Rings 6,344' 5,477' @ 6,347'-6,361'MD(5 spf) -•= � 22 -- - Frac'd w/55 K lbs 20/40 RCC 2: 22) 3 1/2"Selecta Flow Screen w/2.75"X profile 6,438' 5,571' on• 24 H Sand Peforations r (•- 25 - .N."-- -\ 23) 3 1/2"x 7"Premier Isolation Packer 6,518 5,651' 6,563'-6,571' MD(5 spf) • � Frac'd w/68 K lbs 20/40 RCC • 27 - 24) 3 1/2"Halliburton Frac Door 6,540' 5,673' B 28 25) 3 1/2"Carbide Blast Rings 6,558' 5,691' I Sand Peforations - -. @ 6,686',6,700'MD(6 spf) p•/;--- �' Fr •ac'd w/92 K lbs 20/40 RCC "-•;_ , __ • 26) 3 1/2"Selecta Flow Screen w/2.75"X profile 6,584' 5,718' I Sand Peforations - 27) 3 1/2"x 7"Premier Isolation Packer 6,600' 5,733' @ 7,030'-7,042'MD(5 spf) (\e.., -- Ems- . 7,096'-7,108'MD(6 spf) _ - Frac'd w/90 K lbs 20/40 RCC 28) 1"SO Ball Seat w/Wireline Entry Guide 6,626' 5,759' Production Casing: 7",26.00#, L-80, BTC-Mod Set @ 7,542'MD/6,675'TVD ill 9 E ConocoPhilli s Alaska Inc. , Beluga River a Beluga River _' BRU 244-23 N NI Nhl 11 IN I NI FN N Sperry Drilling N € Definitive Survey Report i 06 August, 2012 141,� 1: 41 a Uk! i 1 E :! NC g. 4: HALLIBURTON Amimi , 1111111111111111 Sperry Drilling Li iii V vl ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well BRU 244-23 Project: Beluga River TVD Reference: Rig:75.5+18.5 @ 94.00ft(Arctic Fox) Site: Beluga River MD Reference: Rig:75.5+18.5 @ 94.00ft(Arctic Fox) Well: BRU 244-23 North Reference: True Wellbore: BRU 244-23 Survey Calculation Method: Minimum Curvature Design: BRU 244-23 Database: CPAI EDM Production Project Beluga River Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well BRU 244-23 Well Position +N/-S 0.00 ft Northing: 2,630,874.59 ft Latitude: 61°11'49.366 N +EI-W 0.00 ft Easting: 320,635.69ft Longitude: 151°1'0.469 W' Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 75.50ft Wellbore BRU 244-23 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 7/14/2012 17.73 74.05 55,700 Design BRU 244-23 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.50 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (ft) (ft) (ft) (°) 18.50 0.00 0.00 86.35 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 184.66 3,368.02 BRU 244-23(SAG corrected)(BRU 244-MWD+SCC+SAG MWD+Short Collar correction+BHA SAG C7/24/2012 12:C 3,368.02 7,513.83 BRU 244-23(SAG corrected)(BRU 244-MWD+SCC+SAG MWD+Short Collar correction+BHA SAG C7/24/2012 12:C Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 18.50 0.00 0.00 18.50 -75.50 0.00 0.00 2,630,874.59 320,635.69 0.00 0.00 UNDEFINED 184.66 0.26 223.43 184.66 90.66 -0.27 -0.26 2,630,874.32 320,635.42 0.16 -0.28 MWD+SCC+SAG(1) 244.26 0.48 232.72 244.26 150.26 -0.52 -0.55 2,630,874.07 320,635.13 0.38 -0.58 MWD+SCC+SAG(1) 304.93 0.23 261.76 304.93 210.93 -0.69 -0.87 2,630,873.90 320,634.80 0.50 -0.92 MWD+SCC+SAG(1) 366.19 0.41 240.50 366.19 272.19 -0.82 -1.19 2,630,873.78 320,634.49 0.35 -1.24 MWD+SCC+SAG(1) 426.18 0.33 241.50 426.17 332.17 -1.01 -1.52 2,630,873.60 320,634.15 0.13 -1.59 MWD+SCC+SAG(1) 484.91 0.14 201.53 484.90 390.90 -1.16 -1.70 2,630,873.46 320,633.97 0.41 -1.77 MWD+SCC+SAG(1) 546.11 0.97 84.42 546.10 452.10 -1.17 -1.21 2,630,873.43 320,634.46 1.70 -1.28 MWD+SCC+SAG(1) 611.06 2.41 90.48 611.02 517.02 -1.13 0.70 2,630,873.44 320,636.37 2.23 0.63 MWD+SCC+SAG(1) 673.84 4.83 87.11 673.67 579.67 -1.01 4.66 2,630,873.50 320,640.33 3.87 4.59 MWD+SCC+SAG(1) 737.30 7.74 86.55 736.74 642.74 -0.62 11.60 2,630,873.79 320,647.27 4.59 11.53 MWD+SCC+SAG(1) 798.90 9.93 86.21 797.61 703.61 -0.02 21.04 2,630,874.24 320,656.72 3.56 20.99 MWD+SCC+SAG(1) 861.84 10.64 85.76 859.54 765.54 0.77 32.25 2,630,874.85 320,667.94 1.14 32.23 MWD+SCC+SAG(1) 8/6/2012/2:17.:48PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well BRU 244-23 Project Beluga River TVD Reference:, Rig:75.5+18.5 @ 94.00ft(Arctic Fox) Site: Beluga River MD Reference: '' Rig:75.5+18.5 @ 94.00ft(Arctic Fox) Well: BRU 244-23 North Reference: True Wellbore: BRU 244-23 Survey Calculation Method: Minimum Curvature Design: BRU 244-23 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) 0100) (ft) Survey Tool Name 923.99 12.54 87.45 920.42 826.42 1.49 44.71 2,630,875.38 320,680.41 3.11 44.72 MWD+SCC+SAG(1) 986.60 15.41 88.73 981.17 887.17 1.98 59.82 2,630,875.64 320,695.53 4.61 59.83 MWD+SCC+SAG(1) 1,051.00 18.75 88.84 1,042.72 948.72 2.38 78.73 2,630,875.74 320,714.44 5.19 78.72 MWD+SCC+SAG(1) 1,085.83 19.76 87.90 1,075.60 981.60 2.71 90.21 2,630,875.89 320,725.92 3.03 90.20 MWD+SCC+SAG(1) 1,111.92 20.47 87.19 1,100.10 1,006.10 3.10 99.17 2,630,876.14 320,734.89 2.88 99.17 MWD+SCC+SAG(1) 1,177.90 22.10 85.74 1,161.58 1,067.58 4.58 123.08 2,630,877.25 320,758.81 2.60 123.12 MWD+SCC+SAG(1) 1,241.26 22.22 88.35 1,220.26 1,126.26 5.81 146.94 2,630,878.11 320,782.69 1.57 147.01 MWD+SCC+SAG(1) 1,305.43 25.27 87.38 1,278.99 1,184.99 6.79 172.75 2,630,878.69 320,808.52 4.79 172.84 MWD+SCC+SAG(1) 1,340.16 27.38 87.48 1,310.12 1,216.12 7.48 188.14 2,630,879.14 320,823.91 6.08 188.23 MWD+SCC+SAG(1) 1,368.08 29.07 87.29 1,334.71 1,240.71 8.08 201.33 2,630,879.54 320,837.11 6.06 201.44 MWD+SCC+SAG(1) 1,400.46 31.64 87.62 1,362.65 1,268.65 8.81 217.68 2,630,880.01 320,853.46 7.95 217.80 MWD+SCC+SAG(1) 1,430.94 34.03 87.75 1,388.26 1,294.26 9.47 234.19 2,630,880.42 320,869.98 7.84 234.32 MWD+SCC+SAG(1) 1,462.15 35.80 87.58 1,413.85 1,319.85 10.20 252.04 2,630,880.87 320,887.84 5.68 252.17 MWD+SCC+SAG(1) 1,493.28 37.34 87.31 1,438.85 1,344.85 11.03 270.56 2,630,881.41 320,906.37 4.97 270.72 MWD+SCC+SAG(1) 1,559.48 39.48 86.23 1,490.72 1,396.72 13.36 311.62 2,630,883.09 320,947.46 3.39 311.84 MWD+SCC+SAG(1) 1,621.29 41.22 84.76 1,537.83 1,443.83 16.51 351.51 2,630,885.62 320,987.39 3.21 351.85 MWD+SCC+SAG(1) 1,682.47 43.35 83.82 1,583.09 1,489.09 20.61 392.47 2,630,889.09 321,028.41 3.63 392.99 MWD+SCC+SAG(1) 1,746.14 46.03 84.90 1,628.35 1,534.35 25.00 437.03 2,630,892.79 321,073.02 4.37 437.73 MWD+SCC+SAG(1) 1,808.62 45.62 85.05 1,671.89 1,577.89 28.93 481.66 2,630,896.02 321,117.71 0.68 482.53 MWD+SCC+SAG(1) 1,871.11 45.80 85.54 1,715.53 1,621.53 32.59 526.25 2,630,898.99 321,162.34 0.63 527.25 MWD+SCC+SAG(1) 1,934.36 48.72 85.66 1,758.45 1,664.45 36.16 572.56 2,630,901.83 321,208.70 4.62 573.70 MWD+SCC+SAG(1) 1,996.44 49.57 85.67 1,799.06 1,705.06 39.71 619.38 2,630,904.65 321,255.57 1.37 620.65 MWD+SCC+SAG(1) 2,058.45 49.30 85.57 1,839.38 1,745.38 43.30 666.35 2,630,907.52 321,302.58 0.45 667.75 MWD+SCC+SAG(1) 2,122.52 48.90 84.55 1,881.33 1,787.33 47.47 714.59 2,630,910.94 321,350.89 1.36 716.17 MWD+SCC+SAG(1) 2,185.49 48.40 84.57 1,922.93 1,828.93 51.95 761.65 2,630,914.69 321,398.01 0.79 763.41 MWD+SCC+SAG(1) 2,248.16 47.52 83.09 1,964.90 1,870.90 56.95 807.92 2,630,918.96 321,444.35 2.25 809.91 MWD+SCC+SAG(1) 2,313.08 46.72 82.71 2,009.08 1,915.08 62.83 855.13 2,630,924.11 321,491.64 1.30 857.39 MWD+SCC+SAG(1) 2,374.10 46.80 82.15 2,050.88 1,956.88 68.69 899.19 2,630,929.28 321,535.78 0.68 901.74 MWD+SCC+SAG(1) 2,437.39 46.44 83.56 2,094.35 2,000.35 74.41 944.83 2,630,934.29 321,581.50 1.72 947.65 MWD+SCC+SAG(1) 2,500.59 45.31 84.42 2,138.35 2,044.35 79.16 989.95 2,630,938.34 321,626.69 2.04 992.98 MWD+SCC+SAG(1) 2,563.76 45.77 84.91 2,182.60 2,088.60 83.35 1,034.84 2,630,941.83 321,671.63 0.91 1,038.05 MWD+SCC+SAG(1) 2,627.34 45.94 84.41 2,226.88 2,132.88 87.60 1,080.27 2,630,945.37 321,717.12 0.62 1,083.65 MWD+SCC+SAG(1) 2,690.09 45.57 84.31 2,270.66 2,176.66 92.02 1,125.00 2,630,949.09 321,761.91 0.60 1,128.58 MWD+SCC+SAG(1) 2,752.36 45.19 84.30 2,314.40 2,220.40 96.42 1,169.10 2,630,952.80 321,806.08 0.61 1,172.87 MWD+SCC+SAG(1) 2,814.57 44.59 84.71 2,358.47 2,264.47 100.62 1,212.81 2,630,956.33 321,849.83 1.07 1,216.75 MWD+SCC+SAG(1) 2,876.80 45.30 84.69 2,402.52 2,308.52 104.68 1,256.58 2,630,959.71 321,893.66 1.14 1,260.69 MWD+SCC+SAG(1) 2,939.47 45.78 85.08 2,446.41 2,352.41 108.67 1,301.13 2,630,963.00 321,938.27 0.89 1,305.41 MWD+SCC+SAG(1) 3,002.47 45.83 84.97 2,490.33 2,396.33 112.59 1,346.13 2,630,966.22 321,983.32 0.15 1,350.57 MWD+SCC+SAG(1) 3,064.42 45.88 85.11 2,533.48 2,439.48 116.43 1,390.42 2,630,969.37 322,027.66 0.18 1,395.01 MWD+SCC+SAG(1) 3,127.20 45.36 85.21 2,577.38 2,483.38 120.22 1,435.13 2,630,972.46 322,072.42 0.84 1,439.87 MWD+SCC+SAG(1) 8/6/2012 12.17:48PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well BRU 244-23 Project: Beluga River TVD Reference: Rig:75.5+18.5 @ 94.00ft(Arctic Fox) Site: Beluga River MD Reference: Rig:75.5+18.5 @ 94.00ft(Arctic Fox) Well: BRU 244-23 North Reference: True Wellbore: BRU 244-23 Survey Calculation Method: Minimum Curvature Design: BRU 244-23 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,191.77 45.32 85.59 2,622.77 2,528.77 123.90 1,480.91 2,630,975.43 322,118.25 0.42 1,485.79 MWD+SCC+SAG(1) 3,255.01 44.01 85.65 2,667.75 2,573.75 127.29 1,525.23 2,630,978.14 322,162.62 2.07 1,530.24 MWD+SCC+SAG(1) 3,317.71 44.59 85.30 2,712.62 2,618.62 130.75 1,568.89 2,630,980.91 322,206.32 1.00 1,574.02 MWD+SCC+SAG(1) 3,368.02 45.14 85.84 2,748.28 2,654.28 133.49 1,604.27 2,630,983.10 322,241.74 1.33 1,609.51 MWD+SCC+SAG(1) 3,459.37 45.43 84.45 2,812.55 2,718.55 138.99 1,668.95 2,630,987.59 322,306.49 1.13 1,674.41 MWD+SCC+SAG(2) 3,518.31 45.11 84.25 2,854.03 2,760.03 143.11 1,710.62 2,630,991.07 322,348.21 0.59 1,716.26 MWD+SCC+SAG(2) 3,586.01 44.69 84.02 2,901.99 2,807.99 147.99 1,758.15 2,630,995.21 322,395.82 0.67 1,764.01 MWD+SCC+SAG(2) 3,648.47 44.15 84.35 2,946.60 2,852.60 152.42 1,801.65 2,630,998.96 322,439.37 0.94 1,807.69 MWD+SCC+SAG(2) 3,711.63 43.78 84.15 2,992.06 2,898.06 156.81 1,845.27 2,631,002.68 322,483.06 0.63 1,851.51 MWD+SCC+SAG(2) 3,772.38 43.51 84.09 3,036.02 2,942.02 161.11 1,886.98 2,631,006.32 322,524.82 0.45 1,893.41 MWD+SCC+SAG(2) 3,835.68 43.36 84.17 3,081.99 2,987.99 165.56 1,930.27 2,631,010.10 322,568.18 0.25 1,936.89 MWD+SCC+SAG(2) 3,898.09 43.28 84.50 3,127.39 3,033.39 169.79 1,972.88 2,631,013.66 322,610.84 0.38 1,979.69 MWD+SCC+SAG(2) 3,963.29 41.28 84.67 3,175.63 3,081.63 173.93 2,016.55 2,631,017.12 322,654.57 3.07 2,023.53 MWD+SCC+SAG(2) 3,991.40 39.73 84.65 3,197.00 3,103.00 175.63 2,034.72 2,631,018.54 322,672.77 5.51 2,041.78 MWD+SCC+SAG(2) 4,022.89 38.06 84.30 3,221.51 3,127.51 177.53 2,054.40 2,631,020.14 322,692.47 5.35 2,061.54 MWD+SCC+SAG(2) 4,055.74 36.75 84.36 3,247.60 3,153.60 179.50 2,074.26 2,631,021.80 322,712.36 3.99 2,081.48 MWD+SCC+SAG(2) 4,087.49 34.85 84.10 3,273.35 3,179.35 181.37 2,092.74 2,631,023.38 322,730.86 6.00 2,100.04 MWD+SCC+SAG(2) 4,117.29 34.04 83.75 3,297.93 3,203.93 183.15 2,109.50 2,631,024.90 322,747.65 2.80 2,116.88 MWD+SCC+SAG(2) 4,151.31 32.22 83.77 3,326.42 3,232.42 185.17 2,127.98 2,631,026.63 322,766.16 5.35 2,135.45 MWD+SCC+SAG(2) 4,183.81 31.31 83.80 3,354.05 3,260.05 187.02 2,144.99 2,631,028.22 322,783.19 2.80 2,152.54 MWD+SCC+SAG(2) 4,212.27 30.96 83.76 3,378.41 3,284.41 188.62 2,159.62 2,631,029.59 322,797.84 1.23 2,167.24 MWD+SCC+SAG(2) 4,277.73 28.02 84.29 3,435.38 3,341.38 191.98 2,191.66 2,631,032.45 322,829.93 4.51 2,199.44 MWD+SCC+SAG(2) 4,339.47 25.20 84.84 3,490.58 3,396.58 194.60 2,219.19 2,631,034.64 322,857.49 4.58 2,227.07 MWD+SCC+SAG(2) 4,402.05 22.33 83.48 3,547.84 3,453.84 197.15 2,244.27 2,631,036.80 322,882.61 4.67 2,252.27 MWD+SCC+SAG(2) 4,461.15 19.94 82.47 3,602.96 3,508.96 199.75 2,265.42 2,631,039.07 322,903.80 4.09 2,273.54 MWD+SCC+SAG(2) 4,527.35 17.19 82.71 3,665.71 3,571.71 202.47 2,286.32 2,631,041.46 322,924.74 4.16 2,294.57 MWD+SCC+SAG(2) 4,589.56 14.16 84.42 3,725.60 3,631.60 204.38 2,303.02 2,631,043.11 322,941.46 4.93 2,311.35 MWD+SCC+SAG(2) 4,652.24 11.53 85.48 3,786.71 3,692.71 205.62 2,316.90 2,631,044.13 322,955.35 4.21 2,325.28 MWD+SCC+SAG(2) 4,683.80 10.05 84.61 3,817.71 3,723.71 206.12 2,322.78 2,631,044.55 322,961.25 4.72 2,331.19 MWD+SCC+SAG(2) 4,715.41 8.28 83.50 3,848.92 3,754.92 206.64 2,327.79 2,631,044.99 322,966.26 5.63 2,336.22 MWD+SCC+SAG(2) 4,747.94 6.60 82.31 3,881.17 3,787.17 207.15 2,331.97 2,631,045.44 322,970.45 5.19 2,340.42 MWD+SCC+SAG(2) 4,779.29 4.91 84.97 3,912.36 3,818.36 207.51 2,335.09 2,631,045.75 322,973.58 5.46 2,343.56 MWD+SCC+SAG(2) 4,811.09 3.03 92.31 3,944.08 3,850.08 207.60 2,337.29 2,631,045.80 322,975.77 6.11 2,345.76 MWD+SCC+SAG(2) 4,841.72 1.57 107.71 3,974.69 3,880.69 207.44 2,338.50 2,631,045.62 322,976.98 5.13 2,346.95 MWD+SCC+SAG(2) 4,873.62 0.92 173.16' 4,006.58 3,912.58 207.05 2,338.94 2,631,045.23 322,977.42 4.55 2,347.38 MWD+SCC+SAG(2) 4,905.69 0.73 189.45 4,038.65 3,944.65 206.59 2,338.94 2,631,044.77 322,977.41 0.94 2,347.34 MWD+SCC+SAG(2) 4,969.34 0.85 190.95 4,102.29 4,008.29 205.73 2,338.78 2,631,043.91 322,977.24 0.19 2,347.13 MWD+SCC+SAG(2) 5,032.69 0.83 180.93 4,165.64 4,071.64 204.81 2,338.69 2,631,042.99 322,977.13 0.23 2,346.98 MWD+SCC+SAG(2) 5,095.53 0.97 174.64 4,228.47 4,134.47 203.83 2,338.73 2,631,042.01 322,977.15 0.27 2,346.96 MWD+SCC+SAG(2) 5,157.97 0.88 184.88 4,290.90 4,196.90 202.82 2,338.74 2,631,041.00 322,977.15 0.30 2,346.90 MWD+SCC+SAG(2) 8/6/2012 12:17:48PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well BRU 244-23 Project: Beluga River TVD Reference: Rig:75.5+18.5 @ 94.00ft(Arctic Fox) Site: Beluga River MD Reference: Rig:75.5+18.5 @ 94.00ft(Arctic Fox) Well: BRU 244-23 North Reference: True Wellbore: BRU 244-23 Survey Calculation Method: Minimum Curvature Design: BRU 244-23 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,220.92 0.93 184.21 4,353.84 4,259.84 201.83 2,338.66 2,631,040.01 322,977.05 0.08 2,346.76 MWD+SCC+SAG(2) 5,283.02 0.96 180.80 4,415.93 4,321.93 200.81 2,338.61 2,631,038.99 322,976.99 0.10 2,346.65 MWD+SCC+SAG(2) 5,348.79 0.91 177.32 4,481.70 4,387.70 199.74 2,338.63 2,631,037.92 322,976.99 0.12 2,346.60 MWD+SCC+SAG(2) 5,411.62 0.97 178.38 4,544.52 4,450.52 198.71 2,338.67 2,631,036.89 322,977.02 0.10 2,346.57 MWD+SCC+SAG(2) 5,474.04 0.84 192.81 4,606.93 4,512.93 197.73 2,338.58 2,631,035.91 322,976.91 0.42 2,346.42 MWD+SCC+SAG(2) 5,538.13 0.91 186.10 4,671.01 4,577.01 196.77 2,338.42 2,631,034.95 322,976.74 0.19 2,346.21 MWD+SCC+SAG(2) 5,600.10 0.93 189.75 4,732.97 4,638.97 195.78 2,338.29 2,631,033.97 322,976.59 0.10 2,346.01 MWD+SCC+SAG(2) 5,662.49 0.95 180.12 4,795.36 4,701.36 194.77 2,338.20 2,631,032.96 322,976.49 0.25 2,345.85 MWD+SCC+SAG(2) 5,724.41 0.98 188.35 4,857.27 4,763.27 193.73 2,338.12 2,631,031.92 322,976.39 0.23 2,345.71 MWD+SCC+SAG(2) 5,786.71 1.04 179.90 4,919.56 4,825.56 192.64 2,338.05 2,631,030.83 322,976.30 0.26 2,345.56 MWD+SCC+SAG(2) 5,849.89 0.97 172.60 4,982.73 4,888.73 191.53 2,338.12 2,631,029.72 322,976.35 0.23 2,345.56 MWD+SCC+SAG(2) 5,912.96 0.95 175.61 5,045.79 4,951.79 190.48 2,338.23 2,631,028.67 322,976.44 0.09 2,345.61 MWD+SCC+SAG(2) 5,977.81 1.04 177.26 5,110.63 5,016.63 189.36 2,338.29 2,631,027.55 322,976.50 0.15 2,345.60 MWD+SCC+SAG(2) 6,040.45 0.94 175.51 5,173.26 5,079.26 188.28 2,338.36 2,631,026.47 322,976.55 0.17 2,345.60 MWD+SCC+SAG(2) 6,102.85 0.90 193.14 5,235.65 5,141.65 187.29 2,338.29 2,631,025.48 322,976.46 0.46 2,345.47 MWD+SCC+SAG(2) 6,166.00 0.83 180.80 5,298.79 5,204.79 186.35 2,338.17 2,631,024.54 322,976.33 0.31 2,345.29 MWD+SCC+SAG(2) 6,228.49 0.83 179.87 5,361.28 5,267.28 185.44 2,338.17 2,631,023.64 322,976.31 0.02 2,345.23 MWD+SCC+SAG(2) 6,292.77 1.04 175.99 5,425.55 5,331.55 184.40 2,338.21 2,631,022.59 322,976.33 0.34 2,345.20 MWD+SCC+SAG(2) 6,355.33 1.06 180.61 5,488.10 5,394.10 183.25 2,338.24 2,631,021.44 322,976.35 0.14 2,345.16 MWD+SCC+SAG(2) 6,419.27 1.00 190.92 5,552.03 5,458.03 182.11 2,338.13 2,631,020.31 322,976.22 0.30 2,344.98 MWD+SCC+SAG(2) 6,480.08 1.11 186.42 5,612.83 5,518.83 181.01 2,337.96 2,631,019.20 322,976.03 0.23 2,344.74 MWD+SCC+SAG(2) 6,543.52 0.95 195.22 5,676.26 5,582.26 179.89 2,337.76 2,631,018.09 322,975.81 0.35 2,344.46 MWD+SCC+SAG(2) 6,606.01 0.92 190.97 5,738.74 5,644.74 178.90 2,337.52 2,631,017.10 322,975.56 0.12 2,344.17 MWD+SCC+SAG(2) 6,668.56 0.99 189.04 5,801.28 5,707.28 177.87 2,337.34 2,631,016.08 322,975.37 0.12 2,343.92 MWD+SCC+SAG(2) 6,731.77 0.90 200.89 5,864.48 5,770.48 176.87 2,337.08 2,631,015.08 322,975.09 0.34 2,343.60 MWD+SCC+SAG(2) 6,794.48 0.88 194.62 5,927.18 5,833.18 175.94 2,336.78 2,631,014.16 322,974.78 0.16 2,343.24 MWD+SCC+SAG(2) 6,857.18 1.06 196.55 5,989.88 5,895.88 174.92 2,336.50 2,631,013.14 322,974.47 0.29 2,342.89 MWD+SCC+SAG(2) 6,921.12 1.02 204.77 6,053.81 5,959.81 173.83 2,336.09 2,631,012.06 322,974.05 0.24 2,342.42 MWD+SCC+SAG(2) 6,984.25 0.99 203.47 6,116.93 6,022.93 172.82 2,335.64 2,631,011.06 322,973.58 0.06 2,341.90 MWD+SCC+SAG(2) 7,046.96 1.08 197.22 6,179.63 6,085.63 171.76 2,335.25 2,631,010.00 322,973.18 0.23 2,341.44 MWD+SCC+SAG(2) 7,110.80 1.06 190.80 6,243.45 6,149.45 170.61 2,334.96 2,631,008.85 322,972.87 0.19 2,341.08 MWD+SCC+SAG(2) 7,171.45 0.94 194.12 6,304.09 6,210.09 169.57 2,334.73 2,631,007.82 322,972.63 0.22 2,340.79 MWD+SCC+SAG(2) 7,236.00 1.21 187.11 6,368.63 6,274.63 168.38 2,334.52 2,631,006.64 322,972.39 0.46 2,340.50 MWD+SCC+SAG(2) 7,297.54 1.22 183.29 6,430.16 6,336.16 167.09 2,334.40 2,631,005.34 322,972.26 0.13 2,340.30 MWD+SCC+SAG(2) 7,361.72 1.23 187.32 6,494.33 6,400.33 165.72 2,334.27 2,631,003.98 322,972.11 0.14 2,340.09 MWD+SCC+SAG(2) 7,425.08 1.18 193.40 6,557.67 6,463.67 164.41 2,334.04 2,631,002.67 322,971.85 0.22 2,339.77 MWD+SCC+SAG(2) 7,486.86 1.19 190.50 6,619.44 6,525.44 163.16 2,333.77 2,631,001.43 322,971.57 0.10 2,339.42 MWD+SCC+SAG(2) 7,513.83 1.15 192.45 6,646.40 6,552.40 162.62 2,333.66 2,631,000.89 322,971.45 0.21 2,339.28 MWD+SCC+SAG(2) 7,553.00 1.15 192.45 6,685.56 6,591.56 161.85 2,333.49 2,631,000.12 322,971.27 0.00 2,339.06 PROJECTED to TD 8/6/2012 12.17:48PM Page 5 COMPASS 2003.16 Build 69 _ ` Time Log & Summary Conoco )hillips Wellview Web Reporting Report Well Name: BRU 244-23 Rig Name: DOYON ARCTIC FOX Job Type: DRILLING ORIGINAL Rig Accept: 7/13/2012 12:00:00 AM Rig Release: 8/4/2012 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/08/2012 24 hr Summary. Finish NU and test dry hole tree. Secure the well. Prepare the rig for move. Move pipeshed, beaverslide to J-Pad. Disconnect electrical, steam, hydraulic,water lines from modules. Lay down derrick. 00:00 03:30 3.50 0 0 MIRU MOVE RURD P Complete nipple up dry hole tree. Test flange to 500 PSI low 10 mins, • 5000 PSI high 10 mins.Verified by Company Man. Pull BPV. Install TWC. Body test on dry hole tree. Test to 500 PSI low 10 mins,5000 PSI, high 10 mins.Charted. Pull TWC. Install BPV.Secure well. SIMOPS: Rig down steam interconnect lines between modules. 03:30 06:00 2.50 0 0 MIRU MOVE RURD P Blow down water lines,continue to disconnect steam lines, install support beams in cellar on sub. Prepare wind walls for removal. 06:00 12:00 6.00 0 0 MIRU MOVE RURD P PJSM. Demob pipeshed,and move to J=Pad. Remove beaver slide, disconnect electrical from pits,top drive, remove drilling line spool house with crane,demob top drive and remove with crane,empty#1 boiler, hotwell,water tank, off load 1600 gallons to diesel to fuel truck. 12:00 18:00 6.00 0 0 MIRU MOVE RURD P Prepare rig for move: Lay down torque tube, briddle up blocks, prepare derrick to scope down. Scope down the derrick. Remove draw works wind walls, and roof rafters with crane, Remove roof plates and windwalls around pits, dresser sleeves, rig down motor, pits, pumps modules. 18:00 00:00 6.00 0 0 MIRU MOVE RURD P Secure blocks,and unstring, prepare to lay down the derrick, rig down the rig floor,drillers console,dress the monkey board,pull communication cables, prepare the derrick for being laid down. Lower derrick to stands. Crew change. 07/09/2012 Rig down and move off of C-Pad,and move entire fleet of Arctic Fox modules to J-Pad. Page 1 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 0 0 MIRU MOVE MOB P !PJSM.Telescope down dog house. Prepare for lowering.Clean containment under sub.Tie back tugger lines,cement hose,kelly hose in derrick, remove all lights on skids,prepare all skids for rig move. Remove pins on derrick rams,draw work skid, and ppony sub. 06:00 12:00 6.00 0 0 MIRU MOVE MOB P Remove wind walls on sub, remove stairs, lower dog house into water tank.Move boiler room,motor room, pump room to J-Pad.Weld hand rails on rig floor, remove derrick from sub, _move water tank to J-Pad. 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Remove draw works skid from sub, remove sub from pony sub, move pit complex's, remove shakers from pits, monkey board from derrick, load out wind walls,sub, pony sub, rig mats, suttings box. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Set felt down in foot print,set herculite on top of felt. Set rig mats with crane on foot print.Set pony subs over cellar. SIMOPS: Prepare derrick board, and wind walls for paint at D-Pad. 07/10/2012 Set felt down in foot print,set herculite on top of felt,set upper sub,draw works,derrick,water tank and dog house,set pits, install shakers,set motor units,pump houses, raise derrick, lay mats for pipe houses, start installing wind walls on pits, hook up service lines. 00:00 12:00 12.00 '0 0 MIRU MOVE RURD P Set felt down in foot print,set herculite on top of felt,set upper sub, draw works,derrick,water tank and dog house, 12:00 00:00 12.00 0 0 MIRU MOVE RURD P set pits, install shakers,set motor units, pump houses, raise derrick, lay mats for pipe houses, start installing wind walls on pits, hook up service lines. 07/11/2012 Rigging up-Hook up drive shaft to rotary, raise stacks on engines, prep derric for scoping, hook up electrical lines, install auger,set poor boy gass buster,shop,cuttings tank,pipe houses,break shack, hang torque tube for top drive. 00:00 12:00 12.00 0 MIRU MOVE RURD P Bolt up rotary drive shaft, raise all stacks on skids,splice drilling line, prep derrick for scoping,finish installing wind walls on pits, install flow line, hook up electrical cables, spot auger on shaker skid, rig up poor boy degasser,skate skid, centrifuge house,service line reel house for TD,generator house,and pished buildings. Page 2 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 MIRU MOVE RURD P Continue R/U pipe sheds,string blocks,scope derrick, hook up mud lines in pits&pump room,spot torque tub&TD equipment,set shop, hang torque tube,set TD on floor w/crane,connect TD to blocks, set cuttings tank,spot break shack, set mechanics shop, relocate stairs on Co.Mans unit,clean&organise yard 07/12/2012 Install TD in derrick and hook up service lines to TD, install roof panels over draw works, install diverter line, hook up hydraulics to hydril and knife valve&function test,change liners in pump#3 to 6", put water in pits and function test surface system, prep rig floor F/picking up drill pipe, load 110 jts drill pipe in pipe shed 00:00 06:00 6.00 0 0 MIRU MOVE RURD P Install TD torque tube sleeve,pin TD to sleeve„center TD,rig up stand pipe manifold, N/U diverter bag,spot MWD&dd Shack 06:00 12:00 6.00 0 0 MIRU MOVE RURD P N/U knife valve,and diverter line, remove TD cradle F/rig floor, install draw works covers, hook up service lines to TD,and VFD unit. 12:00 18:00 6.00 0 MIRU MOVE RURD P Rig up koomey lines to diverter& function test, hook up hydrulics to pipe shed, R/u TD hoisting equipment, R/U rig floor,change liners in MP#3 T/6",set viro vac unit, R/u totco mud watch system 18:00 00:00 6.00 MIRU MOVE RURD P Hook up instraments on rig, rig up cement manifold,fill pits W/water, function test all surface equipment, clean and orginaze rig floor To P/U drill pipe, load 110 jts drill pipe in pipe house, perform derrick inspection, hook up jeronemo line 07/13/2012 FIll pits with water,test surface system to 2500 PSI, Finish changing liners in#3 pump, rig up and pick up 110 jts drill pipe&HWDP and stand back,Mix spud mud,test diverter system, Pre spud meeting W/Co Rep, key rig personnel,finish mixing spud mud,Spud well @ 22:00 hrs,drill to 64',trouble shoot top drive blower motor, Drill to 96' 00:00 06:00 6.00 0 0 SURFA( DRILL OTHR P FIll pits with water,test surface system to 2500 PSI, Finish changing liners in#3 pump 06:00 12:00 6.00 0 0 SURFA( DRILL PULD P R/U spinner hawks, P/U 110 jts drill pipe and stand back,start mixing 500 bbls spud mud 12:00 13:00 1.00 0 0 SURFA( DRILL PULD P Pick up 12 jts 5"heavy weight drill pipe,continue mixing mud 13:00 13:30 0.50 0 0 SURFA( DRILL PULD P work on LID machine,bring drilling subs to rig floor 13:30 14:30 1.00 0 0 SURFA( DRILL PULD P Finish picking up HWDP 14:30 16:30 2.00 0 0 SURFA( DRILL OTHR P Get RKB,caliber subs and xo's, B/D smart tools F/Halliburton, install drip pan, remove brackets F/derrick 16:30 17:00 0.50 0 0 SURFA( DRILL PULD P P/U 1 std heavy weight drill pipe f/derrick, M/U XO, bit sub and bit. Page 3 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 20:30 3.50 0 0 SURFA( DRILL OTHR P Dress shakers,finish installing drip pan, load pipe shed with BHA& smart tools, 20:30 21:00 0.50 0 0 SURFA( DRILL BOPE P Function testdiverter system, closing time F/annular 45 sec,full charge 170 sec,function test flow show&pit sensers, H2S&gas sensors calibrated, Witness of Diverter test waived by AOGCC Rep Chuck Scheve. 21:00 22:00 1.00 0 0 SURFA( DRILL SFTY P Pre spud meeting W/Co Rep, key rig personnel,finish mixing spud mud 22:00 23:00 1.00 0 64 SURFA( DRILL DRLG P Spud well Drill T/64' 23:00 23:30 0.50 64 64 SURFA( DRILL RGRP T Trouble shoot top drive issuses (blower motor not running on TD) 23:30 00:00 0.50 64 96 SURFA( DRILL DRLG P Rotate and drill F/64'T/96' 07/14/2012 Drill 12 1/4"hole with bit and HWDP from 96'to 216',Trip out of hole and P/U directional BHA,trip in hole to 193',Wash down from 193'to 216'. (6'of fill), Drill 12 1/4"directional hole with motor from 216' to 371',flow line packed off,set back std and clean out flow line, rotate and slide F/371 T/615-244'@ 48.8 ft/hr,while trouble shooting problems with pumps 2&3 pump motors,circulate hole clean,stand 1 std back,and change saver sub on top drive and elevators to 4", rotate and slide F/615'T/994-379'@ 94.75 ft/hr 00:00 01:45 1.75 96 216 SURFA( DRILL DRLG P Drill 12 1/4"hole with bit and HWDP from 96'to 216' 01:45 03:00 1.25 216 96 SURFA( DRILL TRIP P PJSM. POH to 96'. PU jars and stand back in derrick. 03:00 03:45 0.75 96 0 SURFA( DRILL PULD P LD bit,bit sub and XO.Calibrate block height. 03:45 07:00 3.25 0 100 SURFA( DRILL PULD P MU BHA#2.Orient MWD to motor. 07:00 08:00 1.00 100 100 SURFA( DRILL OTHR P Upload MWD. 08:00 09:00 1.00 100 193 SURFA( DRILL PULD P PU and RIH with 3 NMFC and XO. 09:00 09:30 0.50 193 216 SURFA( DRILL WASH P Wash down from 193'to 216'. (6'of fill) 09:30 12:00 2.50 216 371 SURFA( DRILL DDRL P Drill 12 1/4"directional hole with motor from 216' to 371', PR 425 GPM,80 RPM,2k WOB, 870 PSI. P/U Wt=47k,5/0 Wt=47k, Rot Wt=47k.AST=0,ART=1.54, ADT=1.54,Jar hrs=76.88 12:00 12:30 0.50 371 371 SURFA( DRILL DDRL P Stand back stand HWDP, pick stand w/jars&RIH T/371' 12:30 13:30 1.00 371 371 SURFA( DRILL DDRL P Attempt to drill F/371',flow line packed off,set back std and clean out flow line. 13:30 18:30 5.00 371 615 SURFA( DRILL DDRL P Rotate and slide F/371 T/615-244' @ 48.8 ft/hr,while trouble shooting problems with pumps 2&3 pump motors 18:30 20:00 1.50 615 615 SURFA( DRILL CIRC P Circulate hole clean,stand 1 std back, and change saver sub on top drive and elevators to 4" 20:00 00:00 4.00 615 994 SURFA( DRILL DDRL P Rotate and slide F/615'T/994-379' @ 94.75 ft/hr Page 4 of 22 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 07/15/2012 24 hr Summary Drill 12 1/4"directional hole with motor from 994' to 1241',CBU X4. Flow check well.Static, PJSM. POH on elevators from 1244'to 617',flow check well. Static. RIH,drill from 1241' to 1497',(Note: Hole becoming sticky on backreams. Increase mud wt to 9.0 ppg.),drill F/1497 T/2128', 00:00 03:00 3.00 994 1,244 SURFA( DRILL DDRL P Drill 12 1/4"directional hole with motor from 994' to 1241', PR 530 GPM,80 RPM, 2-10k WOB, 1320 PSI. P/U Wt=80k,S/O Wt=62k, Rot Wt=70k.AST=.62,ART=.33, ADT=.95 03:00 04:15 1.25 1,244 1,244 SURFA( DRILL CIRC P CBU X4. Flow check well.Static. 04:15 05:15 1.00 1,244 617 SURFA( DRILL WPRT P PJSM. POH on elevators from 1244' to 617'. 05:15 06:15 1.00 617 194 SURFA( DRILL WPRT P Change to 5"elevators. POH to top of NMFC's at 194'. Flow check well. Static. 06:15 08:15 2.00 194 1,244 SURFA( DRILL WPRT P Flow check well.Static. RIH with HWDP to 617'.Change elevators to 4". RIH to 928'.Take rotational check shot. RIH to 1181'. Fill pipe and wash to 1244'. 08:15 12:00 3.75 1,244 1,497 SURFA( DRILL DDRL P Drill 12 1/4"directional hole with motor from 1241' to 1497', PR 530 GPM,80 RPM,2-10k WOB, 1320 PSI. P/U Wt=80k,5/0 Wt=62k, Rot Wt=70k.AST=.79,ART=.24, ADT=1.03, hrs on jars=81.73 Note: Hole becoming sticky on backreams. Increase mud wt to 9.0 PP9. 12:00 00:00 12.00 1,497 2,128 SURFA( DRILL DDRL P Drill F/1497 T/2128',gpm 523, 80 rpm, 5/15 wob, 1486 psi, p/u 82,s/o 52, rot wt 68, AST 4.49,ART 10.49 07/16/2012 Rotate and slide f/2128 t/2315', circulate B/U,trip out of hole F/2315 T/1244',flow check well,trip in hole to 2252,wash and ream F/2252 T/2315', rotate and slide F/2315 T/2694', 00:00 03:00 3.00 2,128 2,315 SURFA( DRILL DDRL P Rotate and slide f/2128 t/2315', gpm 521, 80 rpm,5/15 wob, 1540 psi,p/u 86,s/o 54, rot wt 68, AST .25,ART 1.45(JAR HRS 90.01) 03:00 03:45 0.75 2,315 2,315 SURFA( DRILL CIRC P Circulate B/u 03:45 05:00 1.25 2,315 1,244 SURFA( DRILL TRIP P Trip out of hole F/2315 T/1244' 05:00 06:00 1.00 1,244 2,315 SURFA( DRILL TRIP P Flow check well,trip in hole to 2252, wash and ream F/2252 T/2315 @ 345 gpm,710 psi 06:00 12:00 6.00 2,315 2,694 SURFA( DRILL DDRL P Rotate and slide F/2315 T/2694'rpm 90, 1940 psi, U/P 102, S/0 55, RT. WT 72,ADT 2.78 AST 2.48 12:00 00:00 12.00 2,694 3,356 SURFA( DRILL DDRL P Rotate and slide F/2694 T/3356', P/U 117, ROT 82, DW WT 60 ADT 7.9,AST 1.02 ROT HRS 6.8 RPM, 80/95,WOB 10, 547 gpm,2184 psi, HRS on jars=97.9 Page 5 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/17/2012 24 hr Summary Drill F/3356 T/3435',CBU x 4 @ 545 GPM,trip out of hole T/615'change out elevators to 5",continue TOH T/315',flow check well,trip in hole F/315 T/615',change elevators to 4",TIH F/615 T/928',shoot check shot survey,cont TIH F/928 T/3435, circulate and condution mud @ 550 GPM, 1350 psi, monitor well pull 5 stds,wet, (proper hole fill), pump dry job&POH, (BHA, hanging up coming into conductor, @ 101',oreint tools and work thru),continue LID bha&directional tools,down load data from DM collar, pull emt probe, pull directional probe 00:00 02:15 2.25 3,435 3,435 SURFA( DRILL DDRL P Drill F/3356 T/3435', P/U 112 S/o 64 R/T 79,GPM 545, PSI 2290,ADT 1.84,AST 0 02:15 05:45 3.50 3,435 3,435 SURFA(CASING CIRC P CBU x 4 @ 545 GPM, @ 2190 psi, stand back 1 stand every 20 min while circulating 05:45 09:30 3.75 3,435 315 SURFA( CASING TRIP P Trip out of hole T/615'change out elevators to 5", continue TOH T/315', flow check well 09:30 12:00 2.50 315 2,192 SURFA( CASING TRIP P Trip in hole F/315 T/615',change elevators to 4",cont.TIH F/615 T/ 928',shoot check shot survey,cont TIH F/928 T/2759',fill pipe @ 2192' 12:00 12:30 0.50 2,192 3,435 SURFA( CASING TRIP P Cont Tripping in hole T/3435 12:30 16:00 3.50 3,435 3,435 SURFA( CASING CIRC P Circulate and condution mud @ 550 GPM, 1350 psi 16:00 16:30 0.50 3,435 3,435 SURFA( CASING TRIP P Monitor well pull 5 stds,wet, proper hole fill 16:30 19:00 2.50 3,435 3,435 SURFA( CASING TRIP P Pump dry job&POH T/617', hole fill 10bbls over cal. 19:00 20:00 1.00 3,435 3,435 SURFA( CASING TRIP P Monitor well,continue TOH 20:00 21:00 1.00 3,435 3,435 SURFA( CASING TRIP P PJSM,clean rig floor, UD BHA 21:00 21:30 0.50 3,435 3,435 SURFA( CASING TRIP P BHA, hanging up coming into conductor,@ 101',oreint tools and work thru 21:30 22:00 0.50 3,435 3,435 SURFA( CASING TRIP P continue UD bha&directional tools 22:00 00:00 2.00 3,435 3,435 SURFA( CASING OTHR P Down load data from DM collar, pull emt probe, pull directional probe 07/18/2012 UD BHA,clear rig floor of drilling tools, rig up to run casing, PJSM, Run 9 5/8 casing per detail,T/149,M/U circulating swedge and work tight spot W/pumps T/226'-190 gpm,40 psi, P/U 35K S/O 25K, rig up to lay down casing, pull casing, pull 193',observing up to 25K overpull. Observed we left 1 centralizer blade,and 1/2 of a stop ring in the hole.Pictures on S drive. Rig down casing running equipment, change out bails on top drive, change out saver sub to 4 1/2 IF, pick up bit,xo,stab and trip in hole to 98',straighten drilling line on dead man, level rig to center top drive over hole. Continue running in hole to and tag @ 115', pulling 8/10 over on up weight,working through tigh spot several times until smooth. POOH to 98',safety stand down with rig crew and Halliburton employees,service rig. 00:00 01:30 1.50 3,435 3,435 SURFA( CASING PULD P PJSm,continue to UD BHA, EM, HOC, bit, motor 01:30 02:00 0.50 0 0 SURFA( CASING OTHR P Clear rig floor of drilling tools and clean up floor 02:00 06:15 4.25 0 0 SURFA( CASING RNCS P Rig up to run casing,change out bails on top drive, install 9 5/8 elevators, rig up fill up line,get casing tongs to floor and hang, dummy run 9 5/8 casing hanger through stack, Page 6 of 22 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 06:15 08:45 2.50 0 226 SURFA(CASING RNCS P PJSM,Make up shoe track. Fill pipe and check floats. Continue run 9 5/8 casing per detail,T/149.Tagged up. 08:45 11:00 2.25 1 SURFA(CASING RNCS T M/U circulating swedge and work tight spot W/pumps T/226'-190 gpm,40 psi, P/U 35K S/O 25K 11:00 11:30 0.50 226 226 SURFA(CASING RNCS T PJSM,rig up to lay down casing. 11:30 12:00 0.50 226 193 SURFA(CASING RNCS T Attempt to pull casing,pull 193'. Observed pulling up to 25K over when collar or centralizer at the conductor shoe. M/U circulating swedge to top drive.Work through tigh spot until 9 5/8"shoe inside conductor. 12:00 15:00 3.00 193 0 SURFA( CASING RNCS T Lay down 9 5/8 casing.Obtain Hot work permit to rose bud heat the baker loc connections. Observed all centralizers came back except one blade,and 1/2 of a stop ring. 15:00 16:00 1.00 0 0 SURFA(CASING OTHR T PJSM, rig down casing running equipment 16:00 18:30 2.50 0 0 SURFA(CASING OTHR T Change out bails on top drive, change out saver sub to 4 1/2 IF, clean rig floor, R/U rig floor to pick up BHA,get subs,stab to floor, ID& OD drilling tools 18:30 19:30 1.00 0 98 SURFA( CASING TRIP T Pick up bit,xo,stab and trip in hole to 98' 19:30 20:30 1.00 98 98 SURFA(CASING OTHR T Straighten drilling line on dead man, level rig to center top drive over hole. 20:30 21:00 0.50 98 115 SURFA( CASING TRIP T Continue running in hole to and tag @ 115',pulling 8/10 over on up weight, POOH to 98', install safety valve and monitor well 21:00 23:30 2.50 115 98 SURFA( CASING SFTY P Safety stand down with rig crew and Halliburton employees 23:30 00:00 0.50 98 1 SURFA( CASING OTHR P Service rig and clean rig floor 07/19/2012 Continue with Safety stand down with all personnel. RIH with 12 1/4"bit assembly to work tight spot at conductor shoe at 112'.Work down to 161'. POOH lay down assembly. Make up 17 9/16"tapered mill assembly.TIH to work conductor shoe area clean, Observed recovered 3 1/2"piece of centralizer. Lay down mill assembly, make up 12 1/4" Bit,clean out assembly,TIH to 181', (hole clean), POOH L/D bit and xo's, make up 12 1/4 Directional BHA,orient tools,Continue trip in hole to 516', Orient tools and slide F/516 T/ 548',work through F/516'to 548'until cleaned up,trip in hole to 604',change out saver sub on top drive, continue tripping in hole F/604 T/870',orient tools,slide F/870'T/875', pull up T/858'rotate and clean hole T/921',continue tripping in hole to 1007', ream F/1007 T/1110'till clean,trip in hole F/1110'T/1553'ream F/ 1553 T/1850'work stand until clean, ream and wash F/1870 T/2066 @ 435 gpm,60 rpm,Torq 6K,trip in hole on elevators F/2066'T/3261',wash and ream F/3261 T/3375 @ 365 gpm,990 psi 40 rpm,torq 8K 00:00 01:30 1.50 98 98 SURFA( CASING SFTY T Safety stand down with rig crew, Peak,&Mi Swaco employees 01:30 02:00 0.50 98 98 SURFA( CASING OTHR T PJSM, remove TIW valve, rig down casing fill line 02:00 02:30 0.50 98 161 SURFA( CASING TRIP T Trip in hole F/98'T115'work with tight spot,work down to 161' 02:30 03:45 1.25 161 0 SURFA( CASING TRIP T POOH F/161 T/34', lay down stablizer and float sub Page 7 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 05:45 2.00 0 0 SURFA(CASING PULD T PJSM, pick up BHA#4 per DD, FLoat,EWR, DM,XO 05:45 06:30 0.75 0 217 SURFA(CASING TRIP T RIH with 2 stands HWDP out of derrick work with tight spot @ 172', work down to 217'POOH stand back HWDP 06:30 08:45 2.25 217 0 SURFA( CASING TRIP T PJSM,change out elevators,make up xo,emcollar,&stand back inderrick, Lay down DM collar, break bit,and stand back EWR and motor in derrick 08:45 09:45 1.00 0 0 SURFA( CASING PULD T Pick up 17 3/8 junk mill,XO,bit sub, to rig floor,obtain ID's and OD'S, make up on stand of HWDP 09:45 11:15 1.50 0 115 SURFA(CASING MILL T Trip in hole with mill, break circulation @ 70', polish conductor F/ 70'T/115'( 17 3/8 gauge @ conductor shoe 112')40 rpm,torq 1/10 K,470 gpm, 120 psi,continue to work torq spots untill pulling tight spots with out rotating. 11:15 12:00 0.75 115 0 SURFA( CASING TRIP T POOH F/115',clean junk mill, recovered 3.5"piece of centralizer blade 12:00 12:30 0.50 0 0 SURFA( CASING PULD T Lay down mill,&xo,clean rig floor 12:30 13:30 1.00 0 118 SURFA( CASING TRIP T Make up 12 1/4 bit&XO'S,Trip in hole with HWDP T/181'(hole clean), POOH&lay down bit&XO'S 13:30 15:30 2.00 118 516 SURFA( CASING PULD T Make up 12 1/4 Directional BHA, orient tools,change out elevators to 4",continue tripping in hole, lay down single 4"DP, change elevators back to 5"Continue trip in hole to 516',tagged up. 15:30 16:00 0.50 516 604 SURFA(CASING REAM T Orient tools and slide F/516 T/548', work through F/516 to 548 until cleaned up,trip in hole to 604' 16:00 17:00 1.00 604 604 SURFA( CASING OTHR T Change out saver sub on top drive back to HT38, change elevators to 4", make up XO f/drill pipe 17:00 18:00 1.00 604 1,110 SURFA(CASING REAM T Continue tripping in hole F/604 T/870',tagged up,orient tools,slide F/870 T/875',pull up T/858 rotate and clean hole T/921',continue tripping in hole to 1007',ream F/ 1007 T/1110'till clean. 18:00 21:30 3.50 1,110 1,850 SURFA( CASING REAM T Trip in hole F/1110'T/1553'ream F/ 1553 T/1850'work stand until clean 21:30 22:30 1.00 1,850 2,066 SURFA( CASING REAM T Ream and wash F/1870 T/2066 @ 435 gpm,60 rpm,Torq 6K 22:30 00:00 1.50 2,066 3,375 SURFA( CASING TRIP T Trip in hole on elevators F/2066'T/ 3261',wash and ream F/3261 T/ 3375 @ 365 gpm,990 psi 40 rpm, torq 8K Page 8 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/20/2012 24 hr Summary PJSM, M/u top drive @ 3375,set depth,wash and ream T/3435',60 rpm,torq 9K,460 gpm, 1720 psi, pump hi visc sweep,circulate bottoms up, POOH to 3375 and stand 1 stand back, continue to circulate 2nd bottoms up,shoot check shot survey,flow check well,pull out of hole F/3375 T/1059,tight spot-drag 10/20 F/1577-1059'30K over pull @ 1059', kelly up and pump out F/1110 T/1047'@ 345 gpm,620 psi(no over pull @ 1059),continue out of hole, F/1047 T/609',flo check well change elevators to 5",stand back HWDP &LID BHA, PJSM on rigging up&running casing, Run 9 5/8 casing T/969',cbu, run casing F/969 T/1738', (tight spots @ 1350, 1430, 1720), make up top drive and circulate @ 1738',@ 4.3 bpm, 120 psi,good returns, p/u 100K, s/o 45K,continue running casing F/1738 T/2840'Continue running casing F/1738 T/2840', circulate bottoms up @ 4.3 bpm, @ 190 psi, P/U 150K, 55K good returns,continue running casing F/2840 T/3399',circulate @ 3399', @ 4.3 bpm,250 psi, P/U 180/200K,S/O 60K,good returns,circulate and crew change. 00:00 02:15 2.25 3,375 3,375 SURFA( CASING REAM T PJSM,M/u top drive @ 3375,set depth,wash and reame T/3435',60 rpm,torq 9K,460 gpm, 1720 psi, pump hi visc sweep, circulate bottoms up, POOH to 3375 and stand 1 stand back, continue to circulate 2nd bottoms up,shoot check shot survey,flow check well. 02:15 05:45 3.50 3,375 609 SURFA( CASING TRIP T Pull out of hole F/3375 T/1059,tight spot-drag 10/20 F/1577-1059'30K over pull @ 1059', kelly up and pump out F/1110 T/1047'@ 345 gpm,620 psi(no over pull @ 1059), continue out of hole, F/1047 T/609',flo check well change elevators to 5" 05:45 06:30 0.75 609 186 SURFA( CASING TRIP T POOH stand back HWDP in derrick 06:30 09:30 3.00 186 0 SURFA( CASING PULD T Lay down directional BHA assembly, clean floor and clear all drilling tools off floor. 09:30 11:30 2.00 0 0 SURFA(CASING RNCS P PJSM, rig up to run casing 11:30 12:00 0.50 0 0 SURFA( CASING SFTY P PJSM on running casing with rig crew and all third party employees 12:00 16:30 4.50 0 0 SURFA( CASING RNCS P PJSM,make up new shoe and float collar on appropiate jts,check floats, run 9 5/8 casing per running order,fill pipe while running make sure casing full every 5 jts, 16:30 17:00 0.50 0 969 SURFA( CASING CIRC P circulate @ 969',@ 4.3 bpm, 110 psi, P/U 70,S/O 45K good returns 17:00 19:00 2.00 969 1,738 SURFA( CASING RNCS P Run casing F/969 T/1738', (tight spots @ 1350, 1430, 1720) 19:00 19:30 0.50 1,738 1,738 SURFA( CASING CIRC P Make up top drive and circulate @ 1738',@ 4.3 bpm, 120 psi,good returns, p/u 100K, s/o 45K 19:30 22:00 2.50 1,738 2,840 SURFA( CASING RNCS P Continue running casing F/1738 T/2840' 22:00 22:30 0.50 2,840 2,840 SURFA( CASING CIRC P Circulate bottoms up @ 4.3 bpm,@ 190 psi, P/U 150K, 55K good returns 22:30 23:30 1.00 2,840 3,399 SURFA(CASING RNCS P Continue running casing F/2840 T/3399', 23:30 00:00 0.50 3,399 3,399 SURFA(CASING CIRC P Circulate @ 3399', @ 4.3 bpm,250 psi, P/U 180/200K,S/O 60K,good returns,circulate and crew change Page 9 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/21/2012 24 hr Summary Continue RIH with 9 5/8 casing. MU hanger and landing jnt. Land casing on depth at 3426'MD. Circulate& Condition mud at 5.5 BPM-110 PSI. Reciprocate casing with UP WT- 165K, SO WT-75K. Rig up BJ and held PJSM. Pump 40 BBLS of 10 PPG nut plug spacer,and 40 BBLS of 8.5 PPG SAPP pill with red dye. With BJ, Pump 2 BBLS, Pressure test lines to 4000 PSI. BAtch up and pump a total of 349 BBLS of 12.0 PPG cement. Displace with rig at 5 BPM observing increased lift pressures to 900 PSI and bumping plug at 248 BBLS pumped.Observed 55 BBLS of cement returns to surface. Pressure 500 PSI over,check floats, held,and CIP at 0715 HRS. RIG down cement head and landing joint. Rig down BJ cementing unit. RD diverter system.Clena pits. Load pipe shed with 4"DP, PJSM, remove knife valve, R/u pick up lines, remove annular, remove adapter spool,finish removing diverter line, R/U flare line,finish cleaning pits, rig down pick up lines, install&orient well head,test well head @ 5K F/10 min, remove beams in cellar, P/u annular perventer&install on double gate preventer, install mud cross, install single gate, install flare line between choke house and rig, clean flanges on mud cross 00:00 01:30 1.50 3,399 3,426 SURFA( CASING CIRC P Circulate on last jnt of 9 5/8 casing @4.3BPM-200 PSI. UPWf- 165K,SO WT-65K. 01:30 02:00 0.50 3,426 3,426 SURFA(CASING RNCS P Make up landing joint&hanger. Land casing on depth at 3426'MD. Make up BJ cement head and crossover. 02:00 04:00 2.00 3,426 3,426 SURFA( CASING CIRC P Stage pumps up to 5.5 BPM-110 PSI. Reciprocate casing string at 165k Up weight and 65K down weight. RU BJ and lines.Circulate a total of 750 BBLS. Held PJSM with all personnel. Discuss saefty&hazard recognition isues. Discuss cementing operation. 04:00 05:00 1.00 3,426 3,426 SURFA( CEMEN-CMNT P Rig up lines.With rig-Pump 40 BBLS of 10 PPG nut plug spacer, and 40 BBLS of 8.5 PPG SAPP pill with red dye. Drop Bottom plug. 05:00 07:45 2.75 3,426 3,426 SURFA( CEMENT CMNT P With BJ, Pump 2 BBLS, Pressure /C' pI e test lines to 4000 PSI. Batch up and pump a total of 349 BBLS of 12.0 ` o/' PPG cement. Displace with rig at 5 BPM observing increased lift pressures to 900 PSI and bumping plug at 248 BBLS pumped.Observed 55 BBLS of cement returns to surface. Pressure 500 PSI over, check floats, held,and CIP at 0715 HRS.Continue reciprocate until 200 strokes into displacement when casing string became sticky.Casing landed on hanger.ICP-450 PSI- FCP 1030 PSI. 07:45 08:45 1.00 3,426 3,426 SURFA( CASING RNCS P Rig down cement head and lines. Breakout&lay down landing joint. Flush diverter stack with cement retarder fluid. Drain system and clean out cellar box. 08:45 09:00 0.25 3,426 3,426 SURFA( CASING SFTY P Held PJSM with crew. Discuss safety&hazared recognition issues. Discuss procedure to nipple down diverter system. Page 10 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 12:00 3.00 3,426 3,426 SURFA(CASING NUND P Nipple down diverter system including buoy lines, and koomey lines. Utilize Peak crane to break down buoy line.Clean pits. Load pipe shed with 4"DP. 12:00 16:00 4.00 3,426 3,426 SURFA(CASING NUND P Remove knife valve, R/u pick up lines, remove annular, remove adapter spool,finish removing diverter line, R/U flare line,finish _cleaning pits, rig down pick up lines 16:00 17:00 1.00 3,426 3,426 SURFA(CASING NUND P Change out bails on top drive, install 4"elevators. 17:00 19:00 2.00 3,426 3,426 SURFA( CASING NUND P Install&orient well head,test well _head @ 5K F/10 min. 19:00 00:00 5.00 3,426 3,426 SURFA( CASING NUND P Remove beams in cellar, P/u annular perventer&install on double gate preventer, install mud cross, install single gate, install flare line between choke house and rig,clean flanges on mud cross 07/22/2012 Nipple up bop's and choke line, install riser, rig up testing equipment,get RKB'S, make up floor valves to test joint, make up test plug and run in hole to lower spool,test BOP'S,250 Lo 4000psi hi F/5min ea.trouble shoot failing test on#1 test, (choke valves 1,5,9,14,15, annular and HCR kill), bleed off psi,function rams& choke valves,close top rams&psi t/3500 psi,test failed,shut HCR psi up,test failed, inspect for leaks, no visible leaks, pull test plug&inspect, rubber good, install Katch kan to facilitate ability to see leaks easier, install wear busing(9.0625)rig down testing equip,clean rig floor, perform derrick inspection,measure kelly hose,pick up 36 jts,4"drill pipe from pipe shed and stand back in derrick. 00:00 07:00 7.00 3,426 SURFA( CASING NUND P Nipple up bop's, hammer up flange bolts, on lower gate, hook up chokeline, install studs in lower single gate,&stab onto well head& make up, hook up kill line to mud cross, install turn buckles, hook up koomey hoses, R/D potatoe masher, install flow riser, R/U test hoses& manifold on rig floor,obtain RKB's, MOB-8.1"-top pipe rams 11.2, blinds 13", lower rams 16.6, line up _choke manifold to fill with water 07:00 09:00 2.00 SURFA( CASING BOPE P Make up TIW&dart valves to 4"test joint, install test plug and run in to lower spool,fill stack with water n Of 09:00 12:00 3.00 SURFA( CASING BOPE P Test BOP'S,250 Lo 4000psi hiF/ . 10, 5min ea.trouble shoot failing test on #1 test, (choke valves 1,5,9,14,15, annular and HCR kill), bleed off psi, functio rams&choke valves,close top rams&psi t/3500 psi,test failed, shut HCR psi up,test failed, inspect for leaks, no visible leaks, pull test plug&inspect, rubber good, install Katch kan to facilitate ability to see leaks easier. Page 11 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 17:30 5.50 SURFA( CASING BOPE P Test annular @ 250 lo-2500 hi- F/5min,continue to test rest of componrnts&all assciated equiptment @ 250 110, 5000 psi hi, tighten leak @ choke house,check all pit level monitors&flo sensor, function test super choke,&manual choke,flo test samme @ 3 bpm, 17:30 18:30 1.00 SURFA(CASING BOPE P Lay down test plug,and install wear busing(9.0625)rig down testing equip, blow down mud lines and surface lines. 18:30 20:30 2.00 SURFA( CASING PULD P Clean rig floor, perform derrick inspection, measure kelly hose, R/U floor to pick up drill pipe 20:30 22:00 1.50 SURFA( CASING PULD P Pick up 36 jts,4"drill pipe from pipe shed. Racked back in Derrick. 22:00 00:00 2.00 SURFA( CASING PULD P Pull out of hole stand back 18 stands drill pipe in derrick 07/23/2012 Pick up 6.75 bottom hole assembly per directional driller,Torq. bit to 16K,4.5 connections T/32K, install probe,trouble shoot index sub spacer/probe nut,continue picking up BHA,down load MWD,make up antenna sub, prep ports for nuke installation, PJSM W/all employees, load nukes,continue making up bha, pick up bat collar, plug into bat collar&down load per DD,continue picking up flex collars, hwdp*(shallow test hole pulse on first stand HWDP), change out elevators to 4",trip in hole picking up singles F/672 T/858, unable to RIH due to congealed drilling mud packing off flow line,jet flow line&dump contamiated mud F/pit 4 to rock washer,fill pit with water,flush mud pump#1, pump 4 bbls down drill string to clean hole,fill pit#4 with mud,break circulation @ 3bbl/min,stage pumps up to 7 bbl/min&circulate bottoms up(1300 stks), continue picking up pipe&RIH T/2084,fill pipe and circulate 3200 stks @ 5.5 bbl/min,continue RIH U 3249', circulate and condution mud,cut drilling line,&inspect brakes, rig up to test casing, Finish rigging up to test casing, pressure up @ 3000 psi,test no good,trouble shoot pressure problem,found sensor diaphram colasped, pump up sensor on test chart,and change out low torque valve, pressure up in stages, F/900- 1200-2000-T/3000 psi,test failed after 8 min @ 3000 psi, check sensor diaphragm,sensor diaphram ruptured,chane out complete sensor. 00:00 01:00 1.00 0 0 SURFA( CASING PULD P PJSM W/Halliburton and pick up 6.75 bottom hole assembly, install 5" elevators 01:00 03:00 2.00 0 0 SURFA( CASING PULD P Make up BHA per Directional driller, Torq. bit to 16K,4.5 connections T/ 32K, install probe. 03:00 04:00 1.00 0 0 SURFA( CASING PULD T Trouble shoot index sub spacer/ probe nut. 04:00 08:15 4.25 0 672 SURFA( CASING PULD P Continue picking up BHA,down load MWD,make up antenna sub, prep ports for nuke installation, PJSM W/ all employees, load nukes,continue making up bha,pick up bat collar, plug into bat collar&down load per DD,continue picking up flex collars, hwdp*(shallow test hole pulse on first stand HWDP) Page 12 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 11:30 3.25 672 858 SURFA( CASING PULD T Change out elevators to 4",trip in hole picking up singles F/672 T/ 858, unable to RIH due to congealed drilling mud packing off flow line,jet flow line&dump contamiated mud F/ pit 4 to rock washer,fill pit with water,flush mud pump#1, pump 4 bbls down drill string to clean hole, fill pit#4 with mud, break circulation @ 3bbl/min,stage pumps up to 7 bbl/min&circulate bottoms up(1300 stks) 11:30 16:00 4.50 858 3,249 SURFA( CASING PULD P Continue picking up pipe&RIH T/ 2084,fill pipe and circulate 3200 stks @ 5.5 bbl/min,continue RIH t/3249' 16:00 17:00 1.00 3,249 3,249 SURFA( CASING CIRC P Circulate and condution mud, pump 13500 stks @ 450 gpm,W/1320 psi, rig up for casing test,work on# 2 pump throttle 17:00 18:00 1.00 3,249 3,249 SURFA( CASING SLPC P Cut drilling line, (cut 90')inspect brakes 18:00 00:00 6.00 3,249 3,249 SURFA( CASING PRTS T Finish rigging up to test casing, pressure up @ 3000 psi,test no good,trouble shoot pressure problem,found sensor diaphram colasped, pump up sensor on test chart,attempt casing test,(test no good)change out low torque valve, pressure up in stages, 900-1200 -2000-3000 psi,test failed after 8 min @ 3000 psi, check sensor diaphragm,sensor diaphram ruptured, change out complete sensor. 07/24/2012 Test casing @ 3000 PSI F/30 min,test, rig down test equiptment,trip in hole F/3249 T/3311'make up top drive and wash down T/float collar @ 3 bpm,500 gpm,tage float collar @ 3347 MD, P/U wt. 110K, S/O 62K, pick up 5'and test injection pump,drill Float collar, 500 gpm,2000 psi, wob 7K, 80 rpm, 9K torque,continue j drilling out shoe track, F3349 T/3427,drill 20'new hole F/3435 T/3455', circulate and condution mud for FIT ✓ test,circulate untill 9.4 ppg mud wt. in and out, pull drill string into shoe, rig up to FIT test, perform FIT test with injection pump, 16PPG EMW 1295 stks required T/pressure up to 960 PSI,final EMW-14.6 PPG, rig down testing equipment, circulate&prep pits for mud displacement, build spacer pill in pit#4, BOP drill, response time 53 sec,displace- pump 40 bbl spacer, ,pump 9.4 PPG klasheild mud @ 550 ppg, 1800 psi, P/U 110,S/O 70K, RWT 80K, pump until good returns observed @ shakers,obtain slow pump rates @ 3427 MD,2808 TVD,pump#1 @ 3bpm,250 psi @ 4bpm 310 psi,pump#2 @ 3 bpm 250 psi @ 4bpm 320 psi, rotate and slide F/3455 T/3595, @ 550 gpm, 1420 psi, P/U 115K, S/O 70K, RWT 80K, 8K torq on bottom, 7K off bottom,ADT 1.46, C5� 00:00 02:00 2.00 3,249 3,249 SURFA( CASING PRTS P Continue to test casing @ 3000 PSI F/30 min,test, rig down test equiptment. 02:00 02:30 0.50 3,249 3,349 SURFA( CASING TRIP P Trip in hole F/3249 T/3311'make up top drive and wash down T/float collar @ 3 bpm,500 gpm,tage float collar @ 3347 MD, P/U wt. 110K, S/0 62K, pick up 5'and test injection pump. Page 13 of 22 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 02:30 04:30 2.00 3,349 3,427 SURFA(CASING DRLG P Drill Float collar,500 gpm,2000 psi, wob 7K,80 rpm, 9K torque,continue drilling out shoe track, F3349 T/3427, 5/7 wob, 8K torque, 80 rpm,550 gpm,2450 psi, P/U 115K, 5/0 65K, RT.WT 75K 04:30 05:30 1.00 3,427 3,455 PROD1 CASING DRLG P Drill 20'new hole F/3435 T/3455', P/U 115K, S/O 65K, RT.WT 75K 05:30 06:30 1.00 3,455 3,455 PROD1 CASING CIRC P Circulate and condution mud for FIT test,535 gpm,2150 PSI,circulate until)9.4 ppg mud wt.in and out, pull drill string into shoe. 06:30 07:30 1.00 3,455 3,445 PROD1 DRILL FIT P Rig up to FIT test, perform FIT test with injection pump, 16PPG EMW 1295 stks required T/pressure up to 960 PSI,final EMW-14.6 PPG, rig down testing equipment 07:30 08:00 0.50 3,455 3,455 PROD1 DRILL SFTY P PJSM on mud displacement,& performance review. 08:00 08:45 0.75 3,455 3,455 PROD1 DRILL CIRC P Circulate&prep pits for mud displacement, build spacer pill in pit #4. Perform BOP drill, response time 53 sec 08:45 09:45 1.00 3,455 3,455 PROD1 DRILL CIRC P Displace- pump 40 bbl spacer, ,pump 9.4 PPG klasheild mud @ 550 ppg, 1800 psi, P/U 110, S/0 70K, RWT 80K, pump until good returns observed @ shakers 09:45 10:00 0.25 3,455 3,455 PROD1 DRILL DRLG P Obtain slow pump rates @ 3427 MD, 2808 TVD, pump#1 @ 3bpm,250 psi @ 4bpm 310 psi,pump#2 @ 3 bpm 250 psi @ 4bpm 320 psi 10:00 12:00 2.00 3,455 3,595 PROD1 DRILL DDRL P Rotate and slide F/3455 T/3595, @ 550 gpm, 1420 psi, P/U 115K,S/O 70K, RWT 80K, 8K torq on bottom, 7K off bottom,ADT 1.46, 12:00 00:00 12.00 j 3,595 4,224 PROD1 DRILL DDRL P Rotate and slide F/3595 T/4224', P/U 115,S/0 74, ROT WT 90, 8K on bottom torq, 5K torq off bottom, AST 2.12 hrs, ADT 7.08 hrs 07/25/2012 Rotate and slide F/4224'-4506, P/U 118,S/0 80, ROT WT 90, 8K on bottom torq,5K torq off bottom,AST 3.58 hrs, ADT 4.44 hrs,circulate bottoms up @ 4506,trip out hole F/4506 T/3406,monitor well, obtain static loss rate, loss rate=3 BPH,trip in hole F/3406 T/4444,drill F/4506 T/4882,@ 550 gpm,2200 psi, p/u 133k,s/o 84k, rot wt 104 torq 8.5,ADT 3.4,AST 2.62,drill F/4882, T/5327'@ 550 gpm,2350 psi, p/u 140k,s/o 90k, rot wt 106 torq 8.7,ADT 9.3 ,AST 0.0 ART 99.3, max gas units 2300 00:00 07:30 7.50 4,224 4,506 PROD1 DRILL DDRL P Rotate and slide F/4224'-4506, P/U 118,S/0 80, ROT WT 90, 8K on bottom torq,5K torq off bottom, _AST 3.58 hrs, ADT 4.44 hrs 07:30 08:00 0.50 4,506 4,506 PROD1 DRILL CIRC P Circulate bottoms up @ 4506,500 gpm, 1800 psi,obtain slow pump rate,@#1@ 3bpm 250 psi,4bpm 330 psi,#3 @ 3bpm 247-4bpm 340 psi 08:00 09:00 1.00 4,506 3,406 PROD1 DRILL TRIP P Trip out hole F/4506 T/3406, P/U 105K,S/0 65K, no over pull observed Page 14 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:30 1.50 3,406 4,506 PROD1 DRILL TRIP P Monitor well, obtain static loss rate, loss rate=3 BPH,trip in hole F/ 3406 T/4506 10:30 12:00 1.50 4,506 4,567 PROD1 DRILL DDRL P Drill F/4506 T/4567,wob 5K, rpm 80,gpm 550,stp 2150, p/u 123k,s/o 83k,ADT.54,AST.41 12:00 18:00 6.00 4,567 4,882 PROD1 DRILL DDRL P Drill F/4567 T/4882, @ 550 gpm, 2200 psi,p/u 133k,s/o 84k, rot wt 104 torq 8.5,ADT 2.86,AST 2.21 18:00 00:00 6.00 4,882 5,237 PROD1 DRILL DDRL P Drill F/4882, T/5327'@ 550 gpm, 2350 psi, p/u 140k,s/o 90k, rot wt 106 torq 8.7,ADT 9.3 ,AST 0.0 ART 99.3, max gas units 2300 07/26/2012 Rotate and slide F/5437 T/5514,WOB 5/7K, RPM 80,GPM 550,STP 2360,Torq 8.5 on bottom,8.3 off bottom, P/U 140, S/O 95K, RTW 110K,circulate hole clean, monitor well&trip out of hole F/5514 T/4506, monitor well,trip in hole F/4506 to 5514, rotate and slide F/5514 T/5924,wob 5-7K,550 gpm,stp 2520, ECD 10.09, P/U 150K,S/O 98K, RWt 115K,torq on bottom 9.5K,torq off bottom 9K, rotate and slide F/5924 T/6278,wob 5-7K, 510 gpm,stp 220, ECD 10.10, P/U 155K, S/O 100K, RWt 125K,torq on bottom 10.3K, torq off bottom 9K, circulate bottoms up and clean hole,@ 525 gpm, @ 2340 psi,trip out of hole F/6523 T/ 6206, hole taking proper hole fill, no over pull,. 00:00 02:00 2.00 5,437 5,514 PROD1 DRILL DDRL P Rotate and slide F/5437 T/5514, WOB 5/7K, RPM 80, GPM 550,STP 2360,Torq 8.5 on bottom,8.3 off bottom, P/U 140,S/O 95K, RTW 110K,ADT 1.46 hr,AST o.o hrs, ART 1.46 02:00 03:00 1.00 5,514 5,514 PROD1 DRILL CIRC P Circulate hole clean, @ 500 gpm, 1990 psi, rpm 70,off bottom totque 7.7 K gas 440 units 03:00 05:30 2.50 5,514 5,514 PROD1 DRILL TRIP P Obtain SPR @ 5514',MP#1 @ 3bpm 300 psi,@ 4bpm 390 psi, Pump#2 @ 3bpm 300 psi, @ 4bpm 390 psi, monitor well&trip out of hole F/ 5514 T/4506, monitor well,trip in hole F/4506 to 5514 05:30 12:00 6.50 5,514 5,924 PROD1 DRILL DDRL P Rotate and slide F/5514 T/5924, wob 5-7K,550 gpm,stp 2520, ECD 10.09, P/U 150K,S/O 98K, RWt 115K,torq on bottom 9.5K,torq off bottom 10.2K,ADT4.40 hrs,AST 0.0 hrs,ART 4.40 hrs, (jar hrs 123.89) 12:00 18:00 6.00 5,924 6,278 PROD1 DRILL DDRL P Rotate and slide F/5924 T/6278, wob 5-7K,510 gpm,stp 220, ECD 10.10, P/U 155K,S/O 100K, RWt 125K,torq on bottom 10.3K,torq off bottom 9K,ADT3.87 hrs,AST 0.0 hrs,ART 3.87 hrs, (jar hrs 127.76),c 18:00 22:30 4.50 6,278 6,523 PROD1 DRILL DDRL P Rotate and slide F/6278 T/6523, wob 2/5K, 100 rpm,525 gpm,2470 stp, ECD 10.14, p/u 155K,s/o 106K, rtw 126K,torq on bottom 7.8, off bottom 7.3,ADT 7.55 hrs,AST o.o hrs,ART 7.55 hrs 22:30 23:00 0.50 6,523 6,523 PROD1 DRILL CIRC P Circulate bottoms up and clean hole, ©525 gpm, @ 2340 psi. 23:00 00:00 1.00 6,523 6,206 PROD1 DRILL TRIP P Trip out of hole F/6523 T/6206, hole taking proper hole fill, no over pull Page 15 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/27/2012 24 hr Summary Continue tripping out of hole F 6206 T/5516, P/U 145K, S/O 95K,tight hole @ 5655 15K over, @ 5560'20K over,5510'25K over,tight spots OK after working pipe once thru all tight spot, monitor well,trip in hole T/ 6461,fill pipe,wash and ream F/6461 T/6521,drill F/6523 T/6728,wob 7K, rpm 100,gpm 525, ECD 10.39, STP 2650 psi,on bottom torq 9.0,off bottom 8.0, P/U 155K,S/O 105K RTW 125K,ADT 2.48,AST 0.0,ART 2.48,drill F/6728 T/7086, wob 7K, rpm 100,gpm 525, ECD 10.39, STP 3080 psi,on bottom torq 10.0, off bottom 9.0, P/U 165K, SIO 105K RTW 128K,ADT 4.35,AST 0.0,ART 4.35,drill F/7086 T/7464,wob 10K, rpm 100,gpm 525, ECD 10.39, STP 3050 psi,on bottom torq 9.5,off bottom 11.3, P/U 171K, S/O 105K RTW 135K,ADT 4.05,AST 0.0,ART 4.05, Drill F/7464 T/7553,wob 10K, rpm 100,gpm 525, ECD 10.39, STP 3160 psi, on bottom torq 9.5, off bottom 11.3, P/U 176K, S/O 110K RTW 132K,ADT 1.39,AST 0.0,ART 1.39 ,circulate and condution mud @ 12.9 bpm, 1890 psi, Monitor well,trip out of hole F/7553 T/6711,tight spots @ 7219,6909,6800,&6658, pull 20K over,work through tight spots 1X, pull clean 00:00 01:00 1.00 6,206 5,510 PROD1 DRILL TRIP P Continue tripping out of hole F 6206 T/5516, P/U 145K,S/O 95K,tight hole @ 5655 15K over,@ 5560'20K over,5510'25K over,tight spots OK after working pipe once thru all tight spot, 01:00 02:00 1.00 5,510 6,523 PROD1 DRILL TRIP P Monitor well,trip in hole T/6461,fill pipe,wash and ream F/6461 T/6521 @ 360 gpm, 1330 psi 02:00 06:00 4.00 6,523 6,728 PROD1 DRILL DDRL P Drill F/6523 T/6728,wob 7K, rpm 100,gpm 525, ECD 10.39,STP 2650 psi,on bottom torq 9.0,off bottom 8.0, P/U 155K, S/O 105K RTW 125K,ADT 2.48,AST 0.0,ART 2.48 (HRS on jars 133.92)gas 320 units 06:00 12:00 6.00 6,728 7,086 PROD1 DRILL DDRL P Drill F/6728 T/7086, wob 7K, rpm 100,gpm 525, ECD 10.39,STP 3080 psi,on bottom torq 10.0, off bottom 9.0, P/U 165K,S/O 105K RTW 128K,ADT 4.35,AST 0.0,ART 4.35 (HRS on jars 138.27), gas 500 units 12:00 18:00 6.00 7,086 7,464 PROD1 DRILL DDRL P Drill F/7086 T/7464,wob 10K, rpm 100,gpm 525, ECD 10.39,STP 3050 psi,on bottom torq 9.5, off bottom 11.3, P/U 171K, S/O 105K RTW 135K,ADT 4.05,AST 0.0,ART 4.05 ( HRS on jars 142.32),gas 2910 units 18:00 19:45 1.75 7,464 7,553 PROD1 DRILL DDRL P Drill F/7464 T/7553,wob 10K, rpm 100,gpm 525, ECD 10.39,STP 3160 psi, on bottom torq 9.5, off bottom 11.3, P/U 176K, S/O 110K RTW 132K,ADT 1.39,AST 0.0,ART 1.39 ( HRS on jars 143.71),gas 2910 units 19:45 22:00 2.25 7,553 7,553 PROD1 DRILL CIRC P Circulate and condution mud @ 12.9 bpm, 1890 psi 22:00 22:30 0.50 7,553 7,553 PROD1 DRILL SVRG P Check draw works transmission, lub drawworks 22:30 00:00 1.50 7,553 6,711 PROD1 DRILL TRIP P Monitor well,trip out of hole F/7553 T/6711,tight spots @ 7219,6909, 6800, &6658,pull 20K over,work through tight spots 1X, pull clean Page 16 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/28/2012 24 hr Summary Continue trip out to 3347,work thru tigh spot 1X&clean up,service top drive and blocks, monitor well, static loss 2 bbls hr,trip in hole F/3347 T/7361,fill pipe @ 5269&7169, Hallibuton check shots @ 3811,4030, 4222,4722,wash and ream F/7361 T/7553, @ 450 gpm,2500 psi,80 rpm, 130K rtw,circulate and condution hole,550 gpm, 80 rpm,3250 psi, rwt 137K, build LCM pill while circulating, pump 40 bbl pill and spot @ bit, monitor well F/10 min,Trip out of hole to shoe,monitor well for flow,continue trip out to BHA, monitor well, change elevators,stand back HWDP,jars,flex collars,down load mwd tools, pull nuke sources, lay down BHA per DD. 00:00 04:30 4.50 6,711 3,347 PROD1 CASING TRIP P Trip out of hole F/6711 T/6432', monitor well,pump dry job,continue trip out to 3347, pull 15/20 over @ 7219,6909,6800,6658,6548,6538, 6517,6443,6420,6405,6345,6310, 6284,6100, 5524,5415,5380, 5324, 5315,5286, 5252,5245,5180, 5150, wotk thru tight spots 1X and pulled clean 04:30 05:00 0.50 3,347 3,347 PROD1 CASING SVRG P Service top drive and blocks, monitor well,static loss 2 bbls hr. 05:00 10:30 5.50 3,347 7,553 PROD1 CASING TRIP P Trip in hole F/3347 T/7361,fill pipe @ 5269&7169, Hallibuton check shots @ 3811,4030,4222,4722, wash and ream F/7361 T/7553, @ 450 gpm,2500 psi,80 rpm, 130K rtw, 10:30 12:00 1.50 7,553 7,553 PROD1 CASING CIRC P Circulate and condution hole,550 gpm, 80 rpm,3250 psi, rwt 137K, build LCM pill while circulating 12:00 12:30 0.50 7,553 7,553 PROD1 CASING CIRC P Continue circulating and conditioning mud, 550 gpm,80 rpm,3250 psi, rwt 137K, pump 40 bbl pill and spot @ bit 12:30 20:00 7.50 7,553 672 PROD1 CASING TRIP P Monitor well F/10 min,Trip out of hole to shoe, monitor well for flow, continue trip out to BHA, 20:00 00:00 4.00 672 0 PROD1 CASING TRIP P Monitor well,change elevators,stand back HWDP,jars,flex collars,down load mwd tools, pull nuke sources, lay down BHA per DD 07/29/2012 Continue down loading HCIM tool,and laying down BHA, PJSM with Halliburton E-line personnel, rig up logging equipment, run in hole with logging tools and attempt to log , logging tool sttuck @ 4160, pull tools free and trip out with wire line,monitor hole for losses. Fluid losses 1-2 BPH. 00:00 02:00 2.00 0 0 PROD1 CASING TRIP P Continue down loading HCIM tool, and laying down BHA 02:00 04:30 2.50 0 0 PROD1 CASING ELOG P PJSM with Halliburton E-line _personnel, rig up logging equipment, 04:30 12:00 7.50 0 4,160 PROD1 CASING ELOG P Run in hole with logging tools and log and attempt to log, logging tool stuck @ 4160,pull tools free and trip out with wire line, monitor hole for losses 12:00 13:00 1.00 4,160 0 PROD1 CASING ELOG P Continue pulling out of hole with _logging tools,and lay down tools 13:00 18:00 5.00 0 0 PROD1 CASING ELOG P Clean out logging tools, hang wire line sheave in derrick,make up logging tools on drill pipe. Latch up, test to verify. Page 17 of 22 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:00 00:00 6.00 0 3,435 PROD1 CASING ELOG P Trip in hole with logging tools on drill pipe T/3927'. make up side door entry sub, Run in hole F/3435, Runing speed held at 2 minutes/ stand.Observed proper displacement. 07/30/2012 Continue running in hole with with conveyed logging tools F/3435 T/7283', running speed 30ft/min, pull out of hole F 7281 T/6842, Halliburton wire line tie in,sperry gamma logs, run in hole F/6842 T/6936, logging @ 50 ft/min, E-line unit unable to slack off, POOH F 6936 T/3788, (side door entry sub)&trouble shoot, encounter torpedo on wire line @ 4100', uninstall torpedo, continue pulling out of hole F/4100 T/3788',pins on side door entry sub sheared off, (pins set to shear @ 6K ft/lbs)rig down side door entry sub,continue tripping out of hole to 9 5/8 casing shoe,circulate while Halliburton repaired equiptment, circulate @ 235 gpm,320 psi, p/u 80K,s/o 60K, mw 9.8,trip in hole T/3782, install latch head&side entry sub, pump down latch head @ 6.2 bpm @ 380 psi,establish latch up,test tools, Psi increased T/490 psi,trip in hole with conveyed logging tools F/3782 T/4225, retest tools,continue in hole T/7000'@ 30 ft/min per stand, P/U 135K, S/O 90K, log F/7000'T/6600'@ 30 ft/min, run in hole T/7048,WLD and log, pull up to 6704'WLD, pull 90K over T/break free. hole static no mud losses last 24 hrs 00:00 04:00 4.00 3,435 7,283 PROD1 CASING ELOG P Continue running in hole with with conveyed logging tools F/3435 T/ 7283', running speed 30ft/min 04:00 05:30 1.50 7,283 6,842 PROD1 CASING ELOG P Pull out of hole F 7281 T/6842, Halliburton wire line tie in,sperry gamma logs 05:30 06:00 0.50 6,842 6,936 PROD1 CASING ELOG P Run in hole F/6842 T/6936, logging @ 50 ft/min 06:00 09:30 3.50 6,936 3,788 PROD1 CASING ELOG T E-line unit unable to slack off, POOH F 6936 T/3788,(side door entry sub)&trouble shoot, encounter torpedo on wire line @ 4100', uninstall torpedo, continue pulling out of hole F/4100 T/3788' 09:30 10:30 1.00 3,788 3,788 PROD1 CASING ELOG T Pins on side door entry sub sheared off, (pins set to shear @ 6K ft/lbs)rig ✓ down side door entry sun 10:30 11:30 1.00 3,788 3,427 PROD1 CASING ELOG T Continue tripping out of hole to 9 5/8 casing shoe @ 3426'. 11:30 13:30 2.00 3,427 3,427 PROD1 CASING ELOG T Circulate while Halliburton repaired equiptment&replace line, circulate @ 235 gpm,320 psi, p/u 80K,s/o 60K, mw 9.8 PPG 13:30 15:30 2.00 3,427 3,782 PROD1 CASING ELOG T Trip in hole T 3782, install latch head &side entry sub, pump down latch head @ 6.2 bpm @ 380 psi, establish latch up,test tools, Psi increased T/490 psi 15:30 20:00 4.50 3,782 7,000 PROD1 CASING ELOG T Trip in hole with conveyed logging tools F/3782 T/4225,retest tools, continue in hole T/7000'@ 30 ft/min per stand, P/U 135K, S/O 90K 20:00 00:00 4.00 7,000 6,600 PROD1 CASING ELNE P Log F/7000'T/6600'@ 30 ft/min, run in hole T/7048,WLD and log, pull up to 6704'WLD, pull 90K over T/break free, hole static no mud losses last 24 hrs Page 18 of 22 Time Logs Date- From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/31/2012 24 hr Summary Continue with Drill pipe conveyed logging from 6550'MD.Obtain data sets at 6445,6428',6280',6249', 6236',6228',6074',6064',5840', 5683',5634', 5556',5533',5463', 5297', 5199',5097',4855',4731',4703', 4638',4622',4586'. Monitor the well on the trip tank. Losses= 1 Barrel per hour. 00:00 12:00 12.00 6,600 5,840 PROD1 CASING DLOG P Continue with Drill pipe conveyed logging run obtaining data sets from 6485',6445',6428',6366', and 6280'. Observed hole conditions static. Observed overpull of up to 125K over at times to reposition tools. Pick up to 6249',6236',6228',6074'for formation tests.Trip back down from 6074'to 6222'and perform test. Up Wt= 135k, Dn Wt=85k, Begin logging up again. Log up to 6074'. Pick up to 6064'and test. POOH logging from 6064 to 5840'. Up Wt= 122k. Dn Wt=75k. Perform pressure test @ 5840'MD. 12:00 00:00 12.00 5,840 4,586 PROD1 CASING DLOG P Continue the Drill Pipe conveyed logging operations as per the Well Site Geologist.Collecting pressure data points @ 5840',5683',5634', 5556',5533', 5463',5297', 5199', 5097',4855',4731',4703',4638', 4622',4586'. Constant monitoring of the well on the trip tank. Losses= 1 barrel per hour.SIMOPS:Service crown, replace air valve on eaton brake,paint wind walls,prep roof for painting.General house keeping and maintenance. 08/01/2012 Complete drill pipe conveyed wireline logging.Take readings @ 4586',4571',4543',4505',4474',4422',4396', 4346',4338',4312',4286',4231'. POOH with logging tools. Pick up BHA#7. Clean out assembly.Trip to the shoe and change out saver sub. 00:00 07:30 7.50 4,586 4,231 PROD1 CASING DLOG P Continue the Drill Pipe conveyed logging operations as per the Well Site Geologist.Collecting pressure data points @ 4586',4571',4543', 4505',4474',4422',4396',4346', 4338',4312',4286',4231', .Constant monitoring of the well on the trip tank.Wellbore static. Logging complete. 07:30 08:00 0.50 4,231 3,788 PROD1 CASING DLOG P Trip out of the hole to the side door entry sub. 87k=Up Wt.65k=Dn Wt. 08:00 09:30 1.50 3,788 3,788 PROD1 CASING DLOG P Rig down side door entry sub as per Halliburton. POOH with wireline to 300'. Pull side door entry sub out of stump.and lay down stinger and sub. Break out 4.5"IF XO's, and make up stand. Rack back stand and rig down wireline sheaves. 09:30 10:00 0.50 3,788 3,480 PROD1 CASING OWFF P Trip out of the hole from 3788'to 3480'MD. Monitor well at the shoe. Static. Pump dry job. Page 19 of 22 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 10:00 12:00 2.00 3,480 2,498 PROD1 CASING DLOG P Trip out of the hole to 2498'MD. 12:00 14:15 2.25 2,498 519 PROD1 CASING DLOG P Trip out of the hole from 2498'to 519' MD. 14:15 14:30 0.25 519 519 PROD1 CASING DLOG P PJSM.Lay down wireline tools. Monitor the well. Static. 14:30 16:00 1.50 519 0 PROD1 CASING DLOG P Rack back HWDP. Lay down wireline tools and equipment. 16:00 16:30 0.50 0 0 PROD1 CASING RURD P PJSM.Stage BHA for clean out run. 16:30 18:30 2.00 0 480 PROD1 CASING PULD P Pick up BHA#7.Clean out assembly. BHA weight=48k. 18:30 19:30 1.00 480 1,600 PROD1 CASING TRIP P Trip in the hole from 480'to 1600'. Improper displacement.Screw in with topdrive. 19:30 20:00 0.50 1,600 1,600 PROD1 CASING CIRC P Circulate bottoms up @ 3 BPM. 150 PSI. 7%flow. Reciprocate pipe and rotate 20 RPM. Returns 250 strokes early.Good displacement. Discovered leaky float. 20:00 21:00 1.00 1,600 2,300 PROD1 CASING TRIP P Trip in the hole 2 mins per stand. 21:00 21:30 0.50 2,300 2,300 PROD1 CASING CIRC P Circulate and condition.4.6 BPM. 300 PSI. 10%flow. 9.75 PPG mud weight in and out.Good displacement. 21:30 22:30 1.00 2,300 3,426 PROD1 CASING TRIP P Trip in the hole @ 2 mins per stand. Trip to the shoe. 22:30 23:45 1.25 3,426 3,426 PROD1 CASING CIRC P Circulate and condition.6 BPM.420 PSI. 12%flow. Reciprocate and rotate 20 RPM.4k TQ. P/U Wt=82k, S/O Wt=69k, Rot Wt=75k. Mud weight in and out 9.7 heavy. 23:45 00:00 0.25 3,426 3,426 PROD1 CASING OWFF P Observe well for flow.Static.Crew change. Gather tools for changing out saver sub for next crew. 08/02/2012 Change out saver sub at the shoe.Trip in the hole. Circulate @ 5500'MD. Ream from 7100'to TD.Circulate bottoms up 4x's. 9.9 PPG mud weight in and out.Trip out of the hole and lay down the clean out assembly. Pull wear bushing. Begin to change out the upper rams to 7"for the casin• run. 00:00 01:00 1.00 3,465 3,465 PROD1 CASING SVRG P PJSM.Change out saver sub.Torque saver sub to 29k ft lbs.Adjust grabber.Torque clamp to 550 ft lbs. Wire tie all overhead fasteners. 01:00 03:30 2.50 3,465 5,422 PROD1 CASING TRIP P Continue to RIH from 3465'to 5422'. No hole problems. 03:30 05:00 1.50 5,422 5,422 PROD1 CASING CIRC P Circulate and condition mud. Stage pumps from 235 gom to 400 gpm. Max gas-800 units. 05:00 07:00 2.00 5,422 7,439 PROD1 CASING TRIP P Continue RIH from 5422'to 7439'. Rotate and circulate through tight spot at 7130'.OK 07:00 07:30 0.50 7,439 7,553 PROD1 CASING REAM P Wash and ream from 7439'to 7553'. No fill. 07:30 10:30 3.00 7,553 7,553 PROD1 CASING CIRC P Circulate and condition mud. Stage pumps to 500 gpm-2700 psi-60 rpm. Max gas-650 units. CBU 4X. 2700 PSI, 28% Flow,MW 9.9 PPG in and out. Page 20 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 11:00 0.50 7,553 7,553 PROD1 CASING OWFF P Observe well. Static. 11:00 11:30 0.50 7,553 6,933 PROD1 CASING TRIP P POOH from 7553'to 6933'. Up Wt=165k, Dn Wt=110k,Monitor well. Static. Pump 20 BBL 1.5 PPG over dry job. 11:30 12:00 0.50 6,933 6,430 PROD1 CASING TRIP P Trip out of the hole from 6933'to 6430'MD. 12:00 15:00 3.00 6,430 3,430 PROD1 CASING TRIP P Trip out of the hole from 6998'to 3430'. 15:00 15:15 0.25 3,430 3,430 PROD1 CASING OWFF P Observe well for flow or losses. Static. 15:15 17:45 2.50 3,430 480 PROD1 CASING TRIP P Trip out of the hole to the HWDP. 17:45 18:00 0.25 480 480 PROD1 CASING OWFF P Observe well for flow.Static. 18:00 21:00 3.00 480 0 PROD1 CASING PULD P PJSM with Halliburton DD. Lay down all bottom hole components.Grade bit. 21:00 21:15 0.25 0 0 PROD1 CASING OWFF P Observe well. Static. 21:15 22:00 0.75 0 0 PROD1 CASING RURD P Drain stack. Make up 7"BTC x 4'% IF XO to 7"test joint. Make up wear ring puller. Hold PJSM with Vetco Gray wellhead hands. Pull wear ring out. 22:00 00:00 2.00 0 0 PROD1 WHDBO RURD P Change out upper pipe rams to 7" rams.Close blind rams. Line up choke, bleed off Koomey, keep hole full by pumping underneath blinds across HCR kill and choke. 08/03/2012 Change out Upper pipe rams to 7".Test.Dummy run with hanger. Rig up and run 7"26#L-80 BTCM casing to 6062'MD. 00:00 01:00 1.00 0 0 PROD1 WHDBO RURD P Finish change upper rams to 7". 01:00 02:00 1.00 0 0 PROD1 WHDBO RURD P RU test equipment. 02:00 02:30 0.50 0 0 PROD1 WHDBO BOPE P Test 7"rams to 250-4000 psi for 10 min.Chart test. 02:30 03:00 0.50 0 0 PROD1 WHDBO RURD P RD test equipment. Pull test plug. Dummy run 7"hanger. 03:00 06:00 3.00 0 0 PROD1 CASING RURD P RU 7"csg equipment. Install long bales. 06:00 06:30 0.50 0 0 PROD1 CASING SFTY P PJSM on running csg. 06:30 10:30 4.00 0 327 PROD1 CASING RNCS P RIH with 7"26#L-80 BTCM csg to 327'. Baker Lock and check floats. Install centralizers as per detail.lnstall stop rings and tandem rise centalizers on first three joints. One 5'above shoe,one each 10' below and above float collar. Install centralizers every other joint,free floating to joint 101.Torque connections to mark.Average torque=9,000 ft/lbs. 10:30 12:00 1.50 327 372 PROD1 CASING RNCS P Run casing to 372'MD. Page 21 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 372 3,800 PROD1 CASING RNCS P Run in the hole with 7"26#L-80 BTCM casing. From 372'to 3800' MD. Fill pipe each joint.Top off every 5.Good displacement. Run 2 to 3 mins per joint. Break circulation @ 2077'MD. Start with bleeder wide open and pinch back.3 BPM,200 PSI, 9%flow,circulate casing volume.Trip to the shoe.Good displacement. Break circulation as before.3 BPM, 11%flow 270 PSI. 18:00 00:00 6.00 3,800 6,062 PROD1 CASING RNCS P Run in the hole with 7"26#L-80 BTCM casing. From 3800'to 6062' MD. Fill pipe each joint.Top off every 5. Good displacement. Run 2 to 3 mins per joint. Break circulation @ 5401'MD.Start with bleeder wide open and pinch back.3 BPM, 350 PSI, 11%flow,circulate casing volume. No losses while circulating or tripping.0.8 BBLS under displacement. 08/04/2012 Run the 7"26#L80 BTCM casing to bottom. Land. Pump cement. Begin BOPE test. 00:00 02:00 2.00 6,062 6,684 PROD1 CASING RNCS P Continue RIH with 7"26#L-80 BTCM csg fro 6062'to 6684'. Up wt-170k. Dn wt 0 120k.Taking 250k to break over. 02:00 03:15 1.25 6,684 6,684 PROD1 CASING CIRC P Circulate 130 bbls at 3 bpm-380 psi. 03:15 06:15 3.00 6,684 7,542 PROD1 CASING RNCS P Continue RIH with 7"csg. MU hanger and landing jt. Land csg at 7542'. MU cement head. 06:15 09:00 2.75 7,542 7,542 PROD1 CEMEN-CIRCP Break circulation.Attempt to break pipe free at 275k with no success. Land hanger.Circulate and condition mud.Stage pumps from 3 bpm to 4 bpm-520 psi. CBU 2X. 09:00 12:00 3.00 7,542 7,542 PROD1 CEMEN-CMNT P PJSM. Flush mud pumps with 9.8 brine. Drop bottom plug. Baker 1 it Hughes pumped 3 bbls water.Tested G ,,y lines to 2500 psi. Pumped 41.6 bbls 00 10 ppg Seal Bond Spacer, 166 bbls 12 ppg cement,dropped top plug and pumped-5—bbls water. Rig displaced cement with 282.9 bbls 9.8 ppg brine at 4 bpm. Full returns throughout job. Did not bump plug. Shut in pressure -640 psi. Small amount spacer at surface. Page 22 of 22 ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: BRU 244-23 Rig Name: DOYON ARCTIC FOX Job Type: INITIAL COMPLETION Rig Accept: 8/4/2012 12:00:00 PM Rig Release: 8/15/2012 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/04/2012 24 hr Summary Bleed off pressure and test floats.Good.C/O UPR's.Test BOPE. 12:00 14:00 2.00 7,542 7,542 COMPZ WELLPF PUCM P Continue to monitor the well. Bleed off pressure. Floats good. Rig down BHI cementing equipment. 14:00 16:30 2.50 7,542 7,542 COMPZ WELLPF PRTS P Vetco/GE Install packoff and test to 5000 PSI. Good Test. 16:30 18:00 1.50 0 0 COMPZ WELLPF RURD P Change upper rams to 2 7/8"x 5" variables from the 7"solid body ram. Lay down long bales, pick up short bales and 4"elevators on Top Drive. 18:00 18:30 0.50 0 0 COMPZ WELLPFSVRG P Service Rig. Lubricate rig. 18:30 20:00 1.50 0 0 COMPZ WELLPF RURD P Hanag tongs,and make up testing equipment for up coming BOPE test. SIMOPS:Clean pits, haul Kla-Shield to BRWD. load pipe shed with 12 joints of HT 38 4"DP. Strap. 20:00 21:00 1.00 0 0 COMPZ WELLPF SFTY P Prejob safety meeting on testing BOPE. 21:00 00:00 3.00 0 0 COMPZ WELLPF BOPE P Begin BOPE test.Jim Regg, AOGCC waived witness of test on Aug 3rd @ 12:23 Hrs via email.Test all equipment to 250 PSI low,4000 PSI high 10 mins each test,charted, Annular test to 2500 PSI high.Test dart valve, kill HCR, upper pipe rams, choke valves 5,9,14,15.Crew change. 08/05/2012 Test BOPE.SIMOPS: Cleaning pits. Pumping fresh water through out rig plumbing system. Slip and cut drill line. Page 1 of 10 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 12:00 12.00 0 0 COMPZ WELLPF BOPE P Continue to test BOPE.Test 250 PSI low,4000 PSI high.Test with 4" test joint.Test#4,Top rams, manual kill, manual choke, lower IBOP.Test #5,Top rams, manual kill, manual choke, upper IBOP.Test#6. Bottom P ram.Test#7.Top rams,manual kill, Pp choke manifold valves 1,2,6,10. Test#8.Top rams, manual kill,choke manifold,choke valves 3,7,11. l Test#9.Top rams, manual kill,choke manifold valves 3,7,12.Test#10.Top pipe rams, HCR choke,4"Demco on kill line.Test#11.Top pipe rams,4" Demco on kill line, manifold valves 3,8,9,14,15. Change out pop off on test pump. SIMOPS: Building volume of brine and filtered water at BRWD. Cleaning pits,all solids control equipment. Stage MI Swaco downhole tools. 12:00 18:00 6.00 0 0 COMPZ WELLPF BOPE P Continue to test BOPE. Lay down 4" test joint and pick up 3W test joint. Test upper variable pipe rams.2 7/8" x 5".250 PSI low,4000 PSI high. Test annular preventer 250 PSI low, 2500 PSI high. Lay down 3W test joint. Pick up 4W test joint.Test upper VPRams.250 PSI low,4000 PSI high, annular, 250 PSI low,2500 PSI high.Attempt to test choke manifold valve#13. Failed. Mechanic replaced valve#13. 18:00 19:00 1.00 0 0 COMPZ WELLPF BOPE P Rig up to retest choke manifold valve #13. SIMOPS:Cleaning in the pit area, all components. Flush all surface equipment with fresh water, flush stack,top drive hose. Flush stack two times with stack washer. _ Operate rams. 19:00 19:30 0.50 0 0 COMPZ WELLPF BOPE P Retest choke maifold valve#13 and blinds,250 PSI low,4000 PSI high. Test finished. Rig down all testing equipment. 19:30 20:00 0.50 0 0 COMPZ WELLPF RURD P Set wear bushing.6.4375"ID. 20:00 22:00 2.00 0 0 COMPZ WELLPF RURD P Clean pits. Prepare to mix caustic wash for surface equipment. Service top drive,quill, blocks. 22:00 00:00 2.00 0 0 COMPZ WELLPF SLPC P Slip and cut 100'of drilling line. SIMOPS:Clean pits,4,5,6.Trip tank. Empty wash water out with super sucker.Top off both RFR up right tanks with filtered brine and filtered water. 0 Page 2 of 10 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 08/06/2012 24 hr Summary Slip and cur drill line. Perform 200 barrel caustic wash in pits and through out rig. Flush with 150 barrels fresh water. Dispose of all fluids to BRWD.Make up Swaco wellbore cleaning tools and trip in the hole to clean out the casing.Tag plug @ 7447'MD. Pump surface to surface. Prepare to pickle the drill pipe. 00:00 05:45 5.75 0 0 COMPZ WELLPF OTHR P PJSM. Empty and clean pits 1,2,3, trip tank and rock washer pits 1 and 2. 05:45 09:00 3.25 0 0 COMPZ WELLPF OTHR P PJSM. Mix 200 bbl caustic wash in pit 5(3 ppb caustic soda, 1 drum Safe Surf W, DF-9065). Continue cleaning rock washer. 09:00 10:30 1.50 0 0 COMPZ WELLPF OTHR P PJSM. Flush with caustic wash.: Mud pumps 1,2,3 hopper pumps, hopper lines,guns lines,trip tank, trip tank pump and lines, pits 4,5,6 standpipe,topdrive hose, BOP stack kill line choke manifold and poor boy degasser. 10:30 12:00 1.50 0 0 COMPZ WELLPF OTHR P Fill pit#5 with 150 barrels of fresh water,neutralize fluid in rock washer, transfer to open top tank. Flush with 150 barrels fresh water through out rig to remove the caustic wash.Mud pumps 1,2,3 hopper pumps, hopper lines,guns lines,trip tank,trip tank pump and lines, pits 4,5,6 standpipe, topdrive hose, BOP stack kill line choke manifold and poor boy degasser. 12:00 14:00 2.00 0 0 COMPZ WELLPF RURD P Continue to clean the rig and surface equipment, pits. Suck dry with vac trucks. Prepare to pick up BHA#1. 14:00 15:30 1.50 0 877 COMPZ WELLPF PULD P PJSM. Plck up MI Swaco well bore cleaning assembly. Pick up 6 1/8" cement mill and WBCT.TIH to 877 15:30 16:00 0.50 877 877 COMPZ WELLPF SVRG P Service rig. repair hydraulic swivel union 16:00 22:00 6.00 877 7,173 COMPZ WELLPF TRIP P Trip in the hole out of the derrick. 22:00 23:00 1.00 7,173 7,299 COMPZ WELLPF TRIP P Trip in the hole with singles. From 7173'to 7299'MD. 23:00 23:30 0.50 7,299 7,447 COMPZ WELLPF CIRC P Wash down from 7299'MD @ 3 BPM,220 PSI,22% Flow:Tag plug @ 7447'MD. 23:30 00:00 0.50 7,447 7,447 COMPZ WELLPF CIRC P Circulate surface to surface while rotating and reciprocating the WBCT assembly.6 BPM,80 RPM,890 PSI,9.7k TQ Page 3 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/07/2012 24 hr Summary Circulate surface T/surface, @ 80 RPM,TORQ 9.5,240 GPM,860 PSi, P/U 165, S/O 82, RT 110., PJSM w/ BJ, mix safety pickle, R/U return line T/rock washer to reverse circulate, L/D singel, blow down top drive, make up TIW valve W/head pin,chicksan,lo-torq valve to cement line,pump 5 bbl water and test lines to 2500 psi, pump working string pickle as per plan @ 7433', pump @ 42 gpm,20 bbl flo-vis spacer, 10.5 bbl safety pickle,69.5 bbl fresh water, ICP 90 PSI, FCP 497 psi,SIP 421 PSI, reverse circulate 300 bbl fresh water,@ 312 GPM, ICP 970 PSI, FCP 1400 PSI,final returns 54 NTU, PJSM,mix 3 lbs/bbl-40 bbl caustic pill, pump pill train,40 bbl caustic pill,40 bbl safe surf-W pill,40 bbl flo-vis pill, 100 bbl filter floc pill, displace pill train with 450 bbl 9.8 ppg kcl/nacl brine @ 318 gpm, 1350 PSI, PJSM, Rig up head pin and cement line, pressure test casing @ 4000 psi with BJ,(charted test), rig down testing equiptment, line up mud manifold, and stack for trip out of hole,Trip out of hole F/7,422 T/5727,dropp 2.25 rabbit,monitor hole fill on trip tank, continue tripping out of hole T/WBCT ASSY, retieve rabbit @ BHA,take pictures of ASSY, L/D assy, PJSM, rig up Halliburton W/L unit for bond logs, RIH with wire line logs. 00:00 02:30 2.50 7,447 7,447 COMPZ WELLPF CIRC P Circulate surface T/surface, @ 80 RPM,TORQ 9.5,240 GPM, 860 PSi, P/U 165, S/O 82, RT 110. 02:30 03:30 1.00 7,422 7,422 COMPZ WELLPF PRTS P PJSM w/BJ, mix safety pickle, R/U return line T/rock washer to reverse circulate, L/D singel, blow down top drive, make up TIW valve W/head pin,chicksan, lo-torq valve to cement line, pump 5 bbl water and test lines to 2500 psi. 03:30 05:30 2.00 7,422 7,422 COMPZ WELLPF OTHR P Pump working string pickle as per plan @ 7433', pump @ 42 gpm,20 bbl flo-vis spacer, 10.5 bbl safety pickle,69.5 bbl fresh water, ICP 90 PSI, FCP 497 psi,SIP 421 PSI 05:30 06:30 1.00 7,422 7,422 COMPZ WELLPF CIRC P Reverse circulate 300 bbl fresh water,@ 312 GPM, ICP 970 PSI, FCP 1400 PSI,final returns 54 NTU 06:30 07:30 1.00 7,422 7,422 COMPZ WELLPF CIRC P PJSM, mix 3 lbs/bbl-40 bbl caustic pill, R/D cement line,and head pin, make up top drive to drill string. • 07:30 08:30 1.00 7,422 7,422 COMPZ WELLPF CIRC P Pump pill train,40 bbl caustic pill,40 bbl safe surf-W pill,40 bbl flo-vis pill, 100 bbl filter floc pill • 08:30 09:45 1.25 7,422 7,422 COMPZ WELLPF CIRC P Displace pill train with 450 bbl 9.8 ppg kcl/nacl brine @ 318 gpm, 1350 PSI,80 rpm, 9.7 torq, 107 RT 09:45 12:00 2.25 7,422 7,422 COMPZ WELLPF PRTS P PJSM, Rig up head pin and cement line, pressure test casing @ 4000 psi with BJ, (charted test) 12:00 13:30 1.50 7,422 7,422 COMPZ WELLPF PRTS P Rig down testing equiptment, line up mud manifold, and stack for trip out of hole, PJSM on tripping out of hole. 13:30 17:30 4.00 7,422 62 COMPZ WELLPF TRIP P Trip out of hole F/7,422 T/5727, dropp 2.25 rabbit, monitor hole fill on trip tank, continue tripping out of hole T/WBCT ASSY, retieve rabbit @ BHA 17:30 18:00 0.50 62 0 COMPZ WELLPF TRIP P Take pictures of ASSY, L/D assy, total displacement 40.9 bbl 18:00 20:00 2.00 0 0 COMPZ WELLPF ELOG P PJSM, rig up HalliburtonW/L unit for bond logs 20:00 00:00 4.00 0 7,431 COMPZ WELLPF ELOG P RIH with wire line logs Page 4 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/08/2012 24 hr Summary Continue run Halliburton CAST tool from 7431'. RD Halliburton wire line,Send logs to ANC for evaluation, PJSM. remove bell nipple and riser. NU 11"5000 psi shooting flange,sent wireline crew to camp for rest,rig up riser,tee, pack off and sheaves for wire line F/CBL, pick up logging tools,Test lubricator @ 1500 psi, run in hole T/7435', pressure up to 1000 psi, log out of hole T/1000'above top of cement, bleed off psi and lay down tools and rig down wire line, nipple down shooting head and nipple up riser,fill up and bleeder lines T/ picture nipple, PJSM on picking up TCP guns, Prep 5"TCP guns and load in pipe shed,pick up 4 5/8"5 SPF Millennium guns, (39 g charge guns) 00:00 01:30 1.50 7,431 0 COMPZ WELLPF ELOG P Continue run Halliburton CAST tool from 7431'. RD Halliburton wire line. 01:30 03:30 2.00 0 0 COMPZ WELLPF OTHR P Send logs to ANC for evaluation. Clean pits 1 and 2. Rig housekeeping. 03:30 06:15 2.75 0 0 COMPZ WELLPF RURD P PJSM. Remove bell nipple and riser. NU 11"5000 psi shooting flange. 06:15 11:00 4.75 0 0 COMPZ WELLPF OTHR P Sent wireline crew to camp for rest. Continue general rig housekeeping. 11:00 13:00 2.00 0 0 COMPZ WELLPF ELOG P Rig up riser,tee, pack off and sheaves for wire line F/CBL,pick up logging tools,Test lubricator @ 1500 psi. 13:00 19:00 6.00 7,435 0 COMPZ WELLPF ELOG P Run in hole T/7435',pressure up to 1000 psi, log out of hole T/1000' above top of cement, bleed off psi and lay down tools and rig down wire line. 19:00 20:00 1.00 0 0 COMPZ WELLPF RURD P Nipple down shooting head and nipple up riser,fill up and bleeder lines T/picture nipple 20:00 21:30 1.50 0 0 COMPZ WELLPF PERF P PJSM on picking up TCP guns, Prep 5"TCP guns and load in pipe shed 21:30 00:00 2.50 0 0 COMPZ WELLPF PULD P Pick up 4 5/8"5 SPF Millennium guns, (39 g charge guns) 08/09/2012 PJSm, continue picking up 4 5/8 5 SPF Millenium 39 gram charge guns,per detail T 1374', rig up spinner hawks, clean and clear rig floor,trip in hole W/TCP guns on drill pipe F/1,347 T/6946, PJSM,drift 2 stands F/derrick, run in hole F/6946 T/7039, PJSM, make up pumping tee,dual pack off, rig up wire line sheaves, pick up gama-perf tools for tubing conveyed perf correlation,trip in hole w/wire line and correlate guns on depth, PJSM,set champ packer,slack off 35K T/verify,shut annular and line up to reverse circulate,drop bar and fire guns,open by pass and reverse circulate 1 1/2 drill pipe volumes @ 6 bbl/min,620 psi through choke,open annular and circulate 2 bottoms up down drill pipe @ 6 bbl/min @ 550 psi,29%flow,monitor well on trip tank, 1.2 BPH losses,trip out of hole @ 2 min stand monitoring hole on trip tank, monitor well @ 3406'F/30 min,vent gas breaking out of guns. (mud losses 8 bbls over calculated displacement) 00:00 04:30 4.50 0 1,347 COMPZ WELLPF PULD P PJSm,_c.ontin_ue pickingup 4 5/8 _ SPF Millenium 39 gram charge guns, per detail T 1374' 04:30 05:00 0.50 1,347 1,347 COMPZ WELLPF OTHR P Rig up spinner hawks, clean and clear rig floor 05:00 10:00 5.00 1,347 6,946 COMPZ WELLPF TRIP P Trip in hole W/TCP guns on drill pipe F/1,347 T/6946 10:00 10:30 0.50 6,946 7,039 COMPZ WELLPF TRIP P PJSM,drift 2 stands F/derrick, run in hole F/6946 T/7039, p/u 154,s/o 70 10:30 12:00 1.50 7,039 7,039 COMPZ WELLPF FLOG P PJSM, make up pumping tee,dual pack off, rig up wire line sheavers, pick up gama-perf tools for tubing conveyed perf corrlation. Page 5 of 10 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 7,039 7,039 COMPZ WELLPF ELOG P Continue corrlate guns on depth with wire line 14:00 15:00 1.00 7,039 7,039 COMPZ WELLPF PERF P PJSM,set champ packer,slack off 35K T/verify,shut annular and line up to reverse circulate,drop bar and fire guns. 15:00 17:00 2.00 7,039 7,039 COMPZ WELLPF CIRC P Open by pass and reverse circulate 1 1/2 drill pipe volumes @ 6 bbl/min, 620 psi through choke,open annular and circulat 2 bottoms up down drill pipe @ 6bbl/min @ 550 psi,29% flow 17:00 17:30 0.50 7,039 7,039 COMPZ WELLPF OTHR P Monitor well on trip tank, 1.2 BPH losses 17:30 00:00 6.50 7,039 COMPZ WELLPF TRIP P Trip out of hole @ 2 min stand monitoring hole on trip tank, monitor well @ 3406'F/3o min,vent gas breaking out of guns 08/10/2012 Trip out of F 1721 T/1347',make up acme co to joint of drill pipe,clear and clean rig rig floor, bring thread protectors for guns to floor, PJSM, lay down 4 5/8 5 SPF millennium guns F/1347,vent off gas @ connections as needed, remove xo's, From joint of drill pipe in shed, (20 bbl loss F/1721'),clear and clean rig floor of tools, PJSM, pick up 6.120 cement mill,Swaco burr mill and csg clean up tool,XO,trip in hole F/ 67'T/5729',wash F/5729 T/5844'@ 3 bbls/min,222 psi,670 rpm,7/8 torq, 0 wob, Ream and de-burr perforations F/5844 T/7063'wash down to 7100'-P/U 155K, S/O 80K, rot 104K,wash F/5729 T/5844'@ 3 bbls/min,222 psi,670 rpm, 7/8 torq, 0 wob, Ream and de-burr perforations F/5844 T/7063'wash down to 7100'-P/U 155K,S/O 80K, rot 104K 00:00 00:45 0.75 1,721 1,347 COMPZ WELLPF TRIP P Trip out of F 1721 T/1347' 00:45 01:15 0.50 1,347 0 COMPZ WELLPF PULD P make up acme co to joint of drill pipe,clear and clean rig rig floor, bring thread protectors for guns to floor 01:15 09:30 8.25 0 0 COMPZ WELLPF PULD P PJSM, lay down 4 5/8 5 SPF millnnium guns F/1347,vent off gas @ connections as needed, remove xo's, From joint of drill pipe in shed, (20 bbl loss F/1721') 09:30 10:00 0.50 0 0 COMPZ WELLPF PULD P Clear and clean rig floor of tools. 10:00 11:15 1.25 0 67 COMPZ WELLPF PULD P PJSM,pick up 6.120 cement mill, Swaco bur mill and csg clean up tool,XO 11:15 17:00 5.75 67 5,729 COMPZ WELLPF TRIP P Trip in hole F/67'T/5729' 17:00 22:30 5.50 5,729 7,063 COMPZ WELLPF REAM P Wash F/5729 T/5844'@ 3 bbls/min,222psi,670 rpm,7/8 torq, 0 wob, Ream and de-burr performations F/5844 T/7063'wash down to 7100'-P/U 155K, S/O 80K, rot 104K 22:30 00:00 1.50 7,063 7,100 COMPZ WELLPF TRIP P Monitor well, lay down 20 joint drill pipe monitor displacement on trip tank, 13.5 bbls lost F/tour Page 6 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/11/2012 24 hr Summary PJSM, continue laying down drill pipe F/5793 T/5477', pull stripping rubber, and run in hole with pipe out of derrick T/5790', PJSM, pump 90 bbl HEC-10 sweep,displace hole with clean 9.8 brine @ 201 gpm, 530 psi, 30 RPM,6.5 torq, RT 85,(pumped 265 bbls clean brine), blow down top drive,flo check well, drop 2.4"drift on wire,trip out of holeF/5790 T/129'standing back 91 stands in derrick, lay down de-burring tools and cement mill, PJSM, rig up tubing handling equipment, load pipe shed w/lower completion tools, M/U tiw valve to 3.5 ibtm xo for well control, PJSM with third party on picking up lower completion assembly, pick up 3 1/2 IBT 9.3#L-80 lower completion assy, install blast rings per talley, M/U premium PKR assy,selects flow screens, Halliburton frac door, RIH @ 90 sec per stand, P/U 35K,S/O 35K, PJSM, RIH w/completion assy on drill pipe to 5056.0 00:00 01:15 1.25 7,100 5,790 COMPZ WELLPF TRIP P PJSM,continue laying down drill pipe F/5793 T/5477',pull stripping rubber, and run in hole with pipe out of derrick T/5790' 01:15 03:15 2.00 5,790 5,790 COMPZ WELLPF CIRC P PJSm, pump 90 bbl HEC-10 sweep, displace hole with clean 9.8 brine @ 201 gpm, 530 psi, 30 RPM,6.5 torq, RT 85, (pumped 265 bbls clean brine) 03:15 03:30 0.25 5,790 5,790 COMPZ WELLPF TRIP P Blow down top drive,flo check well, drop 2.4"drift on wire. 03:30 08:30 5.00 5,790 0 COMPZ WELLPF TRIP P Trip out of holeF/5790 T/129' standing back 91 stands in derrick, lay down de-burring tools and cement mill 08:30 12:00 3.50 0 0 COMPZ WELLPF PULD P PJSM, rig up tubing handling equipment, load pipe shed w/lower completion tools, M/U tiw valve to 3.5 ibtm xo for well control 12:0012:30 0.50 0 0 COMPZ WELLPF SFTY P PJSM with third party on picking up lower completion assembly 12:30 19:30 7.00 0 0 COMPZ WELLPF PULD P Pick up_3 1/2 IBT 9.3#L-80 lower completion assy, install blast rings per talley, M/U premium PKR assy, selects flow screens, Halliburton frac door, RIH @ 90 sec per stand, P/U 35K,S/O 35K 19:30 00:00 4.50 0 5,056 COMPZ WELLPF TRIP P PJSM RIH w/completion assy on drill pipe to 5056.0 08/12/2012 Continue running in hole with lower completion F/5056 T/6640', Pull up to 6625 and set pipe in tension, P/U 140 K, S/O 77K, PJSM, install TIW valve, rig up lubircator, rig up test equip,test pack off and lubircator @ 1500 psi(charted), run in hole with wire line and correlate depth, rig down wire line sheives, lubircator, PJSM, pick up 15'pup jt, locate depth @ 5656,break circulation @ 120 gpm,240 psi,drop 1"steel ball, (ball drop 24min)pressure up drill pipe to 2500 psi F 5 mins,stage up to 4000 psi F/5 mins, bleed off pressure,pull 20K over, psi test ann T/1000 psi F/5 mins,attempt to release F/setting tool, pull 20K over,slack off 20K (no go)PSI drill pipe T/3000 psi,bleed off, pull 20K over slack off 25K, (no release)slack off 25K, psi up DP to 4000 psi,setting released P/U 117K S/O 67K, PJSM, Rig up to lay down drill pipe, blow down top drive and kill line, monitor well F/30 min, lubircate rotary table and draw works, pull out of hole laying down drill pipe F/4920 T/3453,flow check well F/30 min,continue laying down drill pipe,T/baker PKR running tool and lay down running tool, pull wear busing, load tubing in pipe shed. 00:00 02:15 2.25 5,056 6,625 COMPZ WELLPF RCST P Continue running in hole with lower completion F/5056 T/6640', Pull up to 6625 and set pipe in tension, P/U 140 K,S/O 77K, (3.5 bbls fluid loss) Page 7 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 05:30 3.25 6,625 6,625 COMPZ WELLPF RCST P PJSM, install TIW valve, bring wire line equipment to rig floor, install pumping tee and lubircator, rig up test equip,test pack off and lubircator @ 1500 psi(charted) 05:30 06:30 1.00 6,625 6,625 COMPZ WELLPF ELOG P Run in hole with wire line and correlate depth. 06:30 07:15 0.75 6,625 6,625 COMPZ WELLPF RCST P Rig down wire line sheives, lubircator _ and pumping tee, remove TIW valve. 07:15 10:00 2.75 6,625 5,656 COMPZ WELLPF PACK P PJSM,pick up 15 pup jt, locate depth @ 5656, break circulation @ 120 gpm,240 psi,drop 1"steel ball, (ball drop 24min)pressure up drill pipe to 2500 psi F 5 mins,stage up to 4000 psi F/5 mins,bleed off pressure, pull 20K over, psi test ann T/1000 psi F/5 mins,attempt to release F/setting tool, pull 20K over, slack off 20K(no go)PSI drill pipe T/ 3000 psi, bleed off, pull 20K over slack off 25K, (no release)slack off 25K, psi up DP to 4000 psi,setting released P/U 117K S/O 67K 10:00 11:00 1.00 5,656 5,656 COMPZ WELLPF PULD P PJSM, Rig up to lay down drill pipe, blow down top drive and kill line, monitor well F/30 min 11:00 13:00 2.00 5,656 4,920 COMPZ WELLPF PULD P Pull out of hole laying down drill pipe F/5697 T/4920, P/U 103 K,S/O 63 K 13:00 13:30 0.50 4,920 4,920 COMPZ WELLPF SVRG P Lubircate rotary table and draw works 13:30 14:30 1.00 4,920 3,453 COMPZ WELLPF PULD P Pull out of hole laying down drill pipe F/4920 T/3453 14:30 15:00 0.50 3,453 3,453 COMPZ WELLPF OWFF P Flow check well F/30 min 15:00 21:00 6.00 3,453 0 COMPZ WELLPF PULD P Continue laying down drill pipe,T/ baker PKR running tool and lay down running tool 21:00 21:30 0.50 0 0 COMPZ WELLPF OTHR P Pull wear busing 21:30 00:00 2.50 0 0 COMPZ WELLPF RCST P Load tubing in pipe shed, 08/13/2012 PJSM,continue loading 145 joints 4.5 tubing in pipe shed, bring cannon clamps to rig floor, (130 single line, 20 double line), 10.874 X 4.5 vetco MB-230 hanger,control line and injection line sheives and hang in derrick, emove 4.5 IBTM X 3.5 EUE xo,eait on 3.5 EUE tubing pups, make up 6.17 and 4.11 tubing pups,to top of baker GBH-22 seal assy, bevel bottom of collars on 6.11 pup joint, make up 4.5 IBTm X 3.5 EUE XO, PJSM, make up upper completion assy per running order,XN nipple, DCK-2 shear valve, 1 joint 4.5 tubing, chemical injection sub, 1 joint 4.5 tubing,pick up and run 4.5 12#L-80 IBTM tubing, installing cannon clamps every joint, monitor tubing displacement on trip tank, run in hole to 5245', pick up SSSV and rabbit SSSV with rod and ball, make up SSSV and test @ 5000 PSI for 10 min. 00:00 07:00 7.00 0 0 COMPZ WELLPF RCST P PJSM, continue loading 145 joints 4.5 tubing in pipe shed, bring cannon clamps to rig floor, (130 single line, 20 double line), 10.874 X 4.5 vetco MB-230 hanger, control line and injection line sheives and hang in derrick. Page 8 of 10 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07:00 11:00 4.00 COMPZ WELLPF RCST T Remove 4.5 IBTM X 3.5 EUE xo,eait on 3.5 EUE tubing pups,make up 6.17 and 4.11 tubing pups,to top of baker GBH-22 seal assy, bevel bottom of collars on 6.11 pup joint, make up 4.5 IBTm X 3.5 EUE XO 11:00 12:00 1.00 COMPZ WELLPF RCST P PJSM,make up upper completion assy per running order,XN nipple, DCK-2 shear valve, 1 joint 4.5 tubing, chemical injection sub, 1 joint 4.5 tubing 12:00 00:00 12.00 COMPZ WELLPF RCST P Pick up and run 4.5 12#L-80 IBTM tubing, installing cannon clamps every joint, monitor tubing displacement on trip tank, run in hole to 5245', pick up SSSV and rabbit SSSV with rod and ball, make up SSSV and test @ 5000 PSI for 10 min 08/14/2012 PJSM,continue running upper completion T/5647,make up top drive on jt#139 and break circulation, locate seal bore @ 5683.5(tubing depth), PJSM,pump 105 bbls 9.8 inhibited brine chased with 86 bbls 9.8 filtered brine @ 189 gpm, 330 psi, monitor well F/30 min,break out XO, P/U 1 jt.tubing, RIH and tag no go @ 5708', lay down 3 jts tubing,p/u 3 pup jts(9.77-9.81 -7.78)for space out, p/u 1 jt tubing, make up Vetco MB230-10.875 X 4.5 hanger,make up landing joint,terminate control&chemical lines, land hanger(p/u 103K,s/o 60K), run in lock downs,test hanger seals @ 250 low,5000 hi,clear rig floor of tubing handling equip,make up head pin in landing joint, PJSM, pressure IA U 1500 psi confirm seals are stabbed in,test tubing @ 3000 psi F/30 min, pressure tubing to 4850 psi and shear ball seat,monitor well, remove head pin, make full open safety valve, lay down landing joint, set BPV. 00:00 02:15 2.25 5,245 5,683 COMPZ WELLPF RCST P PJSM,continue running upper completion T/5647, make up top drive on jt#139 and break circulation, locate seal bore @ 5683.5(tubing depth) 02:15 03:00 0.75 5,683 5,668 COMPZ WELLPF CIRC P PJSM,pump 105 bbls 9.8 inhibited brine chased with 86 bbls 9.8 filtered brine @ 189 gpm, 330 psi 03:00 03:30 0.50 5,668 5,668 COMPZ WELLPF OWFF P Monitor well F/30 min. 03:30 08:30 5.00 5,668 5,708 COMPZ WELLPFTHGR P Break out XO, P/U 1 jt.tubing, RIH and tag no go @ 5708', lay down 3 jts tubing, p/u 3 pup jts(9.77-9.81 - 7.78)for space out, p/u 1 jt tubing, make up Vetco MB230-10.875 X 4.5 hanger, make up landing joint, terminate control&chemical lines, land hanger(p/u 103K,s/o 60K), run in lock dwons,test hanger seals @ 250 low,5000 hi,clear rig floor of tubing handling equip,make up head pin in landing joint. 08:30 11:00 2.50 COMPZ WELLPF PRTS P PJSM,pressure IA U 1500 psi confirm seals are stabbed in,test tubing @ 3000 psi F/30 min, pressure tubing to 4850 psi and shear ball seat. 11:00 11:30 0.50 COMPZ WELLPF OWFF P Monitor well. Page 9 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 COMPZ WELLPF PULD P Remove head pin, make full open safety valve, lay down laning jooint, set BPV 12:00 13:30 1.50 COMPZ WELLPF PRTS P Pressure test landing jt.xo, and LTV @ 3000 psi F/5 min against-MC, lay down landing joint, pull TWC, pick up landing jt.drop ball and rod, 13:30 15:00 1.50 COMPZ WELCTI PRTS P Pressure test tubing @ 3000 psi F/ 5min against ball, (seat good)rig up hose from tubing to pits, check for flow, Rig up to pump down 4 1/2 X 7 annulas, pressure up T/2600 psi to shear DK 2 valve 15:00 17:00 2.00 COMPZ WELLPF PRTS P Lay down landing jt.set BPV, pump down 4 1/2 x 7 annulas,pressure up to 3000 psi F/30min, rig down landing joint and associated equip, rig down weatherford tools, blow down surface lines 17:00 17:30 0.50 COMPZ WELLPF NUND P Function rams and flush cavities, drain stack. 17:30 00:00 6.50 COMPZ WELLPF NUND P Remove drilling nipple,flo line& associated equip, R/U patato masher, remove choke and kill lines, clean stack,remove single gate,mud cross,double gate, &hydrill, clean pits 08/15/2012 Continue ND BOP's. INstall Dry hole tree and test same to 5000 PSI. Contnue clean pits,and suck out containments. Secure wellhead and cellar. Rig released at 12:00 HRS. CPAI released operational control to Doyon Drilling at 12:00 HRS. 00:00 12:00 12.00 COMPZ RPCOM NUND P Continue ND BOP stack. Install dry hole tree,and test same to 5000 PSI as per Vetco Grey rep. BPV is installed and tested. Secure wellhead and cellar. Rig released at 12:00 HRS. CPAI released operational control to Doyon drilling at 12:00 HRS. Page 10 of 10 RPU 244-23 Post Rig Well Work Summary DATE SUMMARY 8/17/12 De-Mob Rig & Equipment., Organise dunnage around location, raise all skid end landings, lower hand rails on power skids, remove hand rails on hopper house, and secure in pump house, remove all hand rails, load and secure equipment in pipe shed, re arrange equip in pipe tubs, remove hoses F/ DS sub, install rotary beams, finish securing derrick, draw works skid, remove draw works stack, secure motor stacks, load out fuel skid, boiler skid, Gen#1 & 2, pumps 2 & 3, remove mats, herculite and felt, load out pump#1, lower roof on suction pit, remove shakers, and possum belly. f$0,v ��v 8/18/12 Remove derrick from sub. remove draw works skid F/sub, split sub base, load out derrick, draw works skid, sub bases, load out misc. rig equipment, pick up mats and herclite, load out 0161 doyon equip & rental equipment on barge. 8/19/12 Continue Demob, and clean up pad., load out trailers with misc. equipment 8/23/12 Felt and base Herculite all laid out. Began mob of Rain-for-Rent frac tank farm coordinating Hand-Y-Berm containment assembly. Positioned physical and visual barriers surrounding existing well houses within job site. Laid out frac tree and Vetco Grey equipment for N/D dry- hole tree and N/U frac tree. Mob'd 65-ton crane to J-Pad for tree-swap operations. De- mob'd Drilling's accommodations. 8/24/12 Nippled down dry-hole tree and nippled up frac tree, Pressure tested frac tree to 10k-psi. Mob'd frac equipment and began spotting up. Staged CTU and combi pump. Began rig-up of office/sleeping accomodations. 8/25/12 Completed hook-up of telecoms and utilities to office/sleeping trailers and Site Control. Spotted light plants around pad. Loaded all six frac tanks with fresh water; began heating water to 90-deg F. Completed all Hand-Y-Berm containment assembly. Spotted flow-back tanks. Spotted Data-Van, Wolverine pumps, and Rhino T pumps. Spotted 65T crane, CTU, combi/N2 pump, and chemical trailer. Began rigging-up equipment. Conducted SLT Meeting. 8/26/12 Completed rig-up of fracturing unit, treating iron, CTU, combi/N2 pump, PRVs, and flowback. Equipment status on location is ready to frac. Began hauling in product and mixed KCI in the two of six loaded frac tanks that had been heated. Partially loaded proppant into Sand King. 8/27/12 Safety stand down, Standing by for PEAK safety investigation. 8/28/12 Safety stand down, Standing by for PEAK safety investigation. 8/29/12 Safety stand down, Standing by for PEAK safety investigation. 8/30/12 Safety stand down, Standing by for PEAK safety investigation. 8/31/12 Safety stand down lifted. Continue to prepare location for frac operations. Add KCL to frac water, load proppant. 9/1/12 Performed preliminary slick-line operations, Continue to KCI frac water and load proppant. R/U E-line and RIH to perforate the lower most I sand interval from 7,096'-7,108' RKB w/2.5" {vl through tubing guns with millenium charges , 6 spf. R/D E-line 9/2/12 Perform DFIT test on Lower I sand intervals 7030'-7042' & 7096'-7108' RKB. Placed 90,253 lbs of 20-40 RC Ceramic proppant in the formation and left 9,952 lbs in the casing for the isolation plug for stage 2. 942 Bbls of 6% KCI based frac fluid. 9/3/12 Pressure testd sand plug to 4,000 psi. Tagged plug at 7,000'wlm. Perforated the upper I sand interval 6,686'-6,700'with 2.5" through tubing guns, 6 spf millenium charges. Performed DFIT test, replaced frac sleeve and frac'd the upper I sand interval. Placed 91,642 lbs of RC Ceramic proppant in the formation with 897 Bbls of 6% KCI based frac fluid. 9/4/12 Performed weekly BOPE test(test witness waived by Jim Regg, AOGCC). Performed 'tom cleanout with 2.125 Vortex nozzle to 7442' CTM, pumping 6% KCL at 2 BPM. Rig down coiled tubing. 9/5/12 Rigged slickline and pulled frac sleeve. Tagged top of fill @ 7424' SLM, located tubing tail, flagged wire. Discovered wireline adaptor appears to have damaged threads; sent to Kenai for redress/inspection. New adaptor being machined, on hold until materials flights resume (shut down due to high winds). Performed Wells Safety Standdown; good discussion and feedback. 9/6/12 Set Baker composite bridge pi,— with HES DPU at 6613' RKB. P/T tubing to 5000 psi; pass. Open frac door at 6540'. Wire unit lost PTO while coming out of hole; Ie eveloped in lubricator at Otis connection above W/L valve. Close wireline valve. Spot in second wireline truck, clamp wire, cut and retie to 2nd truck. Spool tools out of hole. Replace lubricator 0- ring, P/T and set frac sleeve 459'. Perform DFIT, pumping 20 bbls KCL. Analyse data. Shut down for night. 9/7/12 Performed stage 3 frac job in the lower H sand at 6,563'-6,571' RKB. Placed 68,000 lbs of the planned 90,000 lbs of 20-40 RC Ceramic proppant in the formation. Momentarily lost pump rate 3/4 throught the 1-6 ppa ramp stage which led to a screen out trend 1 tubing displacement later. Flush called after the 1-6 ppa ramp stage. 65 of the 94 bbl displacement was achieved before screenout the screenout pressure of 5,200 was reached. 4,064 lbs of proppant were left in the tubing. R/U CT and RIH to cleanout proppant to the composite BP at 6,616'. R/U slick-line and performed a tag at 6.454' slm, 90' higher than the required depth to close the frac sleeve. 9/8/12 Performed CTU cleanout to 6600' CTM using 2-1/8"Vortec nozzle and FW 6% KCL. Held 500 psi, 160 psi over SITP, on well throughout job while washing @ 2 bpm. Rig up slickline and tag top of fill @ 6452' SLM, 2' higher than previous tag, with 1.75" bailer. Tag again with 2.65 cent and 1.75 bailer with chisel tip in same spot; sticky/lose spangs. POOH and check tools; recovered frac sand. Review options. Run back in hole with coiled tubing and repeat cleanout @ 2 BPM, holding 700 psi WHTP, forcing slight losses to formation. Tagged top of composite plug at 6616' CTM. Rigged up slickline pulled frac sleeve and tagged top of fill w/ shifting tool at 6433' SLM, 19' HIGHER than pre-FCO tag. Pressure well to 2000 psi; monitor. Plug is solid. Discuss options and shut down for night. 9/9/12 Tested tbg against sand plug to 4000 psi; monitored for 10 mins, held solid. Rigged slickline and opened frac door at 6335', installed frac sleeve. Attempt to P/T treating iron &encounter leak-off; troubleshoot. Perform DFIT. Shut down for the night. 9/10/12 Attempted to troubleshoot leaking treating line PRV. Baker unable to locate re-dress kit to rebuild/repair valve, no other valve available in Alaska to swap. Break out valve from hardline and send to shop. Frac on hold until valve is repaired. 9/11/12 Sent out PRV to Baker shop in Nikiski for rebuild. Finished loading frac tanks with freshwater and mixed 6% KCI in all. Heated tanks back to 80-deg F. Baker redressed PRV and sent back to location. Rigged PRV back into treating iron. Pressure tested treating iron and function tested PRV; all good. Prepared to pump Stage 4 frac in the morning. 9/12/12 Performed Stage 4 fracture treatment in the upper H-sand interval (3-1/2"frac door at 6335'), pumping 814-total-bbls of linear and crosslink gel (20# Lightning 2000), and 54,540-total-lbs 1011 of 20-40 ZG PolarProp resin-coated proppant, continually increasing sand concentration from 1.0-5.0 PPA. Called flush early at 5 ppa due to screen out trend. Pumped full flush of 92-bbl; observed ISIP 3390-psi. Rigged up slickline and RIH shifting tool to close frac door; set down initially 5781', but dropped down through with subsequent 2-1/2" bailer. Reran shifting tool and attempted closing frac door. After unsuccessful pressure test of tubing, ran BO upshift tool with good indication of closure on automatic release; POOH BO tool and obtained passing pressure test of tubing using combi pump with slickline off of well. 9/13/12 Performed Stage 5 fracture treatment in the upper G-sand interval (3-1/2" frac door at 5778'), pumping 1419-total-bbls of linear and crosslink gel (20# Lightning 2000), and 140,171-total- lbs of 20-40 ZG PolarProp resin-coated proppant, continually increasing sand concentration from 1.0-6.0 PPA with extended 1-and 6-PPA stages. Pumped full flush of 90-bbl; observed ISIP 2360-psi. Performed coiled tubing BOPE test(AOGCC waived witness). Rigged up slickline; pulled isolation sleeve from SSSV, then closed frac door at 5778' using BO shifting tool. Begin hauling out Class I and Class II fluids for disposal. 9/14/12 Performed coiled tubing fill clean-out to 6613' pumping 6% KCI at 2-bpm, 60n-psi WHP and 5k-psi CTP. Maintained 1:1 r is throughout cleanout; observed dark re >with bottoms up but unable to grab sample or solids from returns steam with strainer. Tagged down solid on bridge plug twice and pulled out of hole maintaining 2-bpm and 1:1 returns. Stabbed off CT and ran in hole slickline with BO selective shifting tool. Tagged down at 6345' and pulled heavy with jar lick to come up. Pulled out of hole catching every sleeve above on the way out, mostly having to jar up once or twice to pull free; from about 2000' began catching collars, and from 1200' catching every/every-other collar on the way out(jar up once twicw and free). Ran 2-1/4"drive down bailer with flapper catch; set down in same spot. Drove down 2-3' but did not obtain sample once back at surface due to flapper staying open. Ran in hole with 2-1/4" drive down bailer with ball catch and obtained full bailer of formation fines. 9/15/12 Performed coiled tubing milling job, pumping 6% KCI at 1.75-bpm, 600-psi WHP and 5k-psi CTP; 1:1 returns. Ran in hole 2-1/4" motor/mill assembly with 2.65" 5-blade convex junk mill. Milled plug at 6613' until free and pushed down out of tubing tail to TD. Pulled out of hole following design. Blew down CT reel with N2 to tanks. Continued rigging down frac equipment and prepped equipment for mobilization. Moved doghouse/break-trailer to K-pad for Weatherford flowback. 9/16/12 Stood by due to high winds until afternoon. Rigged-up slickline and ran in B shifting tool to close lowermost frac door and confirm all other frac doors closed. Ran in 2-1/4" bailer and tagged bottom at 7495' SLMD. Ran B shifting tool to open all Select-a-Flow production sleeves. Installed 3.735" PX plug in the 4-1/2"X-profile at 5618'; x-line setting tool hung up in SSSV nipple on way out of hole. Tried to work free but pulled out of rope socket leaving setting tool in well. Stood by for wind again in evening. 9/17/12 Ran in slickline with 1.75" JD fishing tool (2.25" OD) to fish plug setting BHA (1.75" OD with 3.62" OD x-line setting tool). Fell clean through SSSV nipple then set down at 1018' SLMD. Pulled up to confirm latch but unable to spang or jar up. Also unable to pull out of hole with straight pull. Confirmed problem not associated with upper sheave or stuffing box. Dropped cutter-bar and pulled wireline out of hole. Attempted fishing cutter-bar with JD but unable to latch. Ran lead impression block and obtained clear picture of fishing neck along perimeter of the LIB. Made grab runs to attempt to centralize cutter-bar; appear to be able to manipulate cutter-bar, but still unable to latch with JD. Lay down for night. 9/18/12 Slickline fished wireline cutter-bar from 999' and fishing tools from 1018' SLMD. Ran in and encountered x-line setting-tool BHA at 2800' SLMD. Fished setting tools; no plug body on toolstring at surface. Fished PXN plug body from 2840' SLMD; three seals off plug body at surface. Ran in gauge ring to drift 4.5" tubing but unable to work down through 2840' SLMD with 3.810" gauge ring. Organized 3.810" swage to be sent from Pollard Kenai to location tomorrow. 9/19/12 Stood by for wind. Stood by for flight in of 3.810" swage and brush tools. 9/20/12 Slickline ran in hole with 4" braided-line brush to 2840'; brush-n-flushed 2800-2900' pumping 6% KCL 1-bpm. Ran in hole 4" brush and tagged XN profile at 5618'. Drifted well with 3.810" gauge ring down to tag at XN profile at 5618'; drifted clean through 2840', no problems. Ran in with 4.5" PXN plug (3.81" OD); no problems through 2840'. Set down 5529'; unable to work down. POOH plug seeing collars from 2400'; catching nearly every collar from 1200' with 1-2 jar licks to pull up (similar 9/14/12). Out of hole inspected plug; no damage. Ran in hole 2.81" PX plug and set in X profile at 5734'. Ran in prong and set in PX plug. Ran in 4' kick-over tool with 1-1/4" JDS pulling tool; latched DMY valve in side-pocket mandrel at 5591'. Recorded WHP 411-psi. Bled WHP to 0-psi and watched for zero 20-min as indicator of good plug set. Pressure tested plug from the top to 1500-psi and watched for 10-min; all good. Bled tubing to 350-psi WHP and pulled DMY valve. Laid down slickline. Rigged up N2 transport and N2/combi pump to IA and pumped 180,000-scf N2 taking returns through the open mandrel, up tubing to surface tanks. Bled down N2 to zero and performed 3 9/21/12 Opened lower master valve an HCR valve and observed 12-psi on well from thermal expansion of N2 over night. I down tubing to zero and performed secc D-min drawdown test on downhole plug; 0-psi after 30-min. Closed master, HCR, r5, swab, and rigged down CT BOPE and buffalo frac head from tree. Rigged up Vetco Gray and installed BPV in tubing hanger. Rigged down Vetco Gray, isolated well and pumped 238,000-scf N2 down IA, through open mandrel at 5591', to tubing, against BPV from below(direction of flow). Pressure tested BPV to 3000-psi; observed and charted a tight test starting 2990-psi IA and 28-psi in tree above BPV(saw 28-psi early due to N2 bleed as pop-it closed at slow N2 rate). Held tight entire test; after 30-min, 2980-psi IA and 28-psi WHP. Bled down N2 pressure to tanks. Nippled down 10k-psi frac tree; nippled up 5k production tree. Pressure tested production tree to 5000-psi for 10-min using 6% KCI. Rigged up Vetco Gray and removed two-way check from tubing hanger. 9/22/12 Rigged up slickline and equalized tubing pressure across plug; pulled prong from plug body at 5734'. Pulled 3.5" plug body from X-profile at 5734'. Set orifice valve in gas lift mandrel at 5529'. Installed isolation sleeve across BP6i SCSSSV profile at 459'. Well ready for tie-in and flowback. 9/23/12 Facilities performing excavation and tie-in work 9/24/12 Facilities performing excavation and tie-in work 9/25/12 Finish facilities tie-in and begin spotting Expro well test equipment. 9/26/12 Rigging up EXPRO equipment on "J" pad 9/27/12 Rigging up EXPRO equipment on "J" pad -about 90% complete 9/28/12 EXPRO equipment rigged up and pressure tested - begin flowing well in morning. 9/29/12 Flowing well with 436 psi FTP, gas rate at 05:30 on 44/64th choke 2.30 MMscfd, —934 bwpd , salinity 23000 ppm 9/30/12 Flowing well with 409 psi FTP, gas rate at 05:30 on 40/64th choke 2.45 MMscfd, —507 bwpd , salinity 19000 ppm 10/1/12 Flowing well with 420 psi FTP, gas rate at 05:30 on 40/64th choke 2.86 MMscfd, —556 bwpd , salinity 13000 ppm 10/2/12 Flowing well with 475 psi FTP, gas rate at 05:30 on 40/64th choke 3.57 MMscfd, —480 bwpd , salinity 12000 ppm 10/3/12 Flowing well with 506 psi FTP, gas rate at 06:00 on 40/64th choke 3.99 MMscfd, —371 bwpd , salinity 12000 ppm 10/4/12 Flowing well with 514 psi FTP, gas rate at 06:00 on 40/64th choke 4.14 MMscfd, —326 bwpd , salinity 12000 ppm 10/5/12 Flowing well with 529 psi FTP, gas rate at 06:00 on 40/64th choke 4.42 MMscfd, —326 bwpd , salinity 10000 ppm 10/6/12 Flowing well with 543 psi FTP, gas rate at 06:00 on 40/64th choke 4.66 MMscfd, —420 bwpd , salinity 11000 ppm 10/7/12 Flowing well with 545 psi FTP, gas rate at 06:00 on 40/64th choke 4.80 MMscfd, —187 bwpd , salinity 10000 ppm 10/8/12 Flowing well with 552 psi FTP, gas rate at 06:00 on 40/64th choke 5.00 MMscfd, —186 bwpd , salinity 10000 ppm 10/9/12 Flowing well with 563 psi FTP, gas rate at 06:00 on 40/64th choke 5.12 MMscfd, —184 bwpd , salinity 9000 ppm 10/10/12 Flowing well with 547 psi FTP, gas rate at 06:00 on 42/64th choke 5.35 MMscfd, —327 bwpd , salinity 10000 ppm 10/11/12 Flowing well with 556 psi FTP, gas rate at 06:00 on 42/64th choke 5.44 MMscfd, —232 bwpd , salinity 8000 ppm 10/12/12 Flowing well with 562 psi FTP, gas rate at 06:00 on 42/64th choke 5.60 MMscfd, —233 bwpd , salinity 8000 ppm 10/13/12 Flowing well with 772 psi FTP, gas rate at 06:00 on 64/248th choke 5.90 MMscfd, , salinity 8000 ppm. Diverted well to production. 10/14/12 Rigging down EXPRO equipment should start loading trucks this morning. 10/15/12 Finished racking up all the pipe, Loaded equipment onto trailers, 4 EXPRO personnel traveling home today. Well flowing at 5.6 MMSCFD with 782 psi FTP on a 64/248th choke. Last Report I ' &l.t (t. 4.t)-e- %44 -z--5 Regg, James B (DOA) (Z-0(910 From: NSK Prod Engr Specialist[n1139@conocophillips.com] Sent: Friday, October 19, 2012 4:38 PMC�(q. To: Regg, James B (DOA) Cc: BRU Supv; DOA AOGCC Prudhoe Bay; Buck, Brian R Subject: RE: BRU Testing, BRU 244-23 extension to 14 day clock Attachments: SVS BRU 10-12-12 String1 MISC.xls Attached you will find the miscellaneous SVS test report for BRU 244-23 pilot and SSV performed on 10/12/12. Bob Christensen I Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska,Inc. Kuparuk Office: 907.659.7535 Kuparuk Pager:659.7000; #924 CPAI Internal Mail: NSK-69 This email may contain confidential information.If you receive this e-mail in error,please notify the sender and delete this email immediately. From: Regg, James B (DOA) [mailto:jim.regg©alaska.gov] Sent: Friday, October 19, 2012 12:58 PM To: Buck, Brian R Cc: BRU Supv; Christensen, Robert D; DOA AOGCC Prudhoe Bay Subject: [EXTERNAL]RE: BRU Testing, BRU 244-23 extension to 14 day clock Your request to delay installation and testing of the subsurface safety valve (SSSV) in BRU 244-23 (PTD 2120690) is approved; it should not be understood to give any blanket approval for future situations that are similar. You are reminded that the regulatory purpose behind allowing up to 14 days to install SSSV is not related to the availability of equipment/personnel; it is tied to completing well intervention work that requires removal of the SSSV, and allowing time for the well to clean up and stable flowing conditions to be established prior to SSSV installation. BRU 244-23 should not have been put on-line to facilities until all equipment and personnel were available. You must have a functional SVS in place to operate the well by regulation, and for Beluga, that includes a SSSV. Since BRU 244-23 was placed on line 10/7 and presumably passed its low pressure pilot and surface safety valve (SSV) tests,AOGCC will allow the well to remain in production until 10/28 as requested. If you have not sent AOGCC the miscellaneous SVS test report for BRU 244-22 pilot and SSV, please do so as soon as possible. The low pressure pilot and SVS will need to be retested when AOGCC visits Beluga on 10/20/12. Please confirm that all safety valve system-related equipment is available at Beluga for placing the SSSV in operation by 10/28. We agree that the deep gas lift installations at Tyonek should continue uninterrupted. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: Buck, Brian R [mailto:Brian.R.BuckPconocophillips.com] Sent: Wednesday, October 17, 2012 5:27 PM To: Regg, James B (DOA) Cc: BRU Supv; Christensen, Robert D Subject: BRU Testing, BRU 244-23 extension to 14 day clock 1 • Jim- As discussed, here is my written request for a 7 day extension of the 14 day clock on BRU 244-23 to install the SSSV. The 14 days to install the SSSV is over on 10/21/12. We are requesting an extension to 10/28/12. We brought the well online to facilities on 10/7/12. We tested the Surface Safety valve successfully. At that time, we had slickline available to install the safety valve at Beluga, but the safety valve surface panel was not complete, so we had to delay that work. We began work on A-14 deep gas lift(DGL) on the Tyonek on 10/10/12. We are still progressing DGL work on the platform and hope to be done with the Tyonek wellwork (according to the latest schedule) on —10/21/12. As with any wellwork, that is an estimate. It is a multi-day operation of course, and the recommended plan is to not stop in the middle of the work. We were planning to head to Beluga to start the 244-23 wellwork, which includes installing a SSSV, immediately following the deep gas lift work on Tyonek. The only slickline crew and wellwork supervisor available to us in Cook Inlet are on the platform working on A-14. Therefore, we are requesting a 7 day extension to the 14-day clock to get this work done. Please reply via email if you accept this proposal for BRU 244-23. I also confirmed with the BRU Supervisor that all SVS tests in addition some meter work are being planned on 10/20/12 as you thought. Please let me know if you have any additional questions or concerns. Thank you, Brian Buck Cook Inlet Reservoir Engineer office: 907-265-6826 cell: 907-223-6320 700 G St., ATO-932; Anchorage, AK 99501 2 . • \ Z, L) .... \ / \ / � � � /_ § / A 3 / , \ u = kCA / \ ¥ col( / \ � _ / � OM % § \ /-.q . a 3>. S _ % 3 / < / & 300 N — ; z \ % R } 7 I* _ - Q / k 9 tO / « w ] 77,1 f § , } ; ) \ % \ \ a a 7) g 'Q § > tcn L. / § £ \ { \ e (-q- c.) k / q U & e• - ® c •4. ft • \ § 0 0. ƒ / 0 � . \ ; 0 , _ u .1 in ' .4- \j co 2 / v - \ ¢ °- a .- k `d e ƒI ) / co 2 ® $ k � : ~ -0 o N "0 2 % J m A 7 2 i / % 3 2 \ 2 \ 0 — EL 3 q = t 'k \ 7 / § es 4 U 3 & $ cn / 0 k k k . \ k \ eq - \ 0< ( o , \ /%Ez $ M yRECEIVED ConocoPhillips OCT 16 2012 TRANSMITTAL AOGCC CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave, Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3539 RE: BRU 244-23 AOGCC permit: 212-069-0 DATE: 10/15/2012 Tr.n mi -d: Beluga River Unit, Alaska BRU 244-23 CD and hardcopy report - r/End of Well report, Mud logging report, Halliburton; BRU 244-23(502832016500);August 4,2012 General information, daily summary, morning reports, bit data, mud report, formation tops, survey report, days vs. depth Final logs, Halliburton Log Viewer, EMF Log Viewer, EOW report in .pdf, ADI backsup II Sign, scan and return electronically to Sandra,D.Lemkec )Conocophiiiips com CC: BRU 244-23 transmittal folder, production well files, eSearch Receipt: Date: f '? .1-1.5 11 �x � G75-Technical Data Management E ConocoPhillips I Anchorage, Alaska )Ph: 90 265.5947 19 I WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 14, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record/Jewelry Log: BRU 244-23 Run Date: 9/1/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU 244-23 LAS Data, Digital Log Image file 1 CD Rom 50-283-20165-00-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Li. a...ez,4_ Date: 10 '"?.-2- t,2 Signed: 1,Q2i, WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 13, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Circumferential Acoustic Scanning Tool/Cement Bond Log/Correlation: BRU 244-23 Run Date: 08/07/2012 - 08/12/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU 244-23 Digital Data in LAS/DLIS format, Digital Log Image files 1 CD Rom 50-283-20165-00-00 Circumferential Acoustic Scanning Tool -No Pressure (Field Print) 1 Color Log 50-283-20165-00-00 Circumferential Acoustic Scanning Tool - Pressure (Field Print) 1 Color Log 50-283-20165-00-00 Advanced Cement Evaluation-No Pressure (ACE Processed Log) 1 Color Log 50-283-20165-00-00 Advanced Cement Evaluation- Pressure (ACE Processed Log) 1 Color Log 50-283-20165-00-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 nget,'CLI 22)eeei7 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com 212 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 10, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Reservoir Description Tool - RDT: BRU 244-23 Run Date: 7/30/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU 244-23 Digital Log Image file, RDT Report 1 CD Rom 50-283-20165-00-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 Idinton.wood@halliburton.com Date: �o ,2-'\Z Signed: Li £. / ' uAILA _ 1 R SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION COMIMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 David A. Ross Completion Engineer 0 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Beluga River Field, Undefined Gas Pool, BRU 244-23 Sundry Number: 312-328 Dear Mr. Ross: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a/ef Cathy I. Foerster Chair DATED this 24th day August,Au ust, 2012. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED APPLICATION FOR SUNDRY APPROVALS AUG2 3 20 AAC 25.280 2012 1.Type of Request Abandon❑ Plug for Redrdl 111Perforate New Pool❑ Repair WeA ka oil. Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate Q Pull Tubing & Gas Cons TO, n Operations Shutdown 111Re-enter Susp Well ❑ Stimulate 2Alter Casing 111 Other A%nchoragp f,JlUfu� 2 Operator Name 4.Current Well Class 5 Permit to Drill Number ConocoPhillips Alaska,Inc Development Q Exploratory ❑ 212-069 3.Address Stratigraphic ❑ Service III6 API Number: P O Box 100360 Anchorage,AK 99510-0360 50-283-20165-00-00 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8 Well Name and Number property line where ownership or landownership changes Spacing Exception Required? Yes ❑ No 0 BRU 244-23 9.Property Designation(Lease Number): 10 Field/Pool(s) Beluga River Undefined Gas Pool(G,H&I Benches) ADL-17658 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft) Effective Depth MD(ft) Effective Depth TVD(ft) Plugs(measured). Junk(measured). 7,553' 6,685 7,458' 6,591' Casing Length Size MD TVD Burst Collapse Structural Conductor 90' 20" 90' 90' Surface 3,427' 9 625" 3,427' 2,801' 8,920 7,110 Intermediate Production 7191.5' 7" 7,542' 6,674' 11,830 11,650 Liner Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size Tubing Grade Tubing MD(ft) 5,827'-5,833',6,050'-6,061', 4,960'-4,966',5,183'-5,194', 4-1/2", 12.6 lb/ft x L-80 4-1/2"- 5,680' 6,217'-6,233',6,262'-6,270', 5,350'-5,366',5,395'-5,403', 3-1/2",9.3 lb/ft 3-1/2"- 6,626' 6,307-6,309',6,347'-6,361', 5,440'-5,442',5,480'-5,494', 6,563'-6,571',6,686'-6,700', 5,696'-5,704',5,819'-5,833', 7,030'-7,042',7,096'-7,108' 6,163'-6,175',6,229'-6,241' Packers and SSSV Type' 1 Premier Production Packer&4 Premier Packers and SSSV MD(ft)and TVD(ft) Isolation Packers,WRSSSV 5,712',5,975',6,322',6,518',6,600'MD 4,845',5,108',5,455',5,651',5,733 TVD 12.Attachments. Description Summary of Proposal Q 13.Well Class after proposed work' Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑� Service Li 14.Estimated Date for 15.Well Status after proposed work 8/28/2012 Commencing Operations Oil Li Gas ❑✓ WDSPL ❑ Suspended ❑ 16 Verbal Approval Date WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative GSTOR ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name David A.Ross Title Completion Engineer Signature C �` Phone Date _ 907-263-4191 8/23/2012 COMMISSION USE ONLY Conditions of approval Notify Commission so that a representative may witness Sundry Number -,,,)__3es/ Plug Integrity ❑ BOP Test IZI -Mechanical Integrity Test ❑ Location Clearance ❑ 1 Other. Ne) Lure [f:rat r -ID La Ke-sx Cr got' "res.* leis--00?sL) Subsequent Form Required /O -Yo 7 (6 / //(/ 4 /401,19 �,i / , APPROVED BY �j (� Approved by / COMMISSIONERilf, OMMISSION y ♦ Date: B� - ` T- l 1 f o.� . •i-44" R� X11/2010 ' t r ^ DMS AUG 2 r `4 �/.1 S.L,..;t Dupl,cal. K IETASS 0.8-1;mlips ConocoPhillups BRU 244-23 Completion Overview 39' of I sand pay, 132' of H sand pay and 11' of G sand pay were selected to perforate after the LWD log and RDT analysis. 9 of the 11 the target sands were tubing conveyed perforated simultaneously prior to running the lower 3 '/2' completion consisting of a production packer and four isolation packers. Carbide blast rings were spaced out across the perforations between the isolation packers. Ball drop frac sleeves were positioned above the blast rings in each interval and screen wrapped production sleeves were placed below the blast rings. After spacing out the lower completion all five packers were hydraulically set simultaneously. The upper completion was run consisting of 4 %/2" tubing with a gas lift mandrel (GLM) chemical injection sub (CIS), and a wireline retrievable sub surface safety valve (WRSV). A 10 K frac tree has been installed to facilitate the post rig fracturing operations. The tubing was left full of kill weight completion brine and the IA left full of inhibited kill weight completion brine. Facilities have finished the underground piping construction and are ready to tie into the well at the end of the testing phase. Following the demobilization of the rig, slick-line operations will be performed to replace the DCK-2 shear valve in the KBG-2 GLM with an EK-DV and retrieve the RHC plug from the 4 '/2" XN nipple. Fracturing and support equipment will be mobilized to J pad and five frac stages will be performed. Through tubing E-line guns will be used to shoot the lower most I sand target below the tubing tail prior to executing the 1st frac stage. A sand plug will be set to isolate the first frac and an additional I sand target will be E-line perforated below the tubing tail prior to performing the 2nd frac stage. A composite BP will then be set in the tubing tail to isolate the zones below and the remaining 3 frac stages will be performed utilizing the frac sleeve system that was installed. A final cleanout and potential N2 lift will be performed after the fifth frac job at which time the frac tree will be replaced with the production tree and the well will be flowed back for a maximum of seven days through well test equipment before putting the well on production. All gas and fluid returning during the flowback period will be metered and vented according to the new EPA NSPS 0000 regulation pertaining to the flowback of fractured gas wells. BRU 244-23 Completion Operations Summary 1. P/U and run a WBCT assembly and displace the well to filtered kill weight brine. 2. R/U E-line and run a cement bond log. 3. Overbalance TCP five target sands simultaneously and pump a FLC pill if required. 4. P/U and run a perforation deburring assembly. 5. P/U and run the lower 3 'h" completion with one production packer and four isolation packers. 6. Space out and hydraulically set all five packers simultaneously. 7. P/U and run the upper 4 1/2" completion with CIS, GLM and WRSV. 8. Space out and land the tubing hanger. Run in lock down screws. �D ,0�1 9. Pressure test the tubing and annulus to 5,000 psi and shear the ball seat. I 211., 10. Install and test a 2-way check valve in the direction of flow. 11. Nipple down the BOP stack and install a 10K frac tree. �- 12. Pressure test the bonnet and tree seals to 7,500 psi 13. Release ria. RDMO 14. Move in and rig up; frac, coiled tubing , slick-line, E-line and support equipment. 15. Perforate the lower most I sand with E-line guns. 16. Frac zone 1 with - 100K lbs of 20-40 RC proppant and - 30K gallons of gaur/borate fluid. V St,,, 1 17. Perforate the upper most I sand with E-line guns. 18. Frac zone 2 with - 100K lbs of 20-40 RC proppant and - 30K gallons of gaur/borate fluid. 19. Set a composite BP in the tubing tail. 20. Frac zones 3-5 with - 100K lbs of 20-40 RC proppant and - 30K gallons of gaur/borate fluid utilizing the frac sleeve system installed. 21. Perform CT cleanouts following each frac if requiregd. t-: F V"s �..4rr BRU 244-23 L� 7 Page 1 of 2 Completion Summary 8/22/2012 aap � i y�R1�i rAss ConocoPhillips 22. Following the 5th frac perform a final CT cleanout and replace the frac tree with the production tree. 23. Demobilize the frac and support equipment and move in and rig up well testing equipment. 24. Flow test the well for a maximum of 7 days as per the EPA NSPS 0000 regulation. 25. Rig down the well testing equipment and put the well on production. BRU 244-23 Page 2 of 2 Completion Summary 8/22/2012 13KU 144-13 ' Grassroots Well Proposed Completion Schematic Conductor(Driven): ? '' j Upper Completion MD TVD 20", .75",API 5L GRB, Full i 1 Grvd, R3 Driven to Refusal 90' 1 1) BP6i SCSSSV w/'/4"SS control line 459' 459' Below Pad Grade 6-9-'2 1 2) BP6i Inj.Sub w/DCV&3/8"SS control line 5,529' 4,662' 5, I t 3) 4-'/2'Camco KBG-2 GLM w/DCK-2(2,500 psi) 5,591' 4,724' Cannon Coupling Protectors 11( coupling Tubing clamp protector, w/rchannelfor(left to ilctor,over I - 4)XN Profile, 3.725"ID 5,618' 4,751' right):0.375"bare line,0.250"bare ; 1 i i 1 5) 80-40 GBH-22 Seal Assembly 5,680' 4,813' line. Low carbon steel.25.25"long. � I t 9 1 I'i Lower Completion 5 OTOCabov etDhe top Se rDling D 111 6) Liner Setting Sleeve, RS Nipple,4"Seal Bore 5,667' 4,800' i j7) 3 1/2"x 7"Premier Production Packer 5,712' 4,845' Surface Casing: i1f 9 5/8",40#, L-80, BTC e I 8) X Profile,2.813 ID 5,734' 4,867' Set @ 3,426'MD/2,786'TVD 0 Il I 5 I i 9) 3 1/2"Halliburton Frac Door 5,778' 4,911' 1 II I 10) 3 1/2"Carbide Blast Rings 5,824' 4,957' 1 IC 11) 3 1/2"Selecta Flow Screen w/2.75"X profile 5,860' 4,993' r 12) 3 1/2"x 7"Premier Isolation Packer 5,975' 5,108' it 2 13) 3 1/2"Halliburton Frac Door 6,032' 5,165' Production Tubing: , 4 Y2",12.6#, L-80, IBT-M to i iGL 1 3 14) 3 1/2"Carbide Blast Rings 6,047' 5,180' 5,667'MD/4,800'TVD ., 3'/2', 9.3#L-80, IBT-M to 5 - 4 6,620'MD,5,753'TVD 15) 3 1/2"Carbide Blast Rings 6,215' 5,348' y 6 5 7 ' 16) 3 1/2"Carbide Blast Rings 6,260' 5,393' i 8- 9 __ G Sand Peforations(5 spf) �--- 10 �- 5,827'-5,833'MD ._ _ �� 17) 3 1/2"Selecta Flow Screen w/2.75"X profile 6,295' 5,428' i •11 12: s 18) 3 1/2"Carbide Blast Rings 6,305' 5,438' H Sand Peforations(5 spf) 14 = 13 @ 6,050'-6,061',6,217'-6,233' . lg 19) 3 1/2"x 7"Premier Isolation Packer 6,322' 5,455' 6,262'-6,270',6,307-6,309'MD i.. �$ am 1719 1 ! 20) 3 1/2"Halliburton Frac Door 6,335' 5,468' i ■20 H Sand Peforations(5 spf) 21 �\_ 21) 3 1/2"Carbide Blast Rings 6,344' 5,477' © 6,347'-6,361'MD ., - __ 22 23 22) 3 1/2"Selecta Flow Screen w/2.75"X profile 6,438' 5,571' ......:::::: 7- - 24 H Sand Peforations C5 spf) ( ( 25 m�� • 23) 3 1/2"x 7"Premier Isolation Packer 6,518 5,651' @ 6,563'-6,571' MD =• - ; 26 27 .•-.- - 24) 3 1/2"Halliburton Frac Door 6,540' 5,673' I Sand Peforations(6 spf) i 28 25) 3 1/2"Carbide Blast Rings 6,558' 5,691' @ 6,686',6,700'MD -•_ 4, _ _ - - I Sand Peforations(5 spf) /• •• � -� 26) 3 1/2"Selecta Flow Screen w/2.75"X profile 6,584' 5,718' @ 7,030'-7,042'MD - _ : _r _ E 27) 3 1/2"x 7"Premier Isolation Packer 6,600' 5,733' I Sand Peforations(6 sof) 7 e ►- @ 7,096'-7,108'MD =_. • _ Production Casing: 28) 1"SO Ball Seat w/Wireline Entry Guide 6,626' 5,759' 7",26.00#, L-80, BTC-Mod ' -, Set @ 7,542'MD/6,675'TVD • Page l of 1 Schwartz, Guy L (DOA) From: Ross, David (Swift Technical Services LLC) [David.Ross@contractor.conocophillips.com] Sent: Friday, August 24, 2012 10:24 AM To: Schwartz, Guy L (DOA) Subject: BRU 244-23 Production Cementing and Packer Setting Reports Attachments: BRU 244-23 Production Casing Cementing Detail.xps; BRU 244-23 Packer Setting Detail.xps Guy, As discussed, attached please find the 7" production cementing report and daily report which reflects the procedures that were used to set the lower completion packers. Let me know at your earliest convenience if you require any additional information. Regards, David A.less C.neasPhillips Alaska Inc. Drilling&Wells-Completion Engineer 700 G Street,ATO 1509 Anchorage,Alaska 99501 Phone:907-263-4191 Cell:907-903-9555 8/24/2012 Cement Detail Report /® v�.� BRU 244-23 (Z ConoaoPhillips String: Production Casing Cement Job: DRILLING ORIGINAL, 7/8/2012 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 8/4/2012 09:21 8/4/2012 12:00 BRU 244-23 Comment PJSM. Flush mud pumps with 9.8 brine. Drop bottom plug. Baker Hughes pumped 3 bbls water.Tested lines to 2500 psi.Pumped 41.6 bbls 10 ppg Seal Bond Spacer, 166 bbls 12 ppg cement,dropped top plug and pumped 5 bbls water.Rig displaced cement with 282.9 bbls 9.8 ppg brine at 4 bpm.Full returns throughout job. Did not bump plug.Shut in pressure-640 psi.Small amount spacer at surface. Cement Stages Stage#1 Description Objective Top(ftKB) Bottom(ftKB) Full Return? Cmnt Rtrn(... Top Plug? Btm Plug? Production Casing Primary 3,564.0 7,542.0 Yes Yes No Cement Q(start)(bbl/min) Q(end)(bbl/min) Q(avg)(bbl/min) P(final)(psi) P(bump)(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 3 4 1,000.0 No No Depth tagged(ftKB) Tag Method 'Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM.Flush mud pumps with 9.8 brine.Drop bottom plug.Baker Hughes pumped 3 bbls water.Tested lines to 2500 psi. Pumped 41.6 bbls 10 ppg Seal Bond Spacer. 166 bbls 12 opo cement,dropped top plug and pumped 5 bbls water. Rig displaced cement with 282.9 bbls 9.8 ppg brine at 4 bpm. Full rettir s throughout job.Did not bump plug.Shut in pressure-640 psi.Small amount spacer at surface. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Production Cement 3,564.0 7,542.0 345 G 166.0 Yield(fN/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(cp) Thickening Time(hrs) CmprStr 1(psi) 2.70 15.39 12.00 Additives Additive Type Concentration Cone Unit label 1 it C1//°*.iff:Ov Page 1/1 Report Printed: 8/24/2012 Security Level: AK Development Daily Drilling Report BRU 244-23 c«toaoPt,iiii� Report Number: 9 Rig: DOYON ARCTIC Report Date: 8/12/2012 AFE Type Network/ID# Total AFE+Sup ORIGINAL 10337120 2,038,002.00 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) BRU 244-23 Development BELUGA RIVER UNIT 30.08 9.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,325.86 114,109.07 153,955.25 1,292,411.15 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 8/4/2012 7/13/2012 7.20 8.50 -1.30 8/13/2012 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) 7"Production,7,541.9ftKB Ops and Depth @ Morning Report 24hr Forecast R/U to run upper completion Pick up 4.5 Upper completion Last 24hr Summary Continue running in hole with lower completion F/5056 T/6640', Pull up to 6625 and set pipe in tension, P/U 140 K,S/O 77K,PJSM,install TIW valve, rig up lubircator,rig up test equip,test pack off and lubircator @ 1500 psi(charted), run in hole with wire line and correlate depth,rig down wire line sheives, lubircator,PJSM,pick up 15 pup jt,locate depth @ 5656,break circulation @ 120 gpm,240 psi,drop 1"steel ball,(ball drop 24min)pressure up drill pipe to 2500 psi F 5 mins,stage up to 4000 psi F/5 mins,bleed off pressure,pull 20K over,psi test ann T/1000 psi F/5 mins,attempt to release F/setting tool, pull 20K over,slack off 20K(no go)PSI drill pipe T/3000 psi,bleed off,pull 20K over slack off 25K,(no release)slack off 25K,psi up DP to 4000 psi,setting released P/U 117K S/O 67K,PJSM,Rig up to lay down drill pipe,blow down top drive and kill line,monitor well F/30 min,lubircate rotary table and draw works,pull out of hole laying down drill pipe F/4920 T/3453,flow check well F/30 min,continue laying down drill pipe,T/baker PKR running tool and lay down running tool,pull wear busing,load tubing in pipe shed. General Remarks Weather Head Count No Accidents/No Incidents/No Spills 53*cloudy SSW @ 16 MPH 75.0 Supervisor Title John Huschle,Tour pusher Tour pusher Charlie Huntington,Tool Pusher Tool Pusher <Contact Name?>,<Title?> Scott Heim,Drilling Supervisor Drilling Supervisor Time Log Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 00:00 02:15 2.25 COMPZN WELLPR RCST P 5,056.0 6,625.0 Continue running in hole with lower completion F/5056 T/6640', Pull up to 6625 and set pipe in tension,P/U 140 K, S/O 77K,(3.5 bbls fluid loss) 02:15 05:30 3.25 COMPZN WELLPR RCST P 6,625.0 6,625.0 PJSM,install TIW valve, bring wire line equipment to rig floor, install pumping tee and lubircator, rig up test equip,test pack off and lubircator @ 1500 psi charted) 05:30 06:30 1.00 COMPZN WELLPR ELOG P 6,625.0 6,625.0 Run in hole with wire line and correlate depth. 06:30'07:15 0.75 COMPZN WELLPR RCST P 6,625.0 6,625.0 Rig down wire line shelves, lubircator and pumping tee, remove TIW valve. 07:15 10:00 2.75 COMPZN WELLPR PACK P 6,625.0 5,656.0 PJSM,pick up 15 pup jt, locate depth @ i 5656,break circulation @ 120 gpm,240 psi,drop 1"steel ball,(ball drop 24min) pressure up drill pipe to 2500 psi F 5 mins,stage up to 4000 psi F/5 mins, bleed off pressure, pull 20K over,psi test ann T/1000 psi F/5 mins,attempt to release F/setting tool,pull 20K over, slack off 20K(no go)PSI drill pipe T/ 3000 psi,bleed off,pull 20K over slack off 25K,(no release)slack off 25K,psi up DP to 4000 psi,setting released P/U 117K S/O 67K 10:00 11:00 1.00 COMPZN WELLPR PULD P 5,656.0 5,656.0 PJSM, Rig up to lay down drill pipe,blow down top drive and kill line,monitor well F/30 min Latest BOP Test Data Date Comment 8/5/2012 Jim Regg AOGCC waived witness via email Aug 3rd. Page 1/2 Report Printed: 8/24/2012 Security Level: AK Development OS Daily Drilling Report to 0 BRU 244-23 CAnocoPhiltips Report Number: 9 Rig: DOYON ARCTIC Report Date: 8/12/2012 Time Log Start End Dur ' Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 11:00 13:00 2.00 COMPZN WELLPR PULD P 5,656.0 4,920.0 Pull out of hole laying down drill pipe F/ 5697 T/4920, P/U 103 K,S/O 63 K 13:00 13:30 0.50 COMPZN WELLPR SVRG P 4,920.0 4,920.0 Lubircate rotary table and draw works 13:30 14:30 1.00 COMPZN WELLPR PULD P 4,920.0 3,453.0 Pull out of hole laying down drill pipe F/ 4920 T/3453 14:30 15:00 0.50 COMPZN WELLPR OWFF P 3,453.0 3,453.0 Flow check well F/30 min 15:00 21:00 6.00 COMPZN WELLPR PULD P 3,453.0 0.0 Continue laying down drill pipe,T/baker PKR running tool and lay down running tool 21:00 21:30 0.50 COMPZN WELLPR OTHR P 0.0 0.0 Pull wear busing 21:30 00:00 2.50'COMPZN WELLPR RCST P 0.0' 0.0 Load tubing in pipe shed, Wellbores Wellbore Name Wellbore API/UWI BRU 244-23 502832016500 Section Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date CONDI 20 0.0 90.0 6/8/2012 6/9/2012 SURFAC 12 1/4 0.0 3,426.0 7/13/2012 7/17/2012 PROD1 8 3/4 0.0 7,553.0 7/24/2012 7/27/2012 Survey Data MD(ftKB) Incl(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS(°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Tubing Strings 3.5"Lower Completion set at 6,626.8ftKB on 8/12/2012 11:00 Tubing Description String Nominal OD(in) String Wt(lbs/ft) String Grade Set Depth(ftKB) 3.5"Lower Completion 3 1/2 9.30 L-80 6,626.8 Page 2/2 Report Printed: 8/24/2012 4 fri p �J 4 h 6 a l; SEAN PARNELL,GOVERNOR Lal ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 C. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Beluga River Field, Undefined Gas Pool, BRU 244-23 ConocoPhillips Alaska, Inc. Permit No: 212-069 Surface Location: 482' FSL, 2619' FWL, SEC. 23, T13N, R10W, SM Bottomhole Location: 683' FSL, 326' FEL, SEC. 23, T13N, R10W, SM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development 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 Commission 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 Commission 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 a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner • DATED this / c-day of June, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 212012 PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work 1 b Proposed Well Class: Development-Oil ❑ Service-Win) ❑ Single Zone ❑ 1 c.Specify if well is proposed for: Drill ❑✓ Re-drill❑ Stratigraphic Test ❑ Development-Gas E Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond U Blanket ❑Single Well 11 Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 - BRU 244-23 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:7496' - TVD: 6624' • Beluga River Field , 4a. Location of Well(Governmental Section): 7 Property Designation(Lease Number). `(yam 'f' 1. .45c-zi. /z- Surface:482'FSL,2619'FWL,Sec.23,T13N,R1OW,SM ADL 21127 , e. './7456 �Betuga Gas Pool Top of Productive Horizon: 8.Land Use Permit 13.Approximate Spud Date S. 661'FSL,576'FEL,Sec.23,T13N, R1OW,SM n/a 7/1/2012 Total Depth: 9.Acres in Property: 14.Distance to 683'FSL,326'FEL,Sec.23,T13N, R1OW,SM 1394 �� / Nearest Property: none 4b.Location of Well(State Base Plane Coordinates-NAD 27) 10.KB Elevation above MSLC """��' eet 15.Distance to Nearest Well Open Surface:x- 320635.7 - y- 2630874.6 Zone- 4 GL Elevation above MSL:7/S 2, two Same Pool: none, 16.Deviated wells: Kickoff depth 500 ' ft. 17.Maximum Anticipated Pressure n prig(see 20 AAC 25 035) Maximum Hole Angle: 45.6° deg Downhole:3042 psig • Surface:2366 psig ' 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c f.or sacks Hole s Casing Weight Grade Coupling ! Length MD TVD MD ND )4. 4-7-f L (including stage data) n/a 20" 154.19# Welded 92' 18.5 18.5 92 92 driven 12.25" 9.625" 40# L-80 BTCM 3514 17.5 17.5 3514 2859 836 sx ClassX.1 8.75" 7" 26# L-80 BTCM 7232' 16.5 16.5 7496 6624 349 sx Class G 4.5" 12.6# L-80 IBTM 7100' 15.5 15.5 7085 6510 Production Tubing 19 PRESENT WELL CONDITION SUMMARY (To be completed for Rednll and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft) Effective Depth ND(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program O 20 AAC 25.050 requirements ❑✓ 21 Verbal Approval Commission Representative: Date. 22 I hereby certify that the foregoing is true and correct. Contact Hank Baca @ 263-4180 ( p? Printed Name / B C. Alvord Title Alaska Drilling Manager Signature a( Phon 265-6120 Date cY2 f 12-0( L /•f`�/l' ( \ Commission Use Only Permit to Dnll API Number: �7 Permit Approv I See cover letter ,21Number. 50.20.3.- /&'J � Date. L�` L\\(L for other requirements Conditions of approval: If box is ecked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Q' 4 "/O 0 0 r.S,..- OP l e--44 t Samples req'd: Yes ❑ No Ltd' Mud log req'd: Yes ❑ No R1/ Other: et-ZS-0 esu �''i`�`r't ( -s itl 2S measures: Yes ❑ No [` ' Directional svy req'd: Yes E " No ❑ / s A '✓e_ A VED BY THE COMMISSION DATE A�/ ' ,COMMISSIONE Form 1'-401 (Revi ed 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(9)) bmit� in Duplicate I� Iz �� .6.'/ ConocoPhillips Alaska,Inc. Post Office Box 1 ConocoPhillips Anchorage,Alaskaa 995 99510-0360 Telephone 907-276-1215 May 16th,2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill BRU 244-23 Gas Producer Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a Permit to Drill an onshore gas producer well in the Beluga River Unit. The surface location will be on the pre-existing J pad containing wells 211-26,224-23,232-26,and 224-23T. The expected spud date is July 1st,2012 conducting operations with Doyon Arctic Fox. BRU 244-23 proposed well design:drill 12-1/4"surface hole to approximately 3,514'MD/2,859'TVD on diverter vent system. Then 9-5/8"surface casing will be run and cemented to surface.8-3/4"production hole will be drilled to 7,496' MD/6,624'TVD on a 5,000 psi BOPE system. Mud logs will be taken from the surface casing shoe to TD. The production hole section will penetrate the Sterling sands through the Beluga I. 7"production casing will be run to TD and cemented to—3,564'MD(500'MD above top of Sterling A). Following drilling operations,the 7"casing will be perforated in the zone of interest. To commence the proposed drilling program,CPAI is seeking approval for variance 20 AAC 25.035(h)(2). This variance is to regulation 20 AAC 25.035(c)(1)(A)specifying vent diameter size. The Doyon Arctic Fox is equipped with ) a 12"vent line compared to the requested 16". Please find attached the information required by 20 ACC 25.005(a)and(c)for your review.Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005(a). 2. Pressure information as required by 20 ACC 25.035(d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drillmg/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If requiring further information,please contact Hank Baca at 263-4180 or Chip Alvord at 265-6120. Sincerely, /14.„,./L `-`- Hank Baca Drilling Engineer i ". Application for Permit to Drill Document Beluga River Unit 244-23 Well Name Requirements of 20 AAC 25.005(D The well for which this application is submitted will be designated as 244-23. Location Summary Requirements of 20 AAC 25.005(c)(21 An application for a Permit to Drill must he accompanied by each of the follow mg hens,except for an nem already on file with the camnusiron and identified in the application (2)a plat identifying the property and the property's owners and Allotting (A)the coordinates of the proposed location of the ire/!at the surface,al the top of each objective formation,and al total depth,referenced to governmental section lines (B)the coordinates of the proposed location of the e ell at the surface,referenced to the state plane coordinate system fir this slate as maintained h) the National Geodetic Survey in the National Oceanic and Atmospheric Admuustralton, (C)the proposed depth of the well at the lap of each objective formation and at total depth Location at Surface 482'FSL, 2619'FWL, Sec 23, T13N,RIOW NAD 27 RKB Elevation 94.0'AMSL Northings: 2,630,874.59" Eastings:320,635.69' ' Pad Elevation 75.5'AMSL Location at Top of Productive Interval 661'FSL, 576'FEL, Sec 23, T13N,R1OW (Sterling A Sand) NAD 27 Measured Depth,RKB: 4,064' Northings: 2,631,021.42' Eastings:322,722.95' Total Vertical Depth,RKB: 3,249' Total Vertical Depth,SS: 3,155' Location at Total Depth 683'FSL, 326'FEL, Sec 23, T13N,RIOW NAD 27 Measured Depth,RKB: 7,496' Northings: 2,631,039.60' Eastings:322,972.70' Total Vertical Depth,RKB: 6,624' • Total Vertical Depth,SS: 6,530' and (D)other information required hi 20 A,4('25 050(h) Requirements of 20 AAC 25.050(b) ((fa well is to he intentionally deviated,the application for a Permit to Drill(Form 10-401)must (I)include a plat,drawn to a suitable scale,showing the lath of the proposed we//hore,including all adjacent wellborn within 200 feet of aqs portion of the proposed well. Please see attachment Directional Plan No close approach issues exist Separation factors are above 10 0 from surface to TD The'/"mile pool scan of the top of Sterling A sands contains no wells And (2)for all ire/!s within 200 feet of the proposed is ellhore (A)list the names of the operators of those 0e/A,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a ropy of the application by certified mail,or (B).slate that the applicant is the only affected owner The Applicant is the only affected owner Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill mud he accompanied It;each of the following items,except for an item already on file a oh the commreshon and identified in the application (3)a diagram and description of the blowout prevention equipment(BOPE)as requited It;20 A 4('25 035,20 AA('25 036,or 20 AA('25 037,as applicable, Please reference BOP schematics on file for Doyon Arctic Fox. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application• (4)information on drilling ha=ards, including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The production hole is expected to penetrate near virgin reservoir pressures of 3,042 psi in the Beluga I-sands. This maximum down hole pressure was documented during the MDT's taken on the offset well 243-34 in 2008. The maximum potential surface pressure(MPSP)while drilling 244-23 is calculated using above maximum reservoir pressure, a gas gradient of 0.10 psi/ft,and the estimated depth of the Beluga I-sand top at 5,804' TVD(WP04): I-sand reservoir pressure =2,946 psi I-sand estimated top depth(WP04) =5,804' TVD Gas Gradient =0.10 psi/ft as per 20 AAC 25.005(c)(4)(A) Hydrostatic of full gas column ==5 (5,804' TVD * 0.10 psi/ft) MPSP=SIBHP—gas column 2,366 psi - (2,946 psi—580.4 psi) (B)data on potential gas:ones, MAs P The well bore will penetrate the Sterling A-C and the Beluga D-I gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation=ones,and zones that have a propensity for differential sticking, See attached BRU 244-23 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application• (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300, A procedure is on file with the commission for performing formation integrity tests. For BRU 244-23,the FIT will occur after drilling out the 9-5/8"surface shoe track plus 20' of new formation. The formation will then be pressured to 16.0 ppg EMW or until leak off occurs,which ever comes first.A required minimum leak off of 11.0 ppg EMW must be obtained. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(61 An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted hoer,pre perforated liner, or screen to be installed Casing Program Casing Weight Top Bottom OD Hole Size (1b/ft) Grade Connection Length MD/TVD MD/TVD 20" Conductor 154.19 Weld 92' 18.5'/ 18.5' 92'/92' 9-5/8" 12-1/4" 40 L-80 BTCM 3,514' 17.5'/17.5' 3,514'/2,859' 7" 8-3/4" 26 L-80 BTCM 7,232' 16.5'/ 16.5' 7,496'/6,624' 4-1/2" Tubing 12.6 L-80 IBTM 7,100' 15.5'/15.5' 7,085'/6,510' L 9-5/8" Surface Casing Single Stage Cement Program The 9-5/8"X 12-1/4"annulus will be cemented from TD to surface using light weight 12.0 ppg Type I cement. Cement System: Preflush: 40.0 bbls Viscosified Water Nut Plug Sweep Spacer: 24.0 bbls Mud Clean II with red dye Lead Slurry: 836 sacks 12.0 ppg Type I Cement+additives Yield=2.30 ft3/sx Mix Water=9.45 gal/sx Displacement: 260 bbls Spud Mud �^ Length Capacity Total Total Total Mix Water Slurry Volumes (ft) (ft3) Excess (ft3) (sacks) (bbls) (bbls) Conductor ID x Surface OD 88 63.5 0% 63.5 27.6 11.6 6.2 15.0"x 9.625" Open Hole x Surface OD 3,426 1073.0 70% 1824.1 793.1 141.2 178.4 12.25"x 9.625" Shoe Track ID 80 34.1 0% 34.1 14.8 2.6 3.3 8.835" Rat Hole 2 .8 70% 1.4 0.6 0.1 0.135 12.25" Total 1923.1 836. 155.5 188.0 Top of Surface casing set at 18.5'MD,surface casing shoe set at 3,514' MD. 54-5 7" Production Casing Single Stage Cement Program The 7"X 8-3/4"annulus will be cemented from TD to 3564' MD(500' above top of Sterling A sand)usiliaht weight 12.0 ppg Class"G"cement. If significant lost circulation occurs during drilling,a hydraulic stage cementing tool may be considered for cementing across the Sterling sands. Cement System: Spacer 40.0 bbls 10 ppg BJ Seal Bond+ 19.8 lbs/bbl Potassium Chloride+67.8 lbs/bbl Barite Lead Slurrycks 12.0 ppg Class G Cement+additives Yield=2.64 ft3/sx Mix Water= 15.07 gal/s Displacement 284 bbls KlaShield Drilling Mud Length Capacity Total ' Total Total Mix Water Slurry Volumes (ft) (ft3) Excess (ft3) (sacks) (bbls) (bbls) Open Hole x Production OD 3982 598.5 50% 898.7 340.0 160.0 122.0 8.75"x 7" Shoe Track 80 17.2 0% 17.2 6.5 3.1 2.3 6.276" Rat Hole 10 4.2 50% 6.3 2.4 1.1 .86 8.75" Total 922.2 (34-8-.9) 164.2 125.2 Top of cement at-3,564' MD,surface shoe set at 3,514' MD,production glroe set at 7,496' MD Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); The 12-1/4"surface hole will be drilled with a diverter system consisting of a remotely operated annular pack-off,full-opening vent line valve,and a 12"diameter vent line. CPAI is seeking approval for regulation 20 AAC 25.035(h)(2). This variance is to regulation 20 AAC 25.035(c)(1)(A)for a 12"diameter. ofr: ORIGINAL Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file ticitli the commission and identified in the application (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Surface Interval Fluid Properties Mud Funnel API Fluid Drill Depth MD Wt. Viscosity Yield Point Loss pH Solids MBT (ft) (ppg) (cp) (lb/100ft ) (cc/30min) (%) 100'-3,514' 8.8-9.6 200-300 40-60 NC—<10 +/-9.0 <7% <35 Surface Interval Summary The 12-1/4"surface hole will be drilled with a fresh water spud mud to an expected total depth of 3,851' MD/2,765' TVD. The spud mud will consist of viscosifiers,pH control,weighting material,and anti accretion/bit balling agents.This fluid will maintain good rheology to remove formation cuttings,prevent loss circulation,promote hole cleaning and ensure good cement to surface. Production Interval Fluid Properties Depth MD Mud Wt. 6 Yield Point API Fluid Solids Loss (ft) (ppg) RPM (lb/100ft2) (cc/30min) pH (%) 3,514'-7,496' 9.6-9.8+ 7-9 18-20 <6cc 9.0-9.5 <5 Production Interval Summary The 8-3/4"production interval will be drilled from 3,514'to a planned TD of 7,496' MD/6,624' TVD. The drilling fluid will be a water based shale inhibitive system consisting of 6%KC1 and other proprietary shale inhibitors.Additional well bore strengthening materials designed to prevent lost circulation in the depleted Sterling sands will be included.Also products for stabilization of coal seams and minimizing fluid invasion to prevent reservoir damage will be added. Whole mud dilutions and rheology maintenance will used to prevent differential sticking. Additional focus will be on good hole cleaning practices. These practices include monitoring tripping speeds and PWD data,controlling ROP,pumping regular sweeps,adjusting rheology,and charting drag weights. Fluid weight will have sufficient density to overbalance the pressure of uncased formations penetrated. Sufficient weighting material stocks will be maintained on site such that the entire mud circulating volume can be raised by a minimum of 1.0 ppg. Diagram of Doyon Arctic Fox Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A-Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A-Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(I1) N/A-Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alma,Inc. is on file with the Commission. t RGNALI Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following Items,except for an lienm already on file mrth the commission and identified in the application: General Procedure: 1. MIRU Doyon Arctic Fox over pre-installed 20"conductor casing with welded landing ring on conductor. '/ 2. Install diverter&function test same. Notify regulatory agencies 48 hours prior to test. • 3. Spud well and drill 12 1/4"hole to the surface casing point at 3514' MD/2859' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing,trip out. 5. Run and cement 9 5/8"40#L80 BTC casing string to surface. - �4�55 r ■ Employ lightweight cement lead slurry to assure cement returns to the surface in a one-stage job. Adequate excess cement will be pumped to ensure cement reachlithe surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP'si/3500psi annular). Notify all regulatory agencies 48 hours prior to test. 7. Make up 8 3/4"bit and BHA and RIH to top of float equipment. • Pressure test casing to 3000 psi for 30 minutes/c. vr ■ Record results and fax to town 8. Drill float equipment and approximately 20' of new hole • Perform LOT(or FIT if gradient reaches 16 ppg equivalent). Minimum 11.0 ppg FIT • Record results and fax to town 9. Drill 8-3/4"hole to+/-7,496' MD/6,624' TVD. Run MWD/LWD logging tools in drill string as required for directional measurements and formation data gathering. POOH with drilling assembly. 10. RU wire line and RIH with MDT tools for collecting fluid samples and formation pressures. 11. PU cleanout assembly and RIH,cleanout to TD,circulate at least four bottoms up. 12. Change 2-7/8"x 5"VBRs to 7"and test break to 5000psi. 13. Run and cement 7"casing per program to TD. Cement casing and bring cement-3564' MD(500' above Sterling A sand). • If there are signs of lost circulation prior to rynning casing, install a Halliburton HES stage cementing tool at+/- 4000' MD. 14. Change 7"rams to 2-7/8"x 5"VBRs and test beak to 5000psi. 15. Run in with a cleanout assembly inside the 7"casing. 16. Displace well to clean brine. 17.stcasing t9sgriasi for 30 min___ 18. Run cement bond log/GR/CCL. 19. RU tubing conveyed perforating equipment and RIH with guns 20. Place guns on depth and fire same 21. POOH with guns and LD same 22. Pick up and run in hole with the lower tubing frac./production string. 23. Run Upper completion per completion schematic.(Latch into anchor,shear PBR,space out,etc.) 24. Land tubing and test tubing hanger. 25. Test inner annulus to 2500 psi for 30 minutes.(Note:This will test tubing integrity.) 26. Pressure up on IA to shear SOV at 3000 psi. 27. Set BPV and ND BOP. 28. Nipple up tree and test same. fC f I a` 1 �. 29. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill nmstc be accompanied by each of the following items,except for an item already on file with the commission and identified m the application• (1 4)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorration under 20 AAC_25.080 for an annular disposal operation in the well; Class II waste fluids will be sent to the class II disposal well at BRWD. Fluids will then be centrifuged to separate out solids greater than 10 microns. All Class II fluids will be transported in the Drilling vacuum truck to prevent mixing of Class I fluids. Class I fluids will be sent to the class I disposal well BRU 232-09 using only the Production vacuum truck. Drill cuttings and solids will be deposited at the Beluga Solid Waste Disposal Cell#5. Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ConocoPhillips (Alaska) Inc. -Expl Beluga River Beluga River Plan: BRU 244-23 Plan: BRU 244-23 Plan: BRU 244-23 (wp04) Standard Proposal Report 08 May, 2012 p4 tat '4. . HALLIBURTON Sperry Drilling Services ORIGINAL HALLIBURTON Project: Beluga River WELL DETAILS: Plan BRU244-23 NAD 1927(NADCON CONUS) Alaska Zone 04 Sperry Drilling ServicesSite: Beluga River Ground Level: 75.50 Well: Plan: BRU 244-23 +N/-S +E1-W Northing Easting Latittude Longitude Slot Wellbore: Plan: BRU 244-23 0.00 0.00 2630874.59 320635.69 61°11'49.366 N 151°1'0.469 W Plan: BRU 244-23(wp04) REFERENCE INFORMATION 0- Co-ordinate(WE)Reference:Well Plan:BRU 244-23,True North SHL:482'FSL,2619'FWL-Sec23-T13N-R1OW Vertical(TVD)Reference:Plan 75.5+18.5 94.008(Arctic Fox) Measured Depth Reference. Plan 75.5+18.5©94.008(Arctic Fox) Calculation Method:Minimum Curvature 400- FORMATION TOP DETAILS 0° CASING DETAILS TVDPath TVDssPath MDPath Formation MD TVD TVDSS Name Size Hole Size 2979.00 2885.00 3685.89 BRWD-1 Injection Zone 5" 3514.30 2859.00 2' .,l 7 x 12-1/4" 9-5/8 12-1/4 3249.00 3155.00 4063.54 Sterling A 800- 7495.65 6624.00 6530.00"x 8-1/2" 7 8-1/2 3429.00 3335.00 4279.02 Sterling B 3582.00 3488.00 4446.20 Sterling C 1000 3744.00 3650.00 4614.28 Beluga D 4014.00 3920.00 4885.65 Beluga E 4366.00 4272.00 5237.65 Beluga F 1200- Z5 4824.00 4730.00 5695.65 Beluga G 05 5154.00 5060.00 6025.65 Beluga H 5859.00 5765.00 6730.65 Beluga I 1), 6325.00 7290.65 Beluga J(Beluga I base) 1600- - 00 `1O 2000- hrO 2400- 00 ,5O 2800- 9-5/8"x 12-1/4" Surface Csg @ 3514'MD,2859'TVD:627'FSL,961'FEL-Sec23-T13N-R1OW • BRWD-1 Injection Zone- - 00 03200 Top Sterling_A @ 4064'MD,3249'TVD:661'FSL,576'FEL-Sec23-T13N-R1OW go Sterling A- - - - - L _ no0 a - Sterling B - - -- N Zp° 03600- -Sterling E - - -Beluga 9- - - - Ttr Top Beluga_D @ 4614'MD,3744'TVD:681'FSL,348'FEL-Sec23-T13N-R1 3W - 0) (D4000 -Beluga - - _ - 0° _ BRU 244-23 30Apr12 Beluga E 5000 - -Beluga F- 4400 - 4800'.- -Beluga C 5200- - - 6000 5600- - 6000- - 7000 000- 7000 6400-- g_;,, ,. (0.''/,a i t.as-4 Top Beluga J @ 7291'MD,6419'TVD:683'FSL,326'FEL-Sec23-T13N-R10W 7"x 8-1/2=__-_, '7496 TD @ 7496'MD,6624'TVD:683'FSL,326'FEL-Sec23-T13N-R1 OW 6800- BRU 244-23 30Apr12 Beluga TO r BRU 244-23(wp04) - 1 1 1 I I 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I I I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I I I 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 f -400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 Vertical Section at 86.35° (800 ft/in) ConocoPhil G lips I1 r ` Alaska t _€ vis = a Qti z m a F - E Sa C IJ s o - O r N r Zuni f O I .S Nv�i- _C V V2as J _ Cr N J I 0. !/O. - N .per. •>8 8 ", _ 6624 { �, w O m�mj /' ` �� 2 �7 zN°O - N c `m'n'n E _ b C m C b „+ / Yi a P N z 3aa /' v vi88 < W F _8 §.'S. U c c cc / �]1 ^c 0 O Cep W mdd T /' X250 4L U r n. - .J.7. V: F^N. " w °O>t.sL. 1 i 88 —8 P C.°CC k. :O W F h N N • a 0 m °°8 1 ' 3000 F ='' - 3 8 Q _o + o 9 _ v oo # ^0. 0 z - _o F @) 2750 P c - .o I C N P F _r 0 1 ^ c a F° h /' - o o co co N N Qp• - - V V - - 2500 - o O N NNNM �°., —� .Mi E.E cK cy v -- ^ m m m m N _o R mmCL CL m C' - o di __0 i3 N= N c c.' 2250 - ^ o _ IL Tu - o - o C _ C 2000 - o —o - o —o - c —c 1750 - V - o —0 - o —o _ e 1500 - 0 3 —o o R. 2I-° N^ z L 25650 LE N F Z - U.-u-o-1 _ N 1250 26 o d�g - O Ens)-7--m 2 _ C Z La� - o 1000 5.6 C�°0 - E En 2 M 44 500 ..f _ 2 .1 O if: _o o c . _O m III , III II II II , I I I I I I II I I I IiII II I I , II II I I II , I I I I I I I I I I I II I I I I I I I I I I I I I II I ,IIIII I,1 I I I II I I I I I I I I I I I , I I I , I , J ° o S o 8 0 8 S 8 8 8 8 o q 8 8 8 18 8 8 8 8 J N ^ O C w I` .0 h C M N v h t IL R (u!/1100£)(±AtioN/Htlinos Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:BRU 244-23 Company: ConocoPhillips(Alaska)Inc.-Expl TVD Reference: Plan 75.5+18.5 @ 94.00ft(Arctic Fox) Project: Beluga River MD Reference: Plan 75.5+18.5 @ 94.00ft(Arctic Fox) Site: Beluga River North Reference: True Well: Plan:BRU 244-23 Survey Calculation Method: Minimum Curvature Wellbore: Plan:BRU 244-23 Design: BRU 244-23(wp04) Project Beluga River,Alaska,USA Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Beluga River Site Position: Northing: 2,630,909.88 ft Latitude: 61°11'51.001 N From: Map Easting: 329,245.55ft Longitude: 150°58'4.800 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.85° Well Plan:BRU 244-23 Well Position +N/-S 0.00 ft Northing: 2,630,874.59 ft Latitude: 61°11'49.366 N +E/-W 0.00 ft Easting: 320,635.69 ft Longitude: 151°1'0.469 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 75.50 ft Wellbore Plan:BRU 244-23 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 7/22/2012 15.14 73.02 55,051 Design BRU 244-23(wp04) Audit Notes: Version: Phase: PLAN Tie On Depth: 18.50 Vertical Section: Depth From(TVD) +N/-5 +E/-W Direction (ft) (ft) (ft) (°) 18.50 0.00 0.00 86.35 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (ft) (°) (1 (ft) ft (ft) (ft) (1100ft) (°/100ft) (°1100ft) (°) 18.50 0.00 0,00 18.50 -75.50 0.00 0.00 0.00 0.00 0.00 0.00 483.36 0.00 0.00 483.36 389.36 0.00 0.00 0.00 0.00 0.00 0.00 885.42 10.05 86.35 883.36 789.36 2.24 35.11 2.50 2.50 0.00 86.35 1,185.42 22.05 86.35 1,171.14 1,077.14 7.51 117.74 4.00 4.00 0.00 0.00 1,657.13 45.63 84.95 1,560.19 1,466.19 28.30 377.72 5.00 5.00 -0.30 -2.51 3,923.14 45.63 84.95 3,144.92 3,050.92 171.00 1,991.13 0.00 0.00 0.00 0.00 4,835.65 0.00 0.00 3,964.00 3,870.00 201.35 2,334.31 5.00 -5.00 0.00 180.00 4,885.65 0.00 0.00 4,014.00 3,920.00 201.35 2,334.31 0.00 0.00 0.00 0.00 7,495.65 0.00 0.00 6,624.00 6,530.00 201.35 2,334.31 0.00 0.00 0.00 0.00 1/ 5/8/2012 9:34:26AM Page 2 ... COMPASS 2003.16 Build 69 h -t) �. L b k Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:BRU 244-23 Company: ConocoPhillips(Alaska)Inc.-Expl TVD Reference: Plan 75.5+18.5 @ 94.00ft(Arctic Fox) , Project: Beluga River MD Reference: Plan 75.5+18.5 @ 94.00ft(Arctic Fox) Site: Beluga River North Reference: True Well: Plan:BRU 244-23 Survey Calculation Method: Minimum Curvature - Wellbore: Plan:BRU 244-23 Design: BRU 244-23(wp04) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Fasting DLS Vert Section (ft) (°) (1 (ft) ft (ft) (ft) (ft) (ft) -75.50 18.50 0.00 0.00 18.50 -75.50 0.00 0.00 2,630,874.59 320,635.69, 0.00 0.00 SHL:482'FSL,2619'FWL-Sec23-T13N-R10W 100.00 0.00 0.00 100.00 6.00 0.00 0.00 2,630,874.59 320,635.69 0.00 0.00 200.00 0.00 0.00 200.00 106.00 0.00 0.00 2,630,874.59 320,635.69 0.00 0.00 300.00 0.00 0.00 300.00 206.00 0.00 0.00 2,630,874.59 320,635.69 0.00 0.00 400.00 0.00 0.00 400.00 306.00 0.00 0.00 2,630,874.59 320,635.69 0.00 0.00 483.36 0.00 0.00 483.36 389.36 0.00 0.00 2,630,874.59 320,635.69 0.00 0.00 500.00 0.42 86.35 500.00 406.00 0.00 0.06 2,630,874.59 320,635.75 2.50 0.06 600.00 2.92 86.35 599.95 505.95 0.19 2.96 2,630,874.73 320,638.65 2.50 2.97 700.00 5.42 86.35 699.68 605.68 0.65 10.21 2,630,875.08 320,645.91 2.50 10.23 800.00 7.92 86.35 798.99 704.99 1.39 21.79 2,630,875.64 320,657.50 2.50 21.84 885.42 10.05 86.35 883.36 789.36 2.24 35.11 2,630,876.28 320,670.82 2.50 35.18 900.00 10.63 86.35 897.70 803.70 2.41 37.72 2,630,876.40 320,673.44 4.00 37.79 1,000.00 14.63 86.35 995.26 901.26 3.80 59.54 2,630,877.46 320,695.28 4.00 59.66 1,100.00 18.63 86.35 1,091.06 997.06 5.62 88.10 2,630,878.83 320,723.86 4.00 88.28 1,185.42 22.05 86.35 1,171.14 1,077.14 7.51 117.74 2,630,880.26 320,753.52 4.00 117.98 1,200.00 22.78 86.27 1,184.61 1,090.61 7.87 123.28 2,630,880.54 320,759.07 5.00 123.53 1,300.00 27.78 85.81 1,275.01 1,181.01 10.83 165.87 2,630,882.84 320,801.69 5.00 166.22 1,400.00 32.77 85.49 1,361.34 1,267.34 14.67 216.12 2,630,885.89 320,852.00 5.00 216.61 1,500.00 37.77 85.24 1,442.96 1,348.96 19.34 273.66 2,630,889.67 320,909.60 5.00 274.33 1,600.00 42.77 85.04 1,519.24 1,425.24 24.82 338.04 2,630,894.14 320,974.06 5.00 338.94 1,657.13 45.63 84.95 1,560.19 1,466.19 28.30 377.72 2,630,897.00 321,013.77 5.00 378.75 1,700.00 45.63 84.95 1,590.17 1,496.17 30.99 408.24 2,630,899.23 321,044.33 0.00 409.38 1,800.00 45.63 84.95 1,660.11 1,566.11 37.29 479.44 2,630,904.42 321,115.62 0.00 480.84 1,900.00 45.63 84.95 1,730.04 1,636.04 43.59 550.64 2,630,909.60 321,186.90 0.00 552.30 2,000.00 45.63 84.95 1,799.98 1,705.98 49.89 621.84 2,630,914.79 321,258.19 0.00 623.75 2,100.00 45.63 84.95 1,869.91 1,775.91 56.19 693.04 2,630,919.98 321,329.47 0.00 695.21 2,200.00 45.63 84.95 1,939.84 1,845.84 62.48 764.24 2,630,925.17 321,400.76 0.00 766.67 2,300.00 45.63 84.95 2,009.78 1,915.78 68.78 835.44 2,630,930.36 321,472.04 0.00 838.12 2,400.00 45.63 84.95 2,079.71 1,985.71 75.08 906.64 2,630,935.55 321,543.33 0.00 909.58 2,500.00 45.63 84.95 2,149.65 2,055.65 81.38 977.84 2,630,940.74 321,614.61 0.00 981.04 2,599.99 45.63 84.95 2,219.58 2,125.58 87.67 1,049.04 2,630,945.93 321,685.90 0.00 1,052.49 2,699.99 45.63 84.95 2,289.52 2,195.52 93.97 1,120.24 2,630,951.12 321,757.18 0.00 1,123.95 2,799.99 45.63 84.95 2,359.45 2,265.45 100.27 1,191.44 2,630,956.31 321,828.47 0.00 1,195.41 2,899.99 45.63 84.95 2,429.39 2,335.39 106.57 1,262.64 2,630,961.50 321,899.75 0.00 1,266.86 2,999.99 45.63 84.95 2,499.32 2,405.32 112.86 1,333.84 2,630,966.69 321,971.04 0.00 1,338.32 3,099.99 45.63 84.95 2,569.25 2,475.25 119.16 1,405.04 2,630,971.88 322,042.32 0.00 1,409.78 3,199.99 45.63 84.95 2,639.19 2,545.19 125.46 1,476.24 2,630,977.07 322,113.61 0.00 1,481.23 3,299.99 45.63 84.95 2,709.12 2,615.12 131.76 1,547.44 2,630,982.25 322,184.89 0.00 1,552.69 3,399.99 45.63 84.95 2,779.06 2,685.06 138.05 1,618.64 2,630,987.44 322,256.18 0.00 1,624.15 3,499.99 45.63 84.95 2,848.99 2,754.99 144.35 1,689.84 2,630,992.63 322,327.46 0.00 1,695.60 3,514.30 45.63 84.95 2,859.00 2,765.00 145.25 1,700.03 2,630,993.38 322,337.66 0.00 1,705.83 Surface Csg @ 3514'MD,2859'TVD:627'FSL,961'FEL-Sec23-T13N-R10W-9-5/8"x 12-114" 3,599.99 45.63 84.95 2,918.93 2,824.93 150.65 1,761.04 2,630,997.82 322,398.75 0.00 1,767.06 5/8/2012 9:34:26AM Page 3 COMPASS 2003.16 Build 69 Halliburton -Sperry HALL I B U R TO N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:BRU 244-23 Company: ConocoPhillips(Alaska)Inc.-Expl TVD Reference: Plan 75.5+18.5 @ 94.00ft(Arctic Fox) Project: Beluga River MD Reference: Plan 75.5+18.5 @ 94.00ft(Arctic Fox) Site: Beluga River North Reference: True Well: Plan:BRU 244-23 Survey Calculation Method: Minimum Curvature Wellbore: Plan:BRU 244-23 Design: BRU 244-23(wp04) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (0) (°) (ft) ft (ft) (ft) (ft) (ft) 2,885.00 3,685.89 45.63 84.95 2,979.00 2,885.00 156.06 1,822.20 2,631,002.28 322,459.98 0.00 1,828.44 BRWD-1 Injection Zone 3,699.99 45.63 84.95 2,988.86 2,894.86 156.95 1,832.24 2,631,003.01 322,470.03 0.00 1,838.52 3,799.99 45.63 84.95 3,058.80 2,964.80 163.24 1,903.44 2,631,008.20 322,541.32 0.00 1,909.97 3,899.99 45.63 84.95 3,128.73 3,034.73 169.54 1,974.64 2,631,013.39 322,612.60 0.00 1,981.43 3,923.14 45.63 84.95 3,144.92 3,050.92 171.00 1,991.13 2,631,014.59 322,629.11 0.00 1,997.97 3,999.99 41.78 84.95 3,200.47 3,106.47 175.68 2,044.01 2,631,018.45 322,682.05 5.00 2,051.04 4,063.54 38.61 84.95 3,249.00 3,155.00 179.29 2,084.86 2,631,021.42 322,722.95 5.00 2,092.04 Top Sterling_A @ 4064'MD,3249'TVD:661'FSL,576'FEL-Sec23-T13N-R10W-Sterling A 4,099.99 36.78 84.95 3,277.84 3,183.84 181.25 2,107.06 2,631,023.04 322,745.17 5.00 2,114.32 4,199.99 31.78 84.95 3,360.44 3,266.44 186.22 2,163.15 2,631,027.13 322,801.33 5.00 2,170.61 4,279.02 27.83 84.95 3,429.00 3,335.00 189.68 2,202.27 2,631,029.98 322,840.50 5.00 2,209.87 Sterling B 4,299.99 26.78 84.95 3,447.64 3,353.64 190.52 2,211.85 2,631,030.68 322,850.10 5.00 2,219.49 4,399.99 21.78 84.95 3,538.76 3,444.76 194.15 2,252.81 2,631,033.66 322,891.10 5.00 2,260.59 4,446.20 19.47 84.95 3,582.00 3,488.00 195.58 2,269.02 2,631,034.85 322,907.33 5.00 2,276.86 Sterling C 4,499.99 16.78 84.95 3,633.12 3,539.12 197.05 2,285.69 2,631,036.06 322,924.02 5.00 2,293.60 4,599.99 11.78 84.95 3,730.00 3,636.00 199.23 2,310.26 2,631,037.85 322,948.62 5.00 2,318.25 4,614.28 11.07 84.95 3,744.00 3,650.00 199.48 2,313.08 2,631,038.06 322,951.44 5.00 2,321.08 Top Beluga_D @ 4614'MD,3744'TVD:681'FSL,348'FEL-Sec23-T13N-R10W-Beluga D 4,699.99 6.78 84.95 3,828.66 3,734.66 200.65 2,326.32 2,631,039.02 322,964.70 5.00 2,334.37 4,799.99 1.78 84.95 3,928.35 3,834.35 201.31 2,333.76 2,631,039.56 322,972.14 5.00 2,341.84 4,835.65 0.00 0.00 3,964.00 3,870.00 201.35 2,334.31 2,631,039.60 322,972.70 5.00 2,342.39 4,885.65 0.00 0.00 4,014.00 3,920.00 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 Beluga E-BRU 244-23 30Apr12 Beluga E 4,899.99 0.00 0.00 4,028.34 3,934.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 4,999.99 0.00 0.00 4,128.34 4,034.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 5,099.99 0.00 0.00 4,228.34 4,134.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 5,199.99 0.00 0.00 4,328.34 4,234.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 5,237.65 0.00 0.00 4,366.00 4,272.00 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 Beluga F 5,299.99 0.00 0.00 4,428.34 4,334.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 5,399.99 0.00 0.00 4,528.34 4,434.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 5,499.99 0.00 0.00 4,628.34 4,534.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 5,599.99 0.00 0.00 4,728.34 4,634.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 5,695.65 0.00 0.00 4,824.00 4,730.00 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 Beluga G 5,699.99 0.00 0.00 4,828.34 4,734.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 5,799.99 0.00 0.00 4,928.34 4,834.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 5,899.99 0.00 0.00 5,028.34 4,934.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 5,999.99 0.00 0.00 5,128.34 5,034.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 6,025.65 0.00 0.00 5,154.00 5,060.00 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 Beluga H 6,099.99 0.00 0.00 5,228.34 5,134.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 5/8/2012 9.34:26AM Page 4 COMPASS 2003.16 Build 69 , J R IGINAt_ Halliburton -Sperry HALLIBUR TON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:BRU 244-23 Company: ConocoPhillips(Alaska)Inc.-Expl TVD Reference: Plan 75.5+18.5 @ 94.00ft(Arctic Fox) Project: Beluga River MD Reference: Plan 75.5+18.5 @ 94.00ft(Arctic Fox) Site: Beluga River North Reference: True Well: Plan:BRU 244-23 Survey Calculation Method: Minimum Curvature Wellbore: Plan:BRU 244-23 Design: BRU 244-23(wp04) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 5,234.34 6,199.99 0.00 0.00 5,328.34 5,234.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 6,299.99 0.00 0.00 5,428.34 5,334.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 6,399.99 0.00 0.00 5,528.34 5,434.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 6,499.99 0.00 0.00 5,628.34 5,534.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 6,599.99 0.00 0.00 5,728.34 5,634.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 6,699.99 0.00 0.00 5,828.34 5,734.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 6,730.65 0.00 0.00 5,859.00 5,765.00 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 Beluga I 6,799.99 0.00 0.00 5,928.34 5,834.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 6,899.99 0.00 0.00 6,028.34 5,934.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 6,999.99 0.00 0.00 6,128.34 6,034.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 7,099.99 0.00 0.00 6,228.34 6,134.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 7,199.99 0.00 0.00 6,328.34 6,234.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 7,290.65 0.00 0.00 6,419.00 6,325.00 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 Top Beluga J @ 7291'MD,6419'TVD:683'FSL,326'FEL-Sec23-T13N-R10W-Beluga J(Beluga I base) 7,299.99 0.00 0.00 6,428.34 6,334.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 7,399.99 0.00 0.00 6,528.34 6,434.34 201.35 2,334.31 2,631,039.60 322,972.70 0.00 2,342.39 7,495.65 0.00 0.00 6,624.00 6,530.00 201.35. 2,334.31 • 2,631,039.60 322,972.70 0.00 2,342.39 7"x 8-1/2"-BRU 244-23 30Apr12 Beluga TD Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) BRU 244-23 30Apr12 Beluga E 0.00 0.00 4,014.00 201.35 2,334.31 2,631,039.60 322,972.70 -plan hits target center -Circle(radius 150.00) BRU 244-23 30Apr12 Beluga TD 0.00 0.00 6,624.00 201.35 2,334.31 2,631,039.60 322,972.70 -plan hits target center -Circle(radius 150.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (') 3,514.30 2,859.00 9-5/8"x 12-1/4" 9-5/8 12-1/4 7,495.65 6,624.00 7"x 8-1/2" 7 8-1/2 5/8/2012 9:34:26AM Page 5 COMPASS 2003.16 Build 69 Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:BRU 244-23 Company: ConocoPhillips(Alaska)Inc.-Expl TVD Reference: Plan 75.5+18.5 @ 94.00ft(Arctic Fox) Project: Beluga River MD Reference: Plan 75.5+18.5 @ 94.00ft(Arctic Fox) Site: Beluga River North Reference: True Well: Plan:BRU 244-23 Survey Calculation Method: Minimum Curvature Wellbore: Plan:BRU 244-23 Design: BRU 244-23(wp04) Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (0) (0) 4,279.02 3,429.00 Sterling B 0.00 4,446.20 3,582.00 Sterling C 0.00 4,063.54 3,249.00 Sterling A 0.00 3,685.89 2,979.00 BRWD-1 Injection Zone 0.00 7,290.65 6,419.00 Beluga J(Beluga I base) 0.00 6,730.65 5,859.00 Beluga I 0.00 5,237.65 4,366.00 Beluga F 0.00 5,695.65 4,824.00 Beluga G 0.00 4,885.65 4,014.00 Beluga E 0.00 4,614.28 3,744.00 Beluga D 0.00 6,025.65 5,154.00 Beluga H 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (ft) (ft) (ft) (ft) Comment 18.50 18.50 0.00 0.00 SHL:482'FSL,2619'FWL-Sec23-T13N-R10W 3,514.30 2,859.00 145.25 1,700.03 Surface Csg @ 3514'MD,2859'TVD:627'FSL,961'FEL-Sec23-T13N-R10W 4,063.54 3,249.00 179.29 2,084.86 Top Sterling_A @ 4064'MD,3249'TVD:661'FSL,576'FEL-Sec23-T13N-R10W 4,614.28 3,744.00 199.48 2,313.08 Top Beluga_D @ 4614'MD,3744'TVD:681'FSL,348'FEL-Sec23-T13N-R10W 7,290.65 6,419.00 201.35 2,334.31 Top Beluga J @ 7291'MD,6419'TVD:683'FSL,326'FEL-Sec23-T13N-R1OW 7,495.65 6,624.00 201.35 2,334.31 TD @ 7496'MD,6624'TVD:683'FSL,326'FEL-Sec23-T13N-R10W 5/8/2012 9:34:26AM Page 6 COMPASS 2003.16 Build 69 x .11\ \I 1 0 I d 0 z0 m 05 .C. r 1 rr N alm Fr 0 c. 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N Cl ° t r O CD ea °' _ N ici 7a i N m N OL. w m V 'O 1 I 1 I 1 1 I I 1 1 I j I I I 1 I 1 I I ( I I I l I I I 1 4 1 1 1 1 N 1 1 1 I o O O Q0 C d d n co 0n M N dOd R _ _ (Uy og.Z)Japed uoiieaedes Q 5 BRU 244-23 Drilling Hazards Summary (To be posted in Rig Floor Doghouse prior to spud) Surface: 12-1/4" Hole with 9-5/8" Casin• Event Risk Level Mitigation Strategy Lost Circulation Medium Reduced pump rates, control ROP and running speeds, mud rheology, lost circulation material, use of low density cement slurries. Clay Balling Medium Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Gas Hydrates Low Monitor well, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud temperatures Abnormal Pressure in Low Diverter drills, increased mud weight. Offset Surface Formations drilling does not indicate abnormal pressures in the surface hole. Production: 8-3/4" Hole with 7" Casing Event _ _ Risk Level Mitigation Strategy Lost circulation High Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre-planned LCM pills, lost circulation material. Sloughing Shale, Tight High Increased mud density to control the shale's, Hole manage fluid composition according to plan, control running speeds and ECD's, sweeps Tight hole in coals Medium Control drilling, mud logs, crew awareness Directional Control Medium BHA design, geologic review and advisement of potential slump blocks. Hole swabbing on trips Low Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Low Well control drills, increased mud weight, offset ,, Pressure well data does not indicate abnormal pressures in the area. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard i/ well control practices BRU 244-23 , V Grassroots Well p ConocoPhilli s Completion Schematic Conductor(Driven): 20", .75",API 5L GRB, Full Grvd, R3 Will be driven to Refusal-90'Below Pad Grad; ' i I •r early June 2012 i i i i Halliburton H ES HO stage tool(c�+/-4000'MD -CONTINGENCY IF THERE ARE LOST CIRCULATION i PROBLEMS-- / Chemical infection port with 3/8"SS control line i +/-500'MD j Citi -- j TOC 500' BP6i SCSSSV with''/i'SS control line to surface i TOC+1-3564'MD/2900'TVD above top (6 +/-550'MD i m.,.:.:.:.,' Sterling i i i i Surface Casing: 9-5/8",40#, L-80, BTC i Set @ 3514'MD/2859'TVD(-550'TVD above i 3514 Sterling-A) / -roc / I, C L 4-'/2"Camco KGB-2 GLM w/1"DCK2 shear valve 1 MI, -11 a ■ --1-1- 4-1/2""X" -I I4'/2""X"Nipple(3.813"ID) • •:•,: Beluga H and I will require ---M4v'� ■ _Tr ■ Fracturing operations ,,L I Baker 80-47 Polished Bore Receptacle t_ u ■ ■ Four Isolation Packer with: — Ball Drop Actuated Frac Sleeve RA tag in 7"casing(on 10'pup) Blast Rings Conventional Sliding Sleeves _LLi._ t ID 0 1—� Formaton: gstimated Tops: Pore Pressure ✓ m Lir 7---) Beluga H 6026'MD/5154'TVD 5.1 -9.6 ppg Beluga I 6731'MD/5859'TVD 9.4-9.8 ppg Fifth Isolation Packer with: —7 Ball Drop Toe Plug I Beluga I Base 7291'MD/6419'TVD 9.4-9.8 ppg "XN"Nipple _ WLEG .61111.01 Production Casing: _:, 7",26.00#, L-80, BTC-Mod - - Set @ 7496'MD/6624'TVD (+/-200'MD Below Beluga I Base) BRU 244-23 gL prepared by Hank Baca 05/16/12 ` Sperry Drilling Services Directional Plan wp04 3( )1 \ / rrn l� 21-1/4'2000 PSI Liao lull 43[=.0.1"--- �� 12'ANSI 150 1 63.38' L 35.06' RIG MAT RIG MAT GROUND LEVEL/TOP OF CELLAR I ( 6,00' I 15.50' 38.56' _ 30.00' 49.50" 48.56' 4 1 1- l. 1 Iler7 it= 96.00' — 20'CASING CUT—OFF — '� r 1. hoe 46.50" I 20'VG—LOC ee j` 30.31' I----20 CONDUCTOR 1 —5/8'4Oj LBS CASING PROPRIETARY NOTICE vetcog rayTM The Information conloined hereon is the confidential property of vetcogroy and Its offiliotes.property Is to be used only 21-1/4" DRILLING RISER ASSEMBLY ARRANGED FOR for shall ne0l of eproogray, and shag not be reproduced or used for USE OVER 20" CASING WITH LANDING RING any other purpose without written WITH 20" QUICK CONNECTIONS AND 12" ANSI CLASS 150 OUTLET consent of vetcogroy. DRAM VS DAM G RICE IS MA 2000 Iemen,so 0A4i X amour se DAR CUSTOMER °°A"" SP-6958-1 mC X REfEKIE CONOCO PHILLIPS/ARCTIC FOX/BELUGA PROJECT ALL 110OI001 APE IPgplalAa: 140.£11 or 1 ■ iiillih WI 24.69' Jig4 -iiir ■ 1_d /! ,.a ui ..,. ,.. 18.00' .1 7.63' SLC C _�i='I■ n.M= 1.I 8' 6.00' CRWNDI LEVEL r{TOP OF , wi_ lir 1 14.83' ii F �1 30.00' 1 r 49.50' I iii I II 96.00' it 20'CASING CUT—OFF ç---- , 46.50' 20 CONDUCTOR 9-5/8'44 L80 CASING / 7"26//L80 CASINO PROPRIETARY NOTICE vetcog rayt ma Information contained hereon Is the confidential property of vetcogray ond Its affiliates. It Is to be used only for the benefit of vetcogray, MB-230 MULTIBOWL SYSTEM and shall not be reproduced or used far ELEVATION VIEW OF 7'LANDING JOINT TO GROUND LEVEL any other purpose without written WITH 2-1/I6 5000 SWEEP ON LOWER SECTION OUTLET AND consent of vetcogroy. UPPER SECTION OUTLETS DOM Ws 0010 C.Pof£ ID MR 2009 MaYea 9Y. OATa X AMMO Int OMCUSTOMER Nam'? SP-6958-2 INC. X filmiicE CONOCO PHIWPS/ARCTIC FOX/BELUGA PROJECT wJ.MrR9w ME MATOXSIME 1 awl ar 1 ONIt,� ii E / \L i MIA 24.69" rik _ c, P' 0. a: .11110 • MEM --- riii riza , 1 131C25.63" it . 1111 It' 18.00" ‘--156 F— 'IjAr---)GROUND'LEVEL i TOP OF s-•1 ..1 1 "-Z RIG MAT 6 I Piiii lir i .., • • ,.. j) cli : IIIIIMI 30,00" . r 49.50" lif I ill In UP.' 96.00" 20*CASING CUT-OFF c\-- 46.50" AS. 0011'," 1i. 20 CONDUCTOR -----9-5/8"401 L60 CASING Ga.d`f* cli)____,„ 4-1/2"L80 TUBING 260 180 CASINO •—..--- PROPRIETARY NOTICE vetcogray"' The Information contained hereon Is the confidential property of setcogray and Its affiliates. It le to be used only for the benefit of vatcogray. MB-230 MULTIBOWL SYSTEM and shall not ba reproduced or used for ELEVATION VIEW OF 4-1/2"LANDING JOINT TO GROUND LEVEL any other purpose without written 51111 2-1/16 5000 SWEEP ON LOWER SECTION AND consent of vetcogray. UPPER SECTION OUTLETS CRUX Ott OAIM X.MCC IS APR 209 RENAIED XX DAIX: X APPROYX1 80 DAM CUSTOMER raw SP-6958-3 WC' pEpEREKE CONOCO PHIWPS/ARCT1C FOX/BELUGA PROJECT x us OrlIENSON ME MPIEWL11£ I 9611 Oi i ORIGINi lii 7.AI k't'-'3•J Illillt°011I 141 II 91.67' ' Y AMP 60.12" 50.31' • M`Al 4,E-5000 FS _"1%,- 6-I.IAS TREE M \_► 12.30- 1�� 1� -fir ■ ` 27.30' 18.00' S1t, 47.32' RIG MAT �� I' • ��.� ... �I. _ I =>. fill, �.lir 6.00' GROUND LEVEL/TOP OF•-__.- .. rim h; I 'l t + I� 30.00' -1l 1I rT— 49.50' lir I it`{ iii II 96.00' 20'CASING CUT-OFF .Ili i !i 46.50' •\ A \1 1,, / i —'x-20 CONDUCTOR '----9-5/8'40f L80 CASING 3-1/2'9.2f 1.80 TU8040I / I� T/26f/L80CASING • PROPRIETARY NOTICE vetco ra The Information contained hereon Is the y� v9. confidential property of Aalcogray and Ito olfdtal... It I.to be used only MB-230 MULTIBOWL SYSTEM for the benefit of wlae9ray. and shat/not be reproduced or used for WITH 4-1/2" TREE any ontosery •Rw ht.Titian consent of lcoa MTH 2-1/16 5000 SWEEP ON LOWER SECTION AND UPPER SECTION OUTLETS C WE aA Ie APR 2009 I.xnm Eft aAIE X WC 09220120 019 o"% CUFERENCE NOCO PHIWPS/ARCTIC fOX/BELUCA PROJECT ME.m.c-6Mwm 8a'} I sari cs1 ORIGJNAw • t,r I ITE'.I DEE-2i,!EMI 1 1 ,1 i_,`.' �.H.4FFEk FHEF:i /,L __2 11" , SH.'i-H k I,CUELE G;TE _. I 3_i i I" °:I' C•RILLIi': SP'OI)L 'd;�3-1/i;" FIr ,UTLEi: ' -EA. 3-1%8" 5i< H_,U6_ULICV LVE_ i 5 �2U. 3_1L3_ LIiJ. L < 'AI '/A1'rc_ -- --T r l I I" S1 SKI-FEE: SII!I;LE G%.TE . • ;_-_--_ I I_____ThT r IN I�n =t]�1 2-7A3"X 5"VBR's `� -- I ! ill 1./114s-- '1_____ Blind m ®,�4t �b > Rams a� 1111 914611 loilisti Nim iiii.:_, , 1 II Lim . _ I__ . g �. 1 I-Y run _ 4_.• 0 �pP / _ -_dz-_-F=-.__ r• ,�j� � �' pi �. Rams-_---.-.F=. Ii r 6 .f) • /. N. ea. rya l The Information contatned In fills drawing Is 3/7!09 Belga Pro(ea 1 Iho sole property of Doyon Drilling toe.Any d 1' / �I 'Its >r reproduction In whole or partwIlhoui the ��j�� e-r ArUlc Fox express written consent of Doyon Doyen I r'II..'-.I IN�. ,,,,, cc',,, Sub Section Drilling Inn.is protdbllod. l 5II 1 ' N Shaffer ll'Sox Stack ORIGINtALw ' 'i\I 1 9 IIi 0 ,,,, m 0 51 Z 2bv .+ w 0_ e9 a o d It W g f e mo v) ow ay� iii .,M £ < W gSP, 563 51 51 m J B w .° �' �'< u $ _ ❑ Yr! i > > o 'Fz' `=F' !Y o.io Q o -@Io -0 V •Y a 29 F w 6 < m P W W s . k' 3 o ,Iu au g W W 5 S =gc ENr z p IA <m < o of 9` e ��5 ,1 ,12 .4 ff,o 11,.; L.,, \ r ,� I etl�C C us N _a _._ a , 4 i—s N Av a u{ u r / \ 4-v0 i�� 01 •v k.0 'E y flJ „\\,* i / co I.ro . ro s 4 ' .... ...... i /\\\\,„A‘,,* / ^ /)/4psir \ .\\AID/ t'A N / / kr' vJ � I co O Z ` o ( /'s`. /s 3 R n svo_\s N r �--•--.spy m m 2 0 ods "' ti V,� •� cz3 w =m a 1:ii 0= 4 Z% C.)°- m8 No11 W / \ 1 d �y .4.0 . Ili Ai;AzI $ R 11 vkJJJ Q' ` Q W 0 N ",s A} F. f s • s8 2 e a' Ws 0 YW C \ , 5 6n 9 �/ A TRANSMISSION rii3oN14—wEiruesNEW 50 c APProx. center ofWSa jrag , —- , %; e YWa /a♦ jb..- --,,,,2_,!„) me___ w % a% •gtl� a ti CEA TRANSMISSes- /S. � I R W ADProx. center /.��\, � z / ai a �� Ce 4r, z i.-P Page 1 of 1 Schwartz, Guy L (DOA) From: Baca, Hank [Hank.Baca©conocophillips.com] Sent: Tuesday, June 12, 2012 10:53 AM To: Schwartz, Guy L (DOA) Subject: BRU 244-23 clarifications Guy, as we discussed on the phone: 4 Line 17: we will be testing the 7" casing to 4000psi, not 4500. `' We are reauesting a variance on diverter line size based in the following: We feel the rig's 12" diverter line can adequately handle flow from the 12-1/4" surface hole we will be drilling. BRU 224-23T was drilled on the same pad last year with no shallow gas shows. The displacement distance between surface shoes for 224-23T and 244-23 is —1915'. The Arctic Fox cannot readily handle a 16" diverter. BRU 242-04 surface hole was drilled earlier this month (from a different pad) with no shallow gas shows encountered which is consistent with historical drilling at BRU. Tubular load info below rasing Program Minimum Calculated Safety Factor lole Casing Weight, Grade, size (in.) Size (in.) Thread Burst Collapse Tensioi 2 1/4" 9 5/8" 40#,L-80,BTC M 1.21 5.87 1.44 S 1/2" 7" 26#,L-80,BTC M 1.19 9.08 1.68 4 1/2" x 3 1/2" 12.6#, 9.3# L-80 2.78 2.40 1.52 Please let me know if you other questions. Thanks, Hank Baca Drilling Engineer 907-263-4180 office 907-229-6235 cell 6/12/2012 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST� / WELL NAME ] `- - (/- 26 PTD# Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ��./6.7., POOL: ('(‘'(-1- ---77<-- -(724. Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE 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 name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name)must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 L LI To Cl, 0) 0 a) 4 CO 0 o @ , co -a-) C C7 a . cri a) c . Ii N - oes O 2 co7 OE7 a co m in 0 m Q •3 a -`0 -o T. -J LO LO bLO LO Q = O O L O 0 O 0 0 N � -0.0 O Q Lri tri o N C N N a) a) ,3 -0 ~ Q Q E 3 o 2 Q ot) o. o m o 2 : .o, W T. D CU N N o a W a Cl) n co y Cl) co a) o 0 0 0 Cl) CU 0) n ( a > M' O U) no n ,- 0. 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M M 0 -- U N N N o c (U N al O coN U o c ce (00 N coN O (0_)q dO I.-, to C (p co O. -I: N E U) 0) O C O w oH IC f E E. o 0) E. o Q o U as a w a c0 a Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simpirfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: ConocoPhillips Alaska Field: Beluga River Unit Rig: Doyon Arctic Fox Date: August 4, 2012 Surface Data Logging End of Well Report BRU 244-23 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Formation Tops 7. Survey Report 8. Days vs. Depth Digital Data to include: Final Logs Halliburton Log Viewer EMF Log Viewer EOW Report PDF Version ADI Backup GENERAL WELL INFORMATION Company: ConocoPhillips Alaska Inc. Rig: Doyon Arctic Fox Well: BRU 244-23 Field: Beluga Borough: Kenai Peninsula Borough State: Alaska Country: United States API Number: 50-283-20165-00-00 Sperry Job Number: AK-AM-0009501602 Spud Date: 13 July 2012 SDL Job Start Date: 20 July 2012 TD Date: 27 July 2012 Total Depth: 7,553’ MD; 6,685.6’ TVD SDL Release Date: 04 Aug 2012 North Reference: True Declination: 17.7306° Dip Angle: 74.051° Total Field Strength: 55701 nT Date Of Magnetic Data: 14 July 2012 Wellhead Coordinates N: North 61° 11’ 47.36” Wellhead Coordinates W: West 151° 1’ 8.49“ Drill Floor Elevation 94.00’ Ground Elevation: 75.50’ Permanent Datum: Mean Sea Level SDL Engineers: Emil Opitz, Bradley Causey SDL Sample Catchers: Joshua Cloyd, Elia Epchook, Colten Roehl, Jacob Johnson Company Geologist: Rick Levinson Company Representatives: Scott Heim, Donald Lutrick, Robert Wall, Jimmy Greco SSDS Unit Number: 115 DAILY SUMMARY BRU 244-23 was spudded 13 Jul 2012. SDL was called on to location for the production section on 20 Jul 2012. 07/20/2012 SDL arrives on location. Begin unit rig up. 07/21/2012 Continue to rig up. 07/22/2012 Continue to rig up. 07/23/2012 Pick up BHA #6 @ 0400hrs. SDL flowed gas chromatograph, and then calibrated gas chromatograph. Calibration check of chromatograph was within 0.1% accuracy; 24551 ppm total read, with an actual 24560 total ppm present. Checked calibration of THA from the previous day – OK. We had gaitronics installed in our unit @ 1130 hrs. RIH & tag cement; circulate and condition mud prior to casing test. 07/24/2012 Perform casing test. Drill 20’ of formation and perform FIT test to 14.6ppg EMW @ 0700 hrs. Begin drilling ahead in production section. WITS transmission and INSITE functionality issues arise when new footage is being made. Troubleshooting with MWD and Anchorage ROC to figure out the problem. Issues resolved @ 0910 hrs. Lithology present consists of; shale/mudstone, claystone, siltstone, unconsolidated sands, and coal in varying degrees of maturity. Shales were often carbonaceous in nature. Non-carbonaceous shales were very gritty and sandy/silty. We were continually challenged by the fluctuations of fluid level in the possum belly throughout the entire day, making it difficult to get constant and consistent gas readings. Maximum gas for the day was 216 units @ 3,816’ MD. 07/25/2012 Continue drilling ahead. At 4,506’ MD, perform a planned short trip back to the 9 5/8” casing shoe from 0800 hrs to 1030 hrs. No issues. Resume drilling. Sperry SDL set up a WITS connection to the rigs’ TOTCO/Rigsense machines for Total Gas. Prior to now, none of the rig- wide Rigsense display monitors showed Total Gas. Lithology observed during the day consisted of; shale, unconsolidated sands, and coal. Possum belly fluid fluctuations have rescinded slightly, as coarser screens were added to the end of the shakers. This has been helpful in our getting of more constant and consistent gas data. Maximum gas for the day was 2366 units @ 5,187’ MD. 07/26/2012 Continue drilling ahead. At 5,511’ MD, perform a planned short from 0230 hrs to 0530 hrs. No issues. Resume drilling. Lithology for the day included shales, unconsolidated sands, and coal beds and stringers. Maximum gas for the day was 2,063 units @ 6,421’ MD. Trace amounts of C-2 (Ethane) were detected by the chromatograph occasionally after 6,300’ MD. Intermittently, an oily iridescent sheen was seen in samples, and small amounts of apparent free oil at the shakers/possum belly around and after 6,200’ MD. Inquiries were made with the Mud Engineer to confirm that these manifestations were not related/caused by mud additives – they were not related to/caused by mud or mud additives, but were in fact formation borne. Begin a planned short trip at 6,520’ MD at 2330 hrs. 07/27/2012 Continue the planned short until 0200hrs. No issues. Resume drilling. Lithology for the day included shales, unconsolidated sands, and coal. Maximum gas for the day was 2,910 units @ 7,105’ MD. Continued detection of trace amounts of C-2 (Ethane), as well as occasional identification of C-3 (Propane), by the gas chromatograph. At 1550 hrs, gas data seemed inconsistent and incorrect. The Mudlogger went to check on the gas trap, and found that the 3rd shaker had been blinded off. This in turn halted the flow of mud coming out of the flow line past the gas trap, rendering gas data useless. The Pitwatcher was immediately located and consulted with, and shortly thereafter, shaker #3 was put back online. The recurrence of an oily sheen and free oil at the shakers remained, intermittently, throughout the day. TD was called by Rick Levinson, Company Geologist, at 7,553’ MD. TD was reached @ 1945 hrs on 27 Jul 2012. CBU 2x, then begin wiper trip to the 9 5/8” casing shoe. 07/28/2012 Continue the wiper trip as per plan ahead. Reached 9 5/8” casing shoe without any issues. CBU 2x, and then run back into hole to ream and clean. No issues until approx. 7,200’ MD, began taking weight on the bit. Wash down hole from 7,200’ MD to the bottom. No significant amounts of cuttings were noticed coming over shakers. Continue washing and reaming hole clean. POOH on elevators. L/D BHA. 07/29/2012 Begin to rig up for wireline. Run wireline. SDL checked Chromatograph calibration today, to ensure readings during the drilling were accurate. After 6 days of continuously running, the chromatograph was off by 5%; reading on the high side. Actual ppm of the calibration gas injected was 24560, and the chromatograph read 25972. 07/30/2012 Wireline got stuck in the hole. They were able to get free. Decision made to pull out of hole, and run back in hole for drill pipe conveyed wireline operations. 07/31/2012 Wireline operations still underway. 08/01/2012 Finish wireline logging. POOH. R/U for clean out run. P/U BHA #7 and RIH. 08/02/2012 RIH to bottom. CBU 2x. Maximum trip gas of 877 units. POOH and L/D heavy weight drill pipe and BHA #7. Change to 7” RAMS. 08/03/2012 Test RAMS. R/U to run 7” casing. Perform dummy run – OK. Run in hole with 7” casing. 08/04/2012 Land 7” casing. Rig down unit. Sperry SDL released. . . Density (ppg)Viscosity out (sec/qt) * Tools ECD (ppg) Avg Min Max Gamma, Resistivity, PWD Trip ml/30min RPM mg/l Coal Gvl API FL 5.5 907-263-3009Unit Phone: Kla-Shield Depth Mud Type 24 hr Recap: 27Background 46 Cor Solids (lb/100ft2) 60,00010.40 Condition Chlorides 4224' YP 2 9.65 Weight 3435' Type 9.625 8.75 (current) Maximum 0 0 000 9.65 1.0 22 0.773 11 Size 1 24-Jul-2012 24:00:00Time: Report #: Date: Conoco Phillips BRU 244-23 Beluga River Unit 24 hr Max Beluga Doyon Arctic Fox AK-AM-0009501602 Customer: Well: Avg PVMBT MWD Summary Depth 3435' to 4220' ShClystCly Ss DepthUnits* 10 80 Depth in / out PDC NOV DSF529D 3426' Lithology (%) 0 Total Charges: 7.0 Drilling AheadRig Activity: Flow In (spm) 260.0 (ppb Eq)cP Report For:Heim/Levinson 3435' 4220' 785' Current Pump & Flow Data: Yesterday's Depth: Flow In (gpm) 216 Hours ROP (ft/hr) Bit Type TFA pH 0 0 C-4n 10 DRILLING AHEAD AT REPORT TIME TEST CASEING AND DRILL OUT CEMENT. PERFORM FIT AND BEGIN DRILLING NEW FORMATION. CURRENTLY % 73 md. Average 0 Rig: Job No.: Current Depth: 24 Hour Progress: Daily Charges: 96% 577 301 SPP (psi) Gallons/stroke 2000 @4.23 Minimum C-4i 3816' Max @ ft Chromatograph (ppm) 00 0 0 Area: Location: 6441 0 29781 Logging Engineers:Emil Opitz / Bradley Causey (max)(current) Report By: ROP Set AtSize Bit # Current in Footage WOB Bradley Causey Mud Data C-3 Casing Summary 0 Grade Gas Summary C-2 TuffSiltSiltstLstCht C-5nC-5iC-1 000 0 0 100% Gas In Air=10,000 UnitsConnection(max) Create PDF files without this message by purchasing novaPDF printer (http://www.novapdf.com) . . Density (ppg)Viscosity out (sec/qt) * Logging Engineers:Emil Opitz / Bradley Causey Report By:Bradley Causey Unit Phone:907-263-3009 24 hr Recap:DRILL TO 4499' AND BEGIN SHORT TRIP. TIH AND RESUME DRILLING. CURRENTLY DRILLING AHEAD AT md. REPORT TIME. =100% Gas In Air (current)(max)(max)Background 150 Trip Connection 10,000 Units 0 0 0000Average30634656 0 0 0000Minimum544527'6687 0 0 0000 C-4i C-4n C-5i C-5n Maximum 2366 5187'283200 Units*Depth C-1 C-2 C-3 10 Gas Summary Chromatograph (ppm) (current)10 80 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade 9.625 3426'BTCM 40.0 L-80Casing Summary Size Set At Type Weight 3435' Depth in / out Footage WOB RPM Condition 2 PDC NOV DSF529D 8.75 0.773 25 4.6 10.20 58,000 9.0 Bit #Bit Type Size TFA Hours mg/l % 5321'Kla-Shield 9.70 9.70 52 3.0 14 pH Chlorides Cor Solids Depth Mud Type in (ppb Eq)cP (lb/100ft2)ml/30min Mud Data MBT PV YP API FL Min Max 4220' to 5321'DM, EWR-P4, HCIM, CTN, ALD, EM, BAT Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 577 SPP (psi)2000 Flow In (spm)301 ROP (ft/hr)182.0 125.0 177.0 5206' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Daily Charges:Rig Activity:Drilling Ahead Total Charges:Report For:Heim/Greco/Levinson Rig:Doyon Arctic Fox Current Depth:5321' Job No.:AK-AM-0009501602 24 Hour Progress:1101' Area:Beluga River Unit Time:24:00:00 Location:Beluga Yesterday's Depth:4220' Customer:Conoco Phillips Report #:2 Well:BRU 244-23 Date:25-Jul-2012 Create PDF files without this message by purchasing novaPDF printer (http://www.novapdf.com) . . Density (ppg)Viscosity out (sec/qt) * Customer:Conoco Phillips Report #:3 Well:BRU 244-23 Date:26-Jul-2012 Area:Beluga River Unit Time:24:00:00 Location:Beluga Yesterday's Depth:5321' Rig:Doyon Arctic Fox Current Depth:6520' Job No.:AK-AM-0009501602 24 Hour Progress:1199' Daily Charges:Rig Activity:Drilling Ahead Total Charges:Report For:Heim/Greco/Levinson ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)0.0 114.0 158.0 5825' Flow In (gpm)577 SPP (psi)2000 Flow In (spm)301 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max 5321' to 6520'DM, EWR-P4, HCIM, CTN, ALD, EM, BAT Mud Data MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in (ppb Eq)cP (lb/100ft2)ml/30min mg/l % 6520'Kla-Shield 9.70 9.70 52 3.0 14 25 4.6 10.20 58,000 9.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 2 PDC NOV DSF529D 8.75 0.773 3435' Casing Summary Size Set At Type Weight Grade 9.625 3426'BTCM 40.0 L-80 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current)20 60 20 Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 2063 6421'248226 0 0 0 0 0 0 Minimum 68 6495'7977 13 0 0 0 0 0 Average 270 43614 2 1 0 0 0 0 Background 0 Trip Connection 10,000 Units =100% Gas In Air (current)(max)(max) 24 hr Recap:DRILL TO 5512' AND SHORT TRIP 1000 FEET. RESUME DRILLING AND DRILL TO 6520'. PERFORM SHORT TRIP md. CURRENTLY SHORT TRIPPING AT REPORT TIME Logging Engineers:Emil Opitz / Bradley Causey Report By:Bradley Causey Unit Phone:907-263-3009 Create PDF files without this message by purchasing novaPDF printer (http://www.novapdf.com) . . Density (ppg)Viscosity out (sec/qt) * Logging Engineers:Emil Opitz / Bradley Causey Report By:Bradley Causey Unit Phone:907-263-3009 24 hr Recap:FINISH WIPER TRIP AND RESUME DRILLING @ 0230. DRILL TO 7553' AND TD. CIRC 2 BOTTOMS UP AND WIPER md. TRIP TO SHOE. CURRENTLY POOH FOR WIPER TRIP AT REPORT TIME. =100% Gas In Air (current)(max)(max)Background 0 Trip Connection 10,000 Units 0 0 0440Average28033420 0 0 0800Minimum1006993'5091 0 0 0000 C-4i C-4n C-5i C-5n Maximum 2910 6421'248226 Units*Depth C-1 C-2 C-3 20 Gas Summary Chromatograph (ppm) (current)10 70 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade 9.625 3426'BTCM 40.0 L-80Casing Summary Size Set At Type Weight 3435' Depth in / out Footage WOB RPM Condition 2 PDC NOV DSF529D 8.75 0.773 27 4.6 10.20 54,000 9.0 Bit #Bit Type Size TFA Hours mg/l % 6520'Kla-Shield 9.95 9.95 52 4.0 15 pH Chlorides Cor Solids Depth Mud Type in (ppb Eq)cP (lb/100ft2)ml/30min Mud Data MBT PV YP API FL Min Max 6520' to 7553'DM, EWR-P4, HCIM, CTN, ALD, EM, BAT Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 556 SPP (psi)3220 Flow In (spm)294 ROP (ft/hr)0.0 74.0 218.0 6572' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Daily Charges:Rig Activity:Drilling Ahead Total Charges:Report For:Heim/Greco/Levinson Rig:Doyon Arctic Fox Current Depth:7553' Job No.:AK-AM-0009501602 24 Hour Progress:1033' Area:Beluga River Unit Time:24:00:00 Location:Beluga Yesterday's Depth:6520' Customer:Conoco Phillips Report #:4 Well:BRU 244-23 Date:27-Jul-2012 Create PDF files without this message by purchasing novaPDF printer (http://www.novapdf.com) . . Density (ppg)Viscosity out (sec/qt) * Logging Engineers:Emil Opitz / Bradley Causey Report By:Bradley Causey Unit Phone:907-263-3009 24 hr Recap:WIPER TRIP TO SHOE AND THAN BACK TO BOTTOM. MAX TRIP GAS OF 577. POOH AND LAY DOWN BHA. md. CURRENTLY LAYING DOWN BHA AT REPORT TIME. =100% Gas In Air (current)(max)(max)Background 0 Trip 577 Connection 10,000 Units 0 0 0000Average00 0 0 0 0 0Minimum00' 0 0 0 0 0 C-4i C-4n C-5i C-5n Maximum 0 0' Units*Depth C-1 C-2 C-3 20 Gas Summary Chromatograph (ppm) (current)10 70 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly Grade 9.625 3426'BTCM 40.0 L-80Casing Summary Size Set At Type Weight 3435' Depth in / out Footage WOB RPM Condition 2 PDC NOV DSF529D 8.75 0.773 27 4.6 10.20 54,000 9.0 Bit #Bit Type Size TFA Hours mg/l % 6520'Kla-Shield 9.95 9.95 52 4.0 15 pH Chlorides Cor Solids Depth Mud Type in (ppb Eq)cP (lb/100ft2)ml/30min Mud Data MBT PV YP API FL Min Max 7553' to 7553'DM, EWR-P4, HCIM, CTN, ALD, EM, BAT Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 0 SPP (psi)0 Flow In (spm)0 ROP (ft/hr)0.0 0.0 0.0 0' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Daily Charges:Rig Activity:LAYING DOWN BHA Total Charges:Report For:Heim/Greco/Levinson Rig:Doyon Arctic Fox Current Depth:7553' Job No.:AK-AM-0009501602 24 Hour Progress:0' Area:Beluga River Unit Time:24:00:00 Location:Beluga Yesterday's Depth:7553' Customer:Conoco Phillips Report #:5 Well:BRU 244-23 Date:28-Jul-2012 Create PDF files without this message by purchasing novaPDF printer (http://www.novapdf.com) . . Density (ppg)Viscosity out (sec/qt) * Logging Engineers:Emil Opitz / Bradley Causey Report By:Bradley Causey Unit Phone:907-263-3009 24 hr Recap:FINISH LAYING DOWN BHA AND RIG UP WIRELINE LOGGERS. FIRST ATTEMPT GOT STUCK AND HAD TO PULL md. OUT. CURRENTLY TRYING SECOND RUN WITH DRILL PIPE TO ASSIST TOOL IN GETTING DOWN HOLE. =100% Gas In Air (current)(max)(max)Background 0 Trip 0 Connection 10,000 Units 0 0 0000Average00 0 0 0 0 0Minimum00' 0 0 0 0 0 C-4i C-4n C-5i C-5n Maximum 0 0' Units*Depth C-1 C-2 C-3 20 Gas Summary Chromatograph (ppm) (current)10 70 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 9.625 3426'BTCM 40.0 L-80 Grade 20 107'WELD 165.0 Casing Summary Size Set At Type Weight 3435' 7553' 4118'7.0 88.0 2 Depth in / out Footage WOB RPM Condition 2 PDC NOV DSF529D 8.75 0.773 79.30 27 4.6 10.20 54,000 9.0 Bit #Bit Type Size TFA Hours mg/l % 7553'Kla-Shield 9.95 9.95 52 4.0 15 pH Chlorides Cor Solids Depth Mud Type in (ppb Eq)cP (lb/100ft2)ml/30min Mud Data MBT PV YP API FL Min Max 7553' to 7553'DM, EWR-P4, HCIM, CTN, ALD, EM, BAT Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 0 SPP (psi)0 Flow In (spm)0 ROP (ft/hr)0.0 0.0 0.0 0' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Daily Charges:Rig Activity:WIRELINE LOGGING Total Charges:Report For:Heim/Greco/Levinson Rig:Doyon Arctic Fox Current Depth:7553' Job No.:AK-AM-0009501602 24 Hour Progress:0' Area:Beluga River Unit Time:24:00:00 Location:Beluga Yesterday's Depth:7553' Customer:Conoco Phillips Report #:6 Well:BRU 244-23 Date:29-Jul-2012 Create PDF files without this message by purchasing novaPDF printer (http://www.novapdf.com) . . Density (ppg)Viscosity out (sec/qt) * Logging Engineers:Emil Opitz / Bradley Causey Report By:Bradley Causey Unit Phone:907-263-3009 24 hr Recap:SECOND WIRELINE RUN LOST COMMUNICATION WITH TOOL. ATTEMPTING THIRD RUN AT REPORT TIME. md. =100% Gas In Air (current)(max)(max)Background 0 Trip 0 Connection 10,000 Units 0 0 0000Average00 0 0 0 0 0Minimum00' 0 0 0 0 0 C-4i C-4n C-5i C-5n Maximum 0 0' Units*Depth C-1 C-2 C-3 20 Gas Summary Chromatograph (ppm) (current)10 70 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 9.625 3426'BTCM 40.0 L-80 Grade 20 107'WELD 165.0 Casing Summary Size Set At Type Weight 3435' 7553' 4118'7.0 88.0 2 Depth in / out Footage WOB RPM Condition 2 PDC NOV DSF529D 8.75 0.773 79.30 27 4.6 10.20 54,000 9.0 Bit #Bit Type Size TFA Hours mg/l % 7553'Kla-Shield 9.95 9.95 52 4.0 15 pH Chlorides Cor Solids Depth Mud Type in (ppb Eq)cP (lb/100ft2)ml/30min Mud Data MBT PV YP API FL Min Max 7553' to 7553'DM, EWR-P4, HCIM, CTN, ALD, EM, BAT Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 0 SPP (psi)0 Flow In (spm)0 ROP (ft/hr)0.0 0.0 0.0 0' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Daily Charges:Rig Activity:WIRELINE LOGGING Total Charges:Report For:Heim/Greco/Levinson Rig:Doyon Arctic Fox Current Depth:7553' Job No.:AK-AM-0009501602 24 Hour Progress:0' Area:Beluga River Unit Time:1/1/1900 0:00 Location:Beluga Yesterday's Depth:7553' Customer:Conoco Phillips Report #:7 Well:BRU 244-23 Date:30-Jul-2012 Create PDF files without this message by purchasing novaPDF printer (http://www.novapdf.com) . . Density (ppg)Viscosity out (sec/qt) * Logging Engineers:Emil Opitz / Bradley Causey Report By:Bradley Causey Unit Phone:907-263-3009 24 hr Recap:WIRELINE LOGGING AT REPORT TIME. md. =100% Gas In Air (current)(max)(max)Background 0 Trip 0 Connection 10,000 Units 0 0 0000Average00 0 0 0 0 0Minimum00' 0 0 0 0 0 C-4i C-4n C-5i C-5n Maximum 0 0' Units*Depth C-1 C-2 C-3 20 Gas Summary Chromatograph (ppm) (current)10 70 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 9.625 3426'BTCM 40.0 L-80 Grade 20 107'WELD 165.0 Casing Summary Size Set At Type Weight 3435' 7553' 4118'7.0 88.0 2 Depth in / out Footage WOB RPM Condition 2 PDC NOV DSF529D 8.75 0.773 79.30 27 4.6 10.20 54,000 9.0 Bit #Bit Type Size TFA Hours mg/l % 7553'Kla-Shield 9.95 9.95 52 4.0 15 pH Chlorides Cor Solids Depth Mud Type in (ppb Eq)cP (lb/100ft2)ml/30min Mud Data MBT PV YP API FL Min Max 7553' to 7553'DM, EWR-P4, HCIM, CTN, ALD, EM, BAT Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 0 SPP (psi)0 Flow In (spm)0 ROP (ft/hr)0.0 0.0 0.0 0' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Daily Charges:Rig Activity:WIRELINE LOGGING Total Charges:Report For:Heim/Greco/Levinson Rig:Doyon Arctic Fox Current Depth:7553' Job No.:AK-AM-0009501602 24 Hour Progress:0' Area:Beluga River Unit Time:1/1/1900 0:00 Location:Beluga Yesterday's Depth:7553' Customer:Conoco Phillips Report #:8 Well:BRU 244-23 Date:31-Jul-2012 Create PDF files without this message by purchasing novaPDF printer (http://www.novapdf.com) . . Density (ppg)Viscosity out (sec/qt) * Logging Engineers:Emil Opitz / Bradley Causey Report By:Bradley Causey Unit Phone:907-263-3009 24 hr Recap:FINISH WIRELINE LOGGING AND RIG DOWN LOGGERS. PU BIT AND BHA AND START TIH FOR CLEANUP TRIP. md. CURRENTLY TIH AT REPORT TIME. =100% Gas In Air (current)(max)(max)Background 0 Trip 0 Connection 10,000 Units 0 0 0000Average00 0 0 0 0 0Minimum00' 0 0 0 0 0 C-4i C-4n C-5i C-5n Maximum 0 0' Units*Depth C-1 C-2 C-3 20 Gas Summary Chromatograph (ppm) (current)10 70 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 9.625 3426'BTCM 40.0 L-80 Grade 20 107'WELD 165.0 Casing Summary Size Set At Type Weight 3435' 7553' 4118'7.0 88.0 2 Depth in / out Footage WOB RPM Condition 2 PDC NOV DSF529D 8.75 0.773 79.30 27 4.6 10.20 54,000 9.0 Bit #Bit Type Size TFA Hours mg/l % 7553'Kla-Shield 9.95 9.95 52 4.0 15 pH Chlorides Cor Solids Depth Mud Type in (ppb Eq)cP (lb/100ft2)ml/30min Mud Data MBT PV YP API FL Min Max 7553' to 7553'DM, EWR-P4, HCIM, CTN, ALD, EM, BAT Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 0 SPP (psi)0 Flow In (spm)0 ROP (ft/hr)0.0 0.0 0.0 0' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Daily Charges:Rig Activity:WIRELINE LOGGING Total Charges:Report For:Heim/Greco/Levinson Rig:Doyon Arctic Fox Current Depth:7553' Job No.:AK-AM-0009501602 24 Hour Progress:0' Area:Beluga River Unit Time:24:00:00 Location:Beluga Yesterday's Depth:7553' Customer:Conoco Phillips Report #:9 Well:BRU 244-23 Date:1-Aug-2012 Create PDF files without this message by purchasing novaPDF printer (http://www.novapdf.com) . . Density (ppg)Viscosity out (sec/qt) * Customer:Conoco Phillips Report #:10 Well:BRU 244-23 Date:2-Aug-2012 Area:Beluga River Unit Time:24:00:00 Location:Beluga Yesterday's Depth:7553' Rig:Doyon Arctic Fox Current Depth:7553' Job No.:AK-AM-0009501602 24 Hour Progress:0' Daily Charges:Rig Activity:WIRELINE LOGGING Total Charges:Report For:Heim/Greco/Levinson ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP (ft/hr)0.0 0.0 0.0 0' Flow In (gpm)0 SPP (psi)0 Flow In (spm)0 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max 7553' to 7553'DM, EWR-P4, HCIM, CTN, ALD, EM, BAT Mud Data MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Type in (ppb Eq)cP (lb/100ft2)ml/30min mg/l % 7553'Kla-Shield 9.95 9.95 52 4.0 15 27 4.6 10.20 54,000 9.0 Bit #Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 2 PDC NOV DSF529D 8.75 0.773 79.30 3435' 7553' 4118'7.0 88.0 2 Casing Summary Size Set At Type Weight Grade 20 107'WELD 165.0 9.625 3426'BTCM 40.0 L-80 Lithology (%)Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff (current)10 70 20 Gas Summary Chromatograph (ppm) Units*Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0' 0 0 0 0 0 Minimum 0 0' 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 Background 0 Trip 877 Connection 10,000 Units =100% Gas In Air (current)(max)(max) 24 hr Recap:FINISH TIH WITH A MAX TRIP GAS OF 877. POOH AND LAY DOWN BHA AND HW DP. CURRENTLY RIGGING UP FOR md. CASEING AT REPORT TIME. Logging Engineers:Emil Opitz / Bradley Causey Report By:Bradley Causey Unit Phone:907-263-3009 Create PDF files without this message by purchasing novaPDF printer (http://www.novapdf.com) . . Density (ppg)Viscosity out (sec/qt) * Logging Engineers:Emil Opitz / Bradley Causey Report By:Bradley Causey Unit Phone:907-263-3009 24 hr Recap:FINISH RIGGING UP TO RUN CASEING. BEGIN RUNNING CASEING STOP TO FILL PIPE AND CIRC OUT GAS md. MAX GAS OF 157 DURING CIRCULATIONS. =100% Gas In Air (current)(max)(max)Background 0 Trip 157 Connection 10,000 Units 0 0 0000Average00 0 0 0 0 0Minimum00' 0 0 0 0 0 C-4i C-4n C-5i C-5n Maximum 0 0' Units*Depth C-1 C-2 C-3 20 Gas Summary Chromatograph (ppm) (current)10 70 Clyst Sh Lst Coal Gvl Tuff Lithology (%)Ss Cht Silt Siltst Cly 9.625 3426'BTCM 40.0 L-80 Grade 20 107'WELD 165.0 Casing Summary Size Set At Type Weight 3435' 7553' 4118'7.0 88.0 2 Depth in / out Footage WOB RPM Condition 2 PDC NOV DSF529D 8.75 0.773 79.30 27 4.6 10.20 54,000 9.0 Bit #Bit Type Size TFA Hours mg/l % 7553'Kla-Shield 9.95 9.95 52 4.0 15 pH Chlorides Cor Solids Depth Mud Type in (ppb Eq)cP (lb/100ft2)ml/30min Mud Data MBT PV YP API FL Min Max 7553' to 7553'DM, EWR-P4, HCIM, CTN, ALD, EM, BAT Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg 0 SPP (psi)0 Flow In (spm)0 ROP (ft/hr)0.0 0.0 0.0 0' Flow In (gpm) ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: Daily Charges:Rig Activity:WIRELINE LOGGING Total Charges:Report For:Heim/Greco/Levinson Rig:Doyon Arctic Fox Current Depth:7553' Job No.:AK-AM-0009501602 24 Hour Progress:0' Area:Beluga River Unit Time:24:00:00 Location:Beluga Yesterday's Depth:7553' Customer:Conoco Phillips Report #:11 Well:BRU 244-23 Date:3-Aug-2012 Create PDF files without this message by purchasing novaPDF printer (http://www.novapdf.com) W E L L N A M E : BR U 2 4 4 - 2 3 LO C A T I O N : Beluga OP E R A T O R : Co n o c o P h i l l i p s A l as k a I n c . AR E A : Beluga River Unit MU D C O : MI S w a c o ST A T E : Alaska RI G : Do y o n A r c t i c F o x SP U D : 13-Jul-12 SP E R R Y J O B : AK - A M - 0 0 0 9 5 0 1 6 0 2 TD : 27-Jul-12 BI T RE C O R D BH A # S D L RU N # Bi t # B i t T y p e B i t Si z e De p t h In De p t h Ou t Fo o t a g e B i t Ho u r s TF A A V G RO P WO B (m a x ) RP M (m a x ) SP P (m a x ) FL O W G P M (m a x ) Bi t G r a d e R e m a r k s 6 5 0 0 2 N O V D S F 5 1 9 D 8 . 7 5 3 4 3 5 7 5 5 3 4 1 1 8 4 3 . 9 6 0 . 7 7 3 9 4 . 0 12 88 3 3 1 0 5 6 5 1 - 2 - B T - T - X - I - W T - T D T D 8 . 7 5 " P r o d u c t i o n H o l e S e c t i o n W E L L N A M E : BR U 2 4 4 - 2 3 LO C A T I O N : Be l u g a OP E R A T O R : Co n o c o P h i l l i p s A l a s k a AR E A : Be l u g a R i v e r U n i t MU D C O : MI S w a c o ST A T E : A la s k a RI G : Do y o n A r c t i c F o x SP U D : 13 - J u l - 1 2 SP E R R Y J O B : A K- A M - 0 0 0 9 5 0 1 6 0 2 TD : 27 - J u l - 1 2 W a t e r - B a s e d M u d R e c o r d Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e S o l i d s Oi l / W a t e r Sd A l k a l p H M B T P f / M f C h l o r H a r d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % % % P m l b / g a l m g / L C a + + 20 - J u l 3 4 3 5 9 . 6 0 2 2 0 2 5 5 5 3 0 / 4 9 / 6 2 1 0 5 / 8 0 / 7 0 / 5 5 / 2 9 / 2 7 2 / 7 . 0 - / 9 3 0 . 5 0 0 . 1 0 8 . 7 4 0 . 0 0 . 1 0 / . 4 0 4 0 0 4 0 . 0 0 R I H w / 9 5 / 8 " c a s i n g 21 - J u l 3 4 3 5 - - - - - - - - - - - - - - - - - N / U B O P s 22 - J u l 3 4 3 5 9 . 4 0 5 6 1 0 2 3 7 / 8 / 1 0 5 . 5 4 3 / 3 3 / 2 7 / 2 0 / 7 / 6 1 / 5 . 0 - / 9 5 t r 6 . 4 0 1 0 . 4 < 5 6 . 4 0 / 1 0 . 2 0 4 8 0 0 0 6 0 . 0 0 P O O H w / 4 " D P 23 - J u l 3 4 5 5 9 . 4 0 6 1 1 0 2 3 7 / 8 / 1 0 5 . 5 4 3 / 3 3 / 2 7 / 2 0 / 7 / 6 1 / 5 . 0 - / 9 5 t r 8 . 5 0 1 0 . 4 0 . 5 0 7 . 4 0 / 1 0 . 0 0 5 6 0 0 0 6 0 . 0 0 P r e s s u r e t e s t c a s i n g 24 - J u l 4 1 4 2 9 . 6 0 4 5 9 1 9 4 / 6 / 8 5 . 2 3 7 / 2 8 / 2 2 / 1 6 / 5 / 4 1 / 8 . 0 1 / 9 1 1 . 0 0 6 . 0 0 1 0 . 3 1 . 0 0 5 . 8 0 / 1 0 . 8 0 6 1 0 0 0 6 0 . 0 0 D r i l l i n g a h e a d p r o d u c t i o n 25 - J u l 5 1 6 5 9 . 7 0 5 2 1 4 2 5 7 / 1 0 / 1 3 4 . 6 5 3 / 3 9 / 3 3 / 2 4 / 8 / 7 1 / 1 9 . 0 2 / 8 9 0 . 7 5 5 . 2 0 1 0 . 2 3 . 0 0 5 . 5 0 / 9 . 0 0 5 8 0 0 0 4 0 . 0 0 D r i l l i n g a h e a d p r o d u c t ion 26 - J u l 6 4 5 5 9 . 7 0 4 7 1 3 2 1 6 / 9 / 1 2 4 . 6 4 7 / 3 4 / 2 9 / 2 1 / 7 / 6 1 / 1 1 0 . 0 2 / 8 8 0 . 7 5 1 . 5 0 9 . 8 4 . 0 0 1 . 3 0 / 3 . 6 0 5 2 0 0 0 4 0 . 0 0 P l a n n e d w i p e r t r i p @ 6 5 20' MD 27 - J u l 7 5 5 3 9 . 9 0 5 0 1 4 2 6 7 / 1 0 / 1 4 4 . 4 5 4 / 4 0 / 3 4 / 2 3 / 8 / 6 1 / 1 1 0 . 0 3 / 8 7 0 . 7 5 1 . 5 0 9 . 9 4 . 2 5 1 . 4 0 / 4 . 2 0 7 0 0 0 0 4 0 . 0 0 W i p e r t r i p t o 9 5 / 8 " c asing shoe 28 - J u l 7 5 5 3 9 . 8 0 5 3 1 5 2 4 6 / 9 / 1 3 4 . 5 5 4 / 3 9 / 3 2 / 2 4 / 7 / 5 1 / 1 1 0 . 0 3 / 8 7 0 . 7 5 1 . 5 0 9 . 9 4 . 2 5 1 . 7 0 / 4 . 8 0 7 0 0 0 0 4 0 . 0 0 L / D B H A 29 - J u l 7 5 5 3 9 . 7 0 5 3 1 4 2 5 6 / 1 0 / 1 5 4 . 6 5 3 / 3 9 / 3 2 / 2 3 / 7 / 6 1 / 1 1 0 . 0 3 / 8 7 0 . 7 5 1 . 9 0 9 . 9 4 . 5 0 2 . 0 0 / 4 . 6 0 6 8 0 0 0 4 0 . 0 0 W i r e l i n e l o g g i n g 30 - J u l 7 5 5 3 9 . 8 0 5 4 1 5 2 4 5 / 9 / 1 4 4 . 2 5 4 / 3 9 / 3 3 / 2 3 / 6 / 5 1 / 1 1 0 . 0 3 / 8 7 0 . 7 5 1 . 4 0 1 0 . 0 4 . 5 0 1 . 5 0 / 4 . 4 0 6 4 0 0 0 4 0 . 0 0 W i r e l i n e l o g g i n g 31 - J u l 7 5 5 3 9 . 8 0 5 2 1 5 2 2 5 / 9 / 1 3 4 . 4 5 2 / 3 7 / 3 1 / 2 1 / 6 / 5 1 / 1 1 0 . 0 3 / 8 7 0 . 7 5 1 . 5 0 1 0 . 0 4 . 5 0 1 . 5 0 / 4 . 3 0 6 4 0 0 0 4 0 . 0 0 W i r e l i n e l o g g i n g 1- A u g 7 5 5 3 9 . 8 0 5 0 1 5 2 1 5 / 7 / 1 0 4 . 5 5 1 / 3 6 / 2 9 / 2 1 / 6 / 5 1 / 1 1 0 . 0 3 / 8 7 0 . 7 5 1 . 3 0 1 0 . 0 4 . 5 0 1 . 2 0 / 4 . 2 0 6 4 0 0 0 4 0 . 0 0 R I H f o r c l e a n o u t r u n 2- A u g 7 5 5 3 9 . 9 0 4 7 1 0 1 5 4 / 5 / 8 4 . 2 3 5 / 2 5 / 1 9 / 1 6 / 5 / 4 1 / 1 1 0 . 0 3 / 8 7 0 . 7 5 1 . 5 0 1 0 . 0 4 . 5 0 1 . 5 0 / 3 . 8 0 6 5 0 0 0 4 0 . 0 0 C h a n g e o u t R A M s 3- A u g 7 5 5 3 9 . 9 0 4 4 1 1 1 4 4 / 5 / 8 4 . 2 3 6 / 2 5 / 2 1 / 1 5 / 4 / 3 1 / 1 1 0 . 0 3 / 8 7 0 . 5 0 1 . 4 0 1 0 . 0 4 . 5 0 1 . 4 0 / 4 . 0 0 6 1 0 0 0 4 0 . 0 0 R I H w / 7 " c a s i n g Ca s i n g R e c o r d 20 " C o n d u c t o r @ 1 0 7 ' 9 5 / 8 " S u r f a c e @ 3 , 4 2 6 ' M D BRU 244‐23 KB = 18.5' Formation/Unit MD TVD TVDss Injection Zone 3672 2964 2945.5 Sterling A 4057 3249 3230.5 Sterling B 4261 3421 3402.5 Sterling C 4430 3574 3555.5 Beluga D 4594 3730 3711.5 Beluga E 4862 3995 3976.5 Beluga F 5199 4332 4313.5 Beluga G 5633 4766 4747.5 Beluga H 5959 5092 5073.5 Beluga I 6632 5764 5745.5 Beluga J 7355 6488 6469.5 TD 7553 6686 6667.5 Formation Tops Project: Company: Local Co-ordinate Reference: TVD Reference: Site: ConocoPhillips(Alaska) Inc. Beluga River Beluga River ConocoPhillips (Alaska) Inc. Definitive Survey Report Well: Wellbore: BRU 244-23 BRU 244-23 Survey Calculation Method:Minimum Curvature Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) Design:BRU 244-23 Database:CPAI EDM Production MD Reference:Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) North Reference: Well BRU 244-23 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Beluga River Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: BRU 244-23 ft ft 0.00 0.00 2,630,874.59 320,635.69 75.50Wellhead Elevation:ft0.00 61° 11' 49.366 N 151° 1' 0.469 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) BRU 244-23 Model NameMagnetics BGGM2011 7/14/2012 17.73 74.05 55,700 Phase:Version: Audit Notes: Design BRU 244-23 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (°) +E/-W (ft) Tie On Depth:18.50 86.350.000.0018.50 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date Survey Date MWD+SCC+SAG MWD + Short Collar correction + BHA SAG C184.66 3,368.02 BRU 244-23 (SAG corrected) (BRU 244-7/24/2012 12:0 MWD+SCC+SAG MWD + Short Collar correction + BHA SAG C3,368.02 7,513.83 BRU 244-23 (SAG corrected) (BRU 244-7/24/2012 12:0 MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 18.50 0.00 0.00 18.50 0.00 0.00-75.50 2,630,874.59 320,635.69 0.00 0.00 UNDEFINED 184.66 0.26 223.43 184.66 -0.27 -0.2690.66 2,630,874.32 320,635.42 0.16 -0.28 MWD+SCC+SAG (1) 244.26 0.48 232.72 244.26 -0.52 -0.55150.26 2,630,874.07 320,635.13 0.38 -0.58 MWD+SCC+SAG (1) 304.93 0.23 261.76 304.93 -0.69 -0.87210.93 2,630,873.90 320,634.80 0.50 -0.92 MWD+SCC+SAG (1) 366.19 0.41 240.50 366.19 -0.82 -1.19272.19 2,630,873.78 320,634.49 0.35 -1.24 MWD+SCC+SAG (1) 426.18 0.33 241.50 426.17 -1.01 -1.52332.17 2,630,873.60 320,634.15 0.13 -1.59 MWD+SCC+SAG (1) 484.91 0.14 201.53 484.90 -1.16 -1.70390.90 2,630,873.46 320,633.97 0.41 -1.77 MWD+SCC+SAG (1) 546.11 0.97 84.42 546.10 -1.17 -1.21452.10 2,630,873.43 320,634.46 1.70 -1.28 MWD+SCC+SAG (1) 611.06 2.41 90.48 611.02 -1.13 0.70517.02 2,630,873.44 320,636.37 2.23 0.63 MWD+SCC+SAG (1) 673.84 4.83 87.11 673.67 -1.01 4.66579.67 2,630,873.50 320,640.33 3.87 4.59 MWD+SCC+SAG (1) 737.30 7.74 86.55 736.74 -0.62 11.60642.74 2,630,873.79 320,647.27 4.59 11.53 MWD+SCC+SAG (1) 798.90 9.93 86.21 797.61 -0.02 21.04703.61 2,630,874.24 320,656.72 3.56 20.99 MWD+SCC+SAG (1) 861.84 10.64 85.76 859.54 0.77 32.25765.54 2,630,874.85 320,667.94 1.14 32.23 MWD+SCC+SAG (1) 8/6/2012 12:17:48PM COMPASS 2003.16 Build 69 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: ConocoPhillips(Alaska) Inc. Beluga River Beluga River ConocoPhillips (Alaska) Inc. Definitive Survey Report Well: Wellbore: BRU 244-23 BRU 244-23 Survey Calculation Method:Minimum Curvature Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) Design:BRU 244-23 Database:CPAI EDM Production MD Reference:Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) North Reference: Well BRU 244-23 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 923.99 12.54 87.45 920.42 1.49 44.71826.42 2,630,875.38 320,680.41 3.11 44.72 MWD+SCC+SAG (1) 986.60 15.41 88.73 981.17 1.98 59.82887.17 2,630,875.64 320,695.53 4.61 59.83 MWD+SCC+SAG (1) 1,051.00 18.75 88.84 1,042.72 2.38 78.73948.72 2,630,875.74 320,714.44 5.19 78.72 MWD+SCC+SAG (1) 1,085.83 19.76 87.90 1,075.60 2.71 90.21981.60 2,630,875.89 320,725.92 3.03 90.20 MWD+SCC+SAG (1) 1,111.92 20.47 87.19 1,100.10 3.10 99.171,006.10 2,630,876.14 320,734.89 2.88 99.17 MWD+SCC+SAG (1) 1,177.90 22.10 85.74 1,161.58 4.58 123.081,067.58 2,630,877.25 320,758.81 2.60 123.12 MWD+SCC+SAG (1) 1,241.26 22.22 88.35 1,220.26 5.81 146.941,126.26 2,630,878.11 320,782.69 1.57 147.01 MWD+SCC+SAG (1) 1,305.43 25.27 87.38 1,278.99 6.79 172.751,184.99 2,630,878.69 320,808.52 4.79 172.84 MWD+SCC+SAG (1) 1,340.16 27.38 87.48 1,310.12 7.48 188.141,216.12 2,630,879.14 320,823.91 6.08 188.23 MWD+SCC+SAG (1) 1,368.08 29.07 87.29 1,334.71 8.08 201.331,240.71 2,630,879.54 320,837.11 6.06 201.44 MWD+SCC+SAG (1) 1,400.46 31.64 87.62 1,362.65 8.81 217.681,268.65 2,630,880.01 320,853.46 7.95 217.80 MWD+SCC+SAG (1) 1,430.94 34.03 87.75 1,388.26 9.47 234.191,294.26 2,630,880.42 320,869.98 7.84 234.32 MWD+SCC+SAG (1) 1,462.15 35.80 87.58 1,413.85 10.20 252.041,319.85 2,630,880.87 320,887.84 5.68 252.17 MWD+SCC+SAG (1) 1,493.28 37.34 87.31 1,438.85 11.03 270.561,344.85 2,630,881.41 320,906.37 4.97 270.72 MWD+SCC+SAG (1) 1,559.48 39.48 86.23 1,490.72 13.36 311.621,396.72 2,630,883.09 320,947.46 3.39 311.84 MWD+SCC+SAG (1) 1,621.29 41.22 84.76 1,537.83 16.51 351.511,443.83 2,630,885.62 320,987.39 3.21 351.85 MWD+SCC+SAG (1) 1,682.47 43.35 83.82 1,583.09 20.61 392.471,489.09 2,630,889.09 321,028.41 3.63 392.99 MWD+SCC+SAG (1) 1,746.14 46.03 84.90 1,628.35 25.00 437.031,534.35 2,630,892.79 321,073.02 4.37 437.73 MWD+SCC+SAG (1) 1,808.62 45.62 85.05 1,671.89 28.93 481.661,577.89 2,630,896.02 321,117.71 0.68 482.53 MWD+SCC+SAG (1) 1,871.11 45.80 85.54 1,715.53 32.59 526.251,621.53 2,630,898.99 321,162.34 0.63 527.25 MWD+SCC+SAG (1) 1,934.36 48.72 85.66 1,758.45 36.16 572.561,664.45 2,630,901.83 321,208.70 4.62 573.70 MWD+SCC+SAG (1) 1,996.44 49.57 85.67 1,799.06 39.71 619.381,705.06 2,630,904.65 321,255.57 1.37 620.65 MWD+SCC+SAG (1) 2,058.45 49.30 85.57 1,839.38 43.30 666.351,745.38 2,630,907.52 321,302.58 0.45 667.75 MWD+SCC+SAG (1) 2,122.52 48.90 84.55 1,881.33 47.47 714.591,787.33 2,630,910.94 321,350.89 1.36 716.17 MWD+SCC+SAG (1) 2,185.49 48.40 84.57 1,922.93 51.95 761.651,828.93 2,630,914.69 321,398.01 0.79 763.41 MWD+SCC+SAG (1) 2,248.16 47.52 83.09 1,964.90 56.95 807.921,870.90 2,630,918.96 321,444.35 2.25 809.91 MWD+SCC+SAG (1) 2,313.08 46.72 82.71 2,009.08 62.83 855.131,915.08 2,630,924.11 321,491.64 1.30 857.39 MWD+SCC+SAG (1) 2,374.10 46.80 82.15 2,050.88 68.69 899.191,956.88 2,630,929.28 321,535.78 0.68 901.74 MWD+SCC+SAG (1) 2,437.39 46.44 83.56 2,094.35 74.41 944.832,000.35 2,630,934.29 321,581.50 1.72 947.65 MWD+SCC+SAG (1) 2,500.59 45.31 84.42 2,138.35 79.16 989.952,044.35 2,630,938.34 321,626.69 2.04 992.98 MWD+SCC+SAG (1) 2,563.76 45.77 84.91 2,182.60 83.35 1,034.842,088.60 2,630,941.83 321,671.63 0.91 1,038.05 MWD+SCC+SAG (1) 2,627.34 45.94 84.41 2,226.88 87.60 1,080.272,132.88 2,630,945.37 321,717.12 0.62 1,083.65 MWD+SCC+SAG (1) 2,690.09 45.57 84.31 2,270.66 92.02 1,125.002,176.66 2,630,949.09 321,761.91 0.60 1,128.58 MWD+SCC+SAG (1) 2,752.36 45.19 84.30 2,314.40 96.42 1,169.102,220.40 2,630,952.80 321,806.08 0.61 1,172.87 MWD+SCC+SAG (1) 2,814.57 44.59 84.71 2,358.47 100.62 1,212.812,264.47 2,630,956.33 321,849.83 1.07 1,216.75 MWD+SCC+SAG (1) 2,876.80 45.30 84.69 2,402.52 104.68 1,256.582,308.52 2,630,959.71 321,893.66 1.14 1,260.69 MWD+SCC+SAG (1) 2,939.47 45.78 85.08 2,446.41 108.67 1,301.132,352.41 2,630,963.00 321,938.27 0.89 1,305.41 MWD+SCC+SAG (1) 3,002.47 45.83 84.97 2,490.33 112.59 1,346.132,396.33 2,630,966.22 321,983.32 0.15 1,350.57 MWD+SCC+SAG (1) 3,064.42 45.88 85.11 2,533.48 116.43 1,390.422,439.48 2,630,969.37 322,027.66 0.18 1,395.01 MWD+SCC+SAG (1) 3,127.20 45.36 85.21 2,577.38 120.22 1,435.132,483.38 2,630,972.46 322,072.42 0.84 1,439.87 MWD+SCC+SAG (1) 8/6/2012 12:17:48PM COMPASS 2003.16 Build 69 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: ConocoPhillips(Alaska) Inc. Beluga River Beluga River ConocoPhillips (Alaska) Inc. Definitive Survey Report Well: Wellbore: BRU 244-23 BRU 244-23 Survey Calculation Method:Minimum Curvature Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) Design:BRU 244-23 Database:CPAI EDM Production MD Reference:Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) North Reference: Well BRU 244-23 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,191.77 45.32 85.59 2,622.77 123.90 1,480.912,528.77 2,630,975.43 322,118.25 0.42 1,485.79 MWD+SCC+SAG (1) 3,255.01 44.01 85.65 2,667.75 127.29 1,525.232,573.75 2,630,978.14 322,162.62 2.07 1,530.24 MWD+SCC+SAG (1) 3,317.71 44.59 85.30 2,712.62 130.75 1,568.892,618.62 2,630,980.91 322,206.32 1.00 1,574.02 MWD+SCC+SAG (1) 3,368.02 45.14 85.84 2,748.28 133.49 1,604.272,654.28 2,630,983.10 322,241.74 1.33 1,609.51 MWD+SCC+SAG (1) 3,459.37 45.43 84.45 2,812.55 138.99 1,668.952,718.55 2,630,987.59 322,306.49 1.13 1,674.41 MWD+SCC+SAG (2) 3,518.31 45.11 84.25 2,854.03 143.11 1,710.622,760.03 2,630,991.07 322,348.21 0.59 1,716.26 MWD+SCC+SAG (2) 3,586.01 44.69 84.02 2,901.99 147.99 1,758.152,807.99 2,630,995.21 322,395.82 0.67 1,764.01 MWD+SCC+SAG (2) 3,648.47 44.15 84.35 2,946.60 152.42 1,801.652,852.60 2,630,998.96 322,439.37 0.94 1,807.69 MWD+SCC+SAG (2) 3,711.63 43.78 84.15 2,992.06 156.81 1,845.272,898.06 2,631,002.68 322,483.06 0.63 1,851.51 MWD+SCC+SAG (2) 3,772.38 43.51 84.09 3,036.02 161.11 1,886.982,942.02 2,631,006.32 322,524.82 0.45 1,893.41 MWD+SCC+SAG (2) 3,835.68 43.36 84.17 3,081.99 165.56 1,930.272,987.99 2,631,010.10 322,568.18 0.25 1,936.89 MWD+SCC+SAG (2) 3,898.09 43.28 84.50 3,127.39 169.79 1,972.883,033.39 2,631,013.66 322,610.84 0.38 1,979.69 MWD+SCC+SAG (2) 3,963.29 41.28 84.67 3,175.63 173.93 2,016.553,081.63 2,631,017.12 322,654.57 3.07 2,023.53 MWD+SCC+SAG (2) 3,991.40 39.73 84.65 3,197.00 175.63 2,034.723,103.00 2,631,018.54 322,672.77 5.51 2,041.78 MWD+SCC+SAG (2) 4,022.89 38.06 84.30 3,221.51 177.53 2,054.403,127.51 2,631,020.14 322,692.47 5.35 2,061.54 MWD+SCC+SAG (2) 4,055.74 36.75 84.36 3,247.60 179.50 2,074.263,153.60 2,631,021.80 322,712.36 3.99 2,081.48 MWD+SCC+SAG (2) 4,087.49 34.85 84.10 3,273.35 181.37 2,092.743,179.35 2,631,023.38 322,730.86 6.00 2,100.04 MWD+SCC+SAG (2) 4,117.29 34.04 83.75 3,297.93 183.15 2,109.503,203.93 2,631,024.90 322,747.65 2.80 2,116.88 MWD+SCC+SAG (2) 4,151.31 32.22 83.77 3,326.42 185.17 2,127.983,232.42 2,631,026.63 322,766.16 5.35 2,135.45 MWD+SCC+SAG (2) 4,183.81 31.31 83.80 3,354.05 187.02 2,144.993,260.05 2,631,028.22 322,783.19 2.80 2,152.54 MWD+SCC+SAG (2) 4,212.27 30.96 83.76 3,378.41 188.62 2,159.623,284.41 2,631,029.59 322,797.84 1.23 2,167.24 MWD+SCC+SAG (2) 4,277.73 28.02 84.29 3,435.38 191.98 2,191.663,341.38 2,631,032.45 322,829.93 4.51 2,199.44 MWD+SCC+SAG (2) 4,339.47 25.20 84.84 3,490.58 194.60 2,219.193,396.58 2,631,034.64 322,857.49 4.58 2,227.07 MWD+SCC+SAG (2) 4,402.05 22.33 83.48 3,547.84 197.15 2,244.273,453.84 2,631,036.80 322,882.61 4.67 2,252.27 MWD+SCC+SAG (2) 4,461.15 19.94 82.47 3,602.96 199.75 2,265.423,508.96 2,631,039.07 322,903.80 4.09 2,273.54 MWD+SCC+SAG (2) 4,527.35 17.19 82.71 3,665.71 202.47 2,286.323,571.71 2,631,041.46 322,924.74 4.16 2,294.57 MWD+SCC+SAG (2) 4,589.56 14.16 84.42 3,725.60 204.38 2,303.023,631.60 2,631,043.11 322,941.46 4.93 2,311.35 MWD+SCC+SAG (2) 4,652.24 11.53 85.48 3,786.71 205.62 2,316.903,692.71 2,631,044.13 322,955.35 4.21 2,325.28 MWD+SCC+SAG (2) 4,683.80 10.05 84.61 3,817.71 206.12 2,322.783,723.71 2,631,044.55 322,961.25 4.72 2,331.19 MWD+SCC+SAG (2) 4,715.41 8.28 83.50 3,848.92 206.64 2,327.793,754.92 2,631,044.99 322,966.26 5.63 2,336.22 MWD+SCC+SAG (2) 4,747.94 6.60 82.31 3,881.17 207.15 2,331.973,787.17 2,631,045.44 322,970.45 5.19 2,340.42 MWD+SCC+SAG (2) 4,779.29 4.91 84.97 3,912.36 207.51 2,335.093,818.36 2,631,045.75 322,973.58 5.46 2,343.56 MWD+SCC+SAG (2) 4,811.09 3.03 92.31 3,944.08 207.60 2,337.293,850.08 2,631,045.80 322,975.77 6.11 2,345.76 MWD+SCC+SAG (2) 4,841.72 1.57 107.71 3,974.69 207.44 2,338.503,880.69 2,631,045.62 322,976.98 5.13 2,346.95 MWD+SCC+SAG (2) 4,873.62 0.92 173.16 4,006.58 207.05 2,338.943,912.58 2,631,045.23 322,977.42 4.55 2,347.38 MWD+SCC+SAG (2) 4,905.69 0.73 189.45 4,038.65 206.59 2,338.943,944.65 2,631,044.77 322,977.41 0.94 2,347.34 MWD+SCC+SAG (2) 4,969.34 0.85 190.95 4,102.29 205.73 2,338.784,008.29 2,631,043.91 322,977.24 0.19 2,347.13 MWD+SCC+SAG (2) 5,032.69 0.83 180.93 4,165.64 204.81 2,338.694,071.64 2,631,042.99 322,977.13 0.23 2,346.98 MWD+SCC+SAG (2) 5,095.53 0.97 174.64 4,228.47 203.83 2,338.734,134.47 2,631,042.01 322,977.15 0.27 2,346.96 MWD+SCC+SAG (2) 5,157.97 0.88 184.88 4,290.90 202.82 2,338.744,196.90 2,631,041.00 322,977.15 0.30 2,346.90 MWD+SCC+SAG (2) 8/6/2012 12:17:48PM COMPASS 2003.16 Build 69 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: ConocoPhillips(Alaska) Inc. Beluga River Beluga River ConocoPhillips (Alaska) Inc. Definitive Survey Report Well: Wellbore: BRU 244-23 BRU 244-23 Survey Calculation Method:Minimum Curvature Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) Design:BRU 244-23 Database:CPAI EDM Production MD Reference:Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) North Reference: Well BRU 244-23 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 5,220.92 0.93 184.21 4,353.84 201.83 2,338.664,259.84 2,631,040.01 322,977.05 0.08 2,346.76 MWD+SCC+SAG (2) 5,283.02 0.96 180.80 4,415.93 200.81 2,338.614,321.93 2,631,038.99 322,976.99 0.10 2,346.65 MWD+SCC+SAG (2) 5,348.79 0.91 177.32 4,481.70 199.74 2,338.634,387.70 2,631,037.92 322,976.99 0.12 2,346.60 MWD+SCC+SAG (2) 5,411.62 0.97 178.38 4,544.52 198.71 2,338.674,450.52 2,631,036.89 322,977.02 0.10 2,346.57 MWD+SCC+SAG (2) 5,474.04 0.84 192.81 4,606.93 197.73 2,338.584,512.93 2,631,035.91 322,976.91 0.42 2,346.42 MWD+SCC+SAG (2) 5,538.13 0.91 186.10 4,671.01 196.77 2,338.424,577.01 2,631,034.95 322,976.74 0.19 2,346.21 MWD+SCC+SAG (2) 5,600.10 0.93 189.75 4,732.97 195.78 2,338.294,638.97 2,631,033.97 322,976.59 0.10 2,346.01 MWD+SCC+SAG (2) 5,662.49 0.95 180.12 4,795.36 194.77 2,338.204,701.36 2,631,032.96 322,976.49 0.25 2,345.85 MWD+SCC+SAG (2) 5,724.41 0.98 188.35 4,857.27 193.73 2,338.124,763.27 2,631,031.92 322,976.39 0.23 2,345.71 MWD+SCC+SAG (2) 5,786.71 1.04 179.90 4,919.56 192.64 2,338.054,825.56 2,631,030.83 322,976.30 0.26 2,345.56 MWD+SCC+SAG (2) 5,849.89 0.97 172.60 4,982.73 191.53 2,338.124,888.73 2,631,029.72 322,976.35 0.23 2,345.56 MWD+SCC+SAG (2) 5,912.96 0.95 175.61 5,045.79 190.48 2,338.234,951.79 2,631,028.67 322,976.44 0.09 2,345.61 MWD+SCC+SAG (2) 5,977.81 1.04 177.26 5,110.63 189.36 2,338.295,016.63 2,631,027.55 322,976.50 0.15 2,345.60 MWD+SCC+SAG (2) 6,040.45 0.94 175.51 5,173.26 188.28 2,338.365,079.26 2,631,026.47 322,976.55 0.17 2,345.60 MWD+SCC+SAG (2) 6,102.85 0.90 193.14 5,235.65 187.29 2,338.295,141.65 2,631,025.48 322,976.46 0.46 2,345.47 MWD+SCC+SAG (2) 6,166.00 0.83 180.80 5,298.79 186.35 2,338.175,204.79 2,631,024.54 322,976.33 0.31 2,345.29 MWD+SCC+SAG (2) 6,228.49 0.83 179.87 5,361.28 185.44 2,338.175,267.28 2,631,023.64 322,976.31 0.02 2,345.23 MWD+SCC+SAG (2) 6,292.77 1.04 175.99 5,425.55 184.40 2,338.215,331.55 2,631,022.59 322,976.33 0.34 2,345.20 MWD+SCC+SAG (2) 6,355.33 1.06 180.61 5,488.10 183.25 2,338.245,394.10 2,631,021.44 322,976.35 0.14 2,345.16 MWD+SCC+SAG (2) 6,419.27 1.00 190.92 5,552.03 182.11 2,338.135,458.03 2,631,020.31 322,976.22 0.30 2,344.98 MWD+SCC+SAG (2) 6,480.08 1.11 186.42 5,612.83 181.01 2,337.965,518.83 2,631,019.20 322,976.03 0.23 2,344.74 MWD+SCC+SAG (2) 6,543.52 0.95 195.22 5,676.26 179.89 2,337.765,582.26 2,631,018.09 322,975.81 0.35 2,344.46 MWD+SCC+SAG (2) 6,606.01 0.92 190.97 5,738.74 178.90 2,337.525,644.74 2,631,017.10 322,975.56 0.12 2,344.17 MWD+SCC+SAG (2) 6,668.56 0.99 189.04 5,801.28 177.87 2,337.345,707.28 2,631,016.08 322,975.37 0.12 2,343.92 MWD+SCC+SAG (2) 6,731.77 0.90 200.89 5,864.48 176.87 2,337.085,770.48 2,631,015.08 322,975.09 0.34 2,343.60 MWD+SCC+SAG (2) 6,794.48 0.88 194.62 5,927.18 175.94 2,336.785,833.18 2,631,014.16 322,974.78 0.16 2,343.24 MWD+SCC+SAG (2) 6,857.18 1.06 196.55 5,989.88 174.92 2,336.505,895.88 2,631,013.14 322,974.47 0.29 2,342.89 MWD+SCC+SAG (2) 6,921.12 1.02 204.77 6,053.81 173.83 2,336.095,959.81 2,631,012.06 322,974.05 0.24 2,342.42 MWD+SCC+SAG (2) 6,984.25 0.99 203.47 6,116.93 172.82 2,335.646,022.93 2,631,011.06 322,973.58 0.06 2,341.90 MWD+SCC+SAG (2) 7,046.96 1.08 197.22 6,179.63 171.76 2,335.256,085.63 2,631,010.00 322,973.18 0.23 2,341.44 MWD+SCC+SAG (2) 7,110.80 1.06 190.80 6,243.45 170.61 2,334.966,149.45 2,631,008.85 322,972.87 0.19 2,341.08 MWD+SCC+SAG (2) 7,171.45 0.94 194.12 6,304.09 169.57 2,334.736,210.09 2,631,007.82 322,972.63 0.22 2,340.79 MWD+SCC+SAG (2) 7,236.00 1.21 187.11 6,368.63 168.38 2,334.526,274.63 2,631,006.64 322,972.39 0.46 2,340.50 MWD+SCC+SAG (2) 7,297.54 1.22 183.29 6,430.16 167.09 2,334.406,336.16 2,631,005.34 322,972.26 0.13 2,340.30 MWD+SCC+SAG (2) 7,361.72 1.23 187.32 6,494.33 165.72 2,334.276,400.33 2,631,003.98 322,972.11 0.14 2,340.09 MWD+SCC+SAG (2) 7,425.08 1.18 193.40 6,557.67 164.41 2,334.046,463.67 2,631,002.67 322,971.85 0.22 2,339.77 MWD+SCC+SAG (2) 7,486.86 1.19 190.50 6,619.44 163.16 2,333.776,525.44 2,631,001.43 322,971.57 0.10 2,339.42 MWD+SCC+SAG (2) 7,513.83 1.15 192.45 6,646.40 162.62 2,333.666,552.40 2,631,000.89 322,971.45 0.21 2,339.28 MWD+SCC+SAG (2) 7,553.00 1.15 192.45 6,685.56 161.85 2,333.496,591.56 2,631,000.12 322,971.27 0.00 2,339.06 PROJECTED to TD 8/6/2012 12:17:48PM COMPASS 2003.16 Build 69 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: ConocoPhillips (Alaska) Inc. -Expl Beluga River Beluga River ConocoPhillips (Alaska) Inc. Definitive Survey Report Well: Wellbore: BRU 244-23 BRU 244-23 Survey Calculation Method:Minimum Curvature Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) Design:BRU 244-23 Database:CPAI EDM Production MD Reference:Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) North Reference: Well BRU 244-23 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1983 North American Datum 1983 Beluga River, Alaska, USA Alaska Zone 4 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: BRU 244-23 ft ft 0.00 0.00 2,630,635.00 1,460,663.00 75.50Wellhead Elevation:ft0.00 61° 11' 47.357 N 151° 1' 8.496 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) BRU 244-23 Model NameMagnetics BGGM2011 7/14/2012 17.73 74.05 55,700 Phase:Version: Audit Notes: Design BRU 244-23 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (°) +E/-W (ft) Tie On Depth:18.50 86.350.000.0018.50 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 8/6/2012 Survey Date MWD+SCC+SAG MWD + Short Collar correction + BHA SAG C184.66 3,368.02 BRU 244-23 (SAG corrected) (BRU 244-7/24/2012 12:0 MWD+SCC+SAG MWD + Short Collar correction + BHA SAG C3,368.02 7,513.83 BRU 244-23 (SAG corrected) (BRU 244-7/24/2012 12:0 MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 18.50 0.00 0.00 18.50 0.00 0.00-75.50 2,630,635.00 1,460,663.00 0.00 0.00 UNDEFINED 184.66 0.26 223.43 184.66 -0.27 -0.2690.66 2,630,634.73 1,460,662.74 0.16 -0.28 MWD+SCC+SAG (1) 244.26 0.48 232.72 244.26 -0.52 -0.55150.26 2,630,634.49 1,460,662.44 0.38 -0.58 MWD+SCC+SAG (1) 304.93 0.23 261.76 304.93 -0.69 -0.87210.93 2,630,634.32 1,460,662.12 0.50 -0.92 MWD+SCC+SAG (1) 366.19 0.41 240.50 366.19 -0.82 -1.19272.19 2,630,634.20 1,460,661.80 0.35 -1.24 MWD+SCC+SAG (1) 426.18 0.33 241.50 426.17 -1.01 -1.52332.17 2,630,634.02 1,460,661.46 0.13 -1.59 MWD+SCC+SAG (1) 484.91 0.14 201.53 484.90 -1.16 -1.70390.90 2,630,633.87 1,460,661.28 0.41 -1.77 MWD+SCC+SAG (1) 546.11 0.97 84.42 546.10 -1.17 -1.21452.10 2,630,633.84 1,460,661.77 1.70 -1.28 MWD+SCC+SAG (1) 611.06 2.41 90.48 611.02 -1.13 0.70517.02 2,630,633.86 1,460,663.68 2.23 0.63 MWD+SCC+SAG (1) 673.84 4.83 87.11 673.67 -1.01 4.66579.67 2,630,633.92 1,460,667.64 3.87 4.59 MWD+SCC+SAG (1) 737.30 7.74 86.55 736.74 -0.62 11.60642.74 2,630,634.20 1,460,674.59 4.59 11.53 MWD+SCC+SAG (1) 798.90 9.93 86.21 797.61 -0.02 21.04703.61 2,630,634.65 1,460,684.03 3.56 20.99 MWD+SCC+SAG (1) 861.84 10.64 85.76 859.54 0.77 32.25765.54 2,630,635.27 1,460,695.25 1.14 32.23 MWD+SCC+SAG (1) 8/6/2012 12:14:55PM COMPASS 2003.16 Build 69 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: ConocoPhillips (Alaska) Inc. -Expl Beluga River Beluga River ConocoPhillips (Alaska) Inc. Definitive Survey Report Well: Wellbore: BRU 244-23 BRU 244-23 Survey Calculation Method:Minimum Curvature Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) Design:BRU 244-23 Database:CPAI EDM Production MD Reference:Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) North Reference: Well BRU 244-23 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 923.99 12.54 87.45 920.42 1.49 44.71826.42 2,630,635.80 1,460,707.73 3.11 44.72 MWD+SCC+SAG (1) 986.60 15.41 88.73 981.17 1.98 59.82887.17 2,630,636.05 1,460,722.84 4.61 59.83 MWD+SCC+SAG (1) 1,051.00 18.75 88.84 1,042.72 2.38 78.73948.72 2,630,636.15 1,460,741.75 5.19 78.72 MWD+SCC+SAG (1) 1,085.83 19.76 87.90 1,075.60 2.71 90.21981.60 2,630,636.30 1,460,753.24 3.03 90.20 MWD+SCC+SAG (1) 1,111.92 20.47 87.19 1,100.10 3.10 99.171,006.10 2,630,636.55 1,460,762.20 2.88 99.17 MWD+SCC+SAG (1) 1,177.90 22.10 85.74 1,161.58 4.58 123.081,067.58 2,630,637.66 1,460,786.13 2.60 123.12 MWD+SCC+SAG (1) 1,241.26 22.22 88.35 1,220.26 5.81 146.941,126.26 2,630,638.52 1,460,810.00 1.57 147.01 MWD+SCC+SAG (1) 1,305.43 25.27 87.38 1,278.99 6.79 172.751,184.99 2,630,639.10 1,460,835.83 4.79 172.84 MWD+SCC+SAG (1) 1,340.16 27.38 87.48 1,310.12 7.48 188.141,216.12 2,630,639.55 1,460,851.22 6.08 188.23 MWD+SCC+SAG (1) 1,368.08 29.07 87.29 1,334.71 8.08 201.331,240.71 2,630,639.94 1,460,864.42 6.06 201.44 MWD+SCC+SAG (1) 1,400.46 31.64 87.62 1,362.65 8.81 217.681,268.65 2,630,640.41 1,460,880.77 7.95 217.80 MWD+SCC+SAG (1) 1,430.94 34.03 87.75 1,388.26 9.47 234.191,294.26 2,630,640.82 1,460,897.29 7.84 234.32 MWD+SCC+SAG (1) 1,462.15 35.80 87.58 1,413.85 10.20 252.041,319.85 2,630,641.27 1,460,915.15 5.68 252.17 MWD+SCC+SAG (1) 1,493.28 37.34 87.31 1,438.85 11.03 270.561,344.85 2,630,641.81 1,460,933.69 4.97 270.72 MWD+SCC+SAG (1) 1,559.48 39.48 86.23 1,490.72 13.36 311.621,396.72 2,630,643.50 1,460,974.77 3.39 311.84 MWD+SCC+SAG (1) 1,621.29 41.22 84.76 1,537.83 16.51 351.511,443.83 2,630,646.03 1,461,014.71 3.21 351.85 MWD+SCC+SAG (1) 1,682.47 43.35 83.82 1,583.09 20.61 392.471,489.09 2,630,649.49 1,461,055.72 3.63 392.99 MWD+SCC+SAG (1) 1,746.14 46.03 84.90 1,628.35 25.00 437.031,534.35 2,630,653.19 1,461,100.33 4.37 437.73 MWD+SCC+SAG (1) 1,808.62 45.62 85.05 1,671.89 28.93 481.661,577.89 2,630,656.41 1,461,145.03 0.68 482.53 MWD+SCC+SAG (1) 1,871.11 45.80 85.54 1,715.53 32.59 526.251,621.53 2,630,659.39 1,461,189.66 0.63 527.25 MWD+SCC+SAG (1) 1,934.36 48.72 85.66 1,758.45 36.16 572.561,664.45 2,630,662.23 1,461,236.01 4.62 573.70 MWD+SCC+SAG (1) 1,996.44 49.57 85.67 1,799.06 39.71 619.381,705.06 2,630,665.05 1,461,282.88 1.37 620.65 MWD+SCC+SAG (1) 2,058.45 49.30 85.57 1,839.38 43.30 666.351,745.38 2,630,667.91 1,461,329.90 0.45 667.75 MWD+SCC+SAG (1) 2,122.52 48.90 84.55 1,881.33 47.47 714.591,787.33 2,630,671.33 1,461,378.20 1.36 716.17 MWD+SCC+SAG (1) 2,185.49 48.40 84.57 1,922.93 51.95 761.651,828.93 2,630,675.07 1,461,425.32 0.79 763.41 MWD+SCC+SAG (1) 2,248.16 47.52 83.09 1,964.90 56.95 807.921,870.90 2,630,679.35 1,461,471.66 2.25 809.91 MWD+SCC+SAG (1) 2,313.08 46.72 82.71 2,009.08 62.83 855.131,915.08 2,630,684.49 1,461,518.95 1.30 857.39 MWD+SCC+SAG (1) 2,374.10 46.80 82.15 2,050.88 68.69 899.191,956.88 2,630,689.66 1,461,563.10 0.68 901.74 MWD+SCC+SAG (1) 2,437.39 46.44 83.56 2,094.35 74.41 944.832,000.35 2,630,694.67 1,461,608.82 1.72 947.65 MWD+SCC+SAG (1) 2,500.59 45.31 84.42 2,138.35 79.16 989.952,044.35 2,630,698.72 1,461,654.00 2.04 992.98 MWD+SCC+SAG (1) 2,563.76 45.77 84.91 2,182.60 83.35 1,034.842,088.60 2,630,702.21 1,461,698.95 0.91 1,038.05 MWD+SCC+SAG (1) 2,627.34 45.94 84.41 2,226.88 87.60 1,080.272,132.88 2,630,705.75 1,461,744.43 0.62 1,083.65 MWD+SCC+SAG (1) 2,690.09 45.57 84.31 2,270.66 92.02 1,125.002,176.66 2,630,709.47 1,461,789.23 0.60 1,128.58 MWD+SCC+SAG (1) 2,752.36 45.19 84.30 2,314.40 96.42 1,169.102,220.40 2,630,713.18 1,461,833.39 0.61 1,172.87 MWD+SCC+SAG (1) 2,814.57 44.59 84.71 2,358.47 100.62 1,212.812,264.47 2,630,716.70 1,461,877.15 1.07 1,216.75 MWD+SCC+SAG (1) 2,876.80 45.30 84.69 2,402.52 104.68 1,256.582,308.52 2,630,720.08 1,461,920.98 1.14 1,260.69 MWD+SCC+SAG (1) 2,939.47 45.78 85.08 2,446.41 108.67 1,301.132,352.41 2,630,723.37 1,461,965.58 0.89 1,305.41 MWD+SCC+SAG (1) 3,002.47 45.83 84.97 2,490.33 112.59 1,346.132,396.33 2,630,726.59 1,462,010.64 0.15 1,350.57 MWD+SCC+SAG (1) 3,064.42 45.88 85.11 2,533.48 116.43 1,390.422,439.48 2,630,729.74 1,462,054.98 0.18 1,395.01 MWD+SCC+SAG (1) 3,127.20 45.36 85.21 2,577.38 120.22 1,435.132,483.38 2,630,732.83 1,462,099.74 0.84 1,439.87 MWD+SCC+SAG (1) 8/6/2012 12:14:55PM COMPASS 2003.16 Build 69 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: ConocoPhillips (Alaska) Inc. -Expl Beluga River Beluga River ConocoPhillips (Alaska) Inc. Definitive Survey Report Well: Wellbore: BRU 244-23 BRU 244-23 Survey Calculation Method:Minimum Curvature Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) Design:BRU 244-23 Database:CPAI EDM Production MD Reference:Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) North Reference: Well BRU 244-23 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,191.77 45.32 85.59 2,622.77 123.90 1,480.912,528.77 2,630,735.80 1,462,145.56 0.42 1,485.79 MWD+SCC+SAG (1) 3,255.01 44.01 85.65 2,667.75 127.29 1,525.232,573.75 2,630,738.50 1,462,189.93 2.07 1,530.24 MWD+SCC+SAG (1) 3,317.71 44.59 85.30 2,712.62 130.75 1,568.892,618.62 2,630,741.28 1,462,233.63 1.00 1,574.02 MWD+SCC+SAG (1) 3,368.02 45.14 85.84 2,748.28 133.49 1,604.272,654.28 2,630,743.46 1,462,269.05 1.33 1,609.51 MWD+SCC+SAG (1) 3,459.37 45.43 84.45 2,812.55 138.99 1,668.952,718.55 2,630,747.95 1,462,333.81 1.13 1,674.41 MWD+SCC+SAG (2) 3,518.31 45.11 84.25 2,854.03 143.11 1,710.622,760.03 2,630,751.42 1,462,375.53 0.59 1,716.26 MWD+SCC+SAG (2) 3,586.01 44.69 84.02 2,901.99 147.99 1,758.152,807.99 2,630,755.56 1,462,423.14 0.67 1,764.01 MWD+SCC+SAG (2) 3,648.47 44.15 84.35 2,946.60 152.42 1,801.652,852.60 2,630,759.32 1,462,466.69 0.94 1,807.69 MWD+SCC+SAG (2) 3,711.63 43.78 84.15 2,992.06 156.81 1,845.272,898.06 2,630,763.03 1,462,510.37 0.63 1,851.51 MWD+SCC+SAG (2) 3,772.38 43.51 84.09 3,036.02 161.11 1,886.982,942.02 2,630,766.67 1,462,552.14 0.45 1,893.41 MWD+SCC+SAG (2) 3,835.68 43.36 84.17 3,081.99 165.56 1,930.272,987.99 2,630,770.45 1,462,595.50 0.25 1,936.89 MWD+SCC+SAG (2) 3,898.09 43.28 84.50 3,127.39 169.79 1,972.883,033.39 2,630,774.01 1,462,638.16 0.38 1,979.69 MWD+SCC+SAG (2) 3,963.29 41.28 84.67 3,175.63 173.93 2,016.553,081.63 2,630,777.47 1,462,681.88 3.07 2,023.53 MWD+SCC+SAG (2) 3,991.40 39.73 84.65 3,197.00 175.63 2,034.723,103.00 2,630,778.88 1,462,700.09 5.51 2,041.78 MWD+SCC+SAG (2) 4,022.89 38.06 84.30 3,221.51 177.53 2,054.403,127.51 2,630,780.48 1,462,719.79 5.35 2,061.54 MWD+SCC+SAG (2) 4,055.74 36.75 84.36 3,247.60 179.50 2,074.263,153.60 2,630,782.14 1,462,739.68 3.99 2,081.48 MWD+SCC+SAG (2) 4,087.49 34.85 84.10 3,273.35 181.37 2,092.743,179.35 2,630,783.72 1,462,758.18 6.00 2,100.04 MWD+SCC+SAG (2) 4,117.29 34.04 83.75 3,297.93 183.15 2,109.503,203.93 2,630,785.24 1,462,774.96 2.80 2,116.88 MWD+SCC+SAG (2) 4,151.31 32.22 83.77 3,326.42 185.17 2,127.983,232.42 2,630,786.97 1,462,793.47 5.35 2,135.45 MWD+SCC+SAG (2) 4,183.81 31.31 83.80 3,354.05 187.02 2,144.993,260.05 2,630,788.56 1,462,810.51 2.80 2,152.54 MWD+SCC+SAG (2) 4,212.27 30.96 83.76 3,378.41 188.62 2,159.623,284.41 2,630,789.93 1,462,825.16 1.23 2,167.24 MWD+SCC+SAG (2) 4,277.73 28.02 84.29 3,435.38 191.98 2,191.663,341.38 2,630,792.79 1,462,857.25 4.51 2,199.44 MWD+SCC+SAG (2) 4,339.47 25.20 84.84 3,490.58 194.60 2,219.193,396.58 2,630,794.98 1,462,884.81 4.58 2,227.07 MWD+SCC+SAG (2) 4,402.05 22.33 83.48 3,547.84 197.15 2,244.273,453.84 2,630,797.14 1,462,909.93 4.67 2,252.27 MWD+SCC+SAG (2) 4,461.15 19.94 82.47 3,602.96 199.75 2,265.423,508.96 2,630,799.41 1,462,931.12 4.09 2,273.54 MWD+SCC+SAG (2) 4,527.35 17.19 82.71 3,665.71 202.47 2,286.323,571.71 2,630,801.80 1,462,952.05 4.16 2,294.57 MWD+SCC+SAG (2) 4,589.56 14.16 84.42 3,725.60 204.38 2,303.023,631.60 2,630,803.45 1,462,968.78 4.93 2,311.35 MWD+SCC+SAG (2) 4,652.24 11.53 85.48 3,786.71 205.62 2,316.903,692.71 2,630,804.47 1,462,982.67 4.21 2,325.28 MWD+SCC+SAG (2) 4,683.80 10.05 84.61 3,817.71 206.12 2,322.783,723.71 2,630,804.89 1,462,988.56 4.72 2,331.19 MWD+SCC+SAG (2) 4,715.41 8.28 83.50 3,848.92 206.64 2,327.793,754.92 2,630,805.32 1,462,993.58 5.63 2,336.22 MWD+SCC+SAG (2) 4,747.94 6.60 82.31 3,881.17 207.15 2,331.973,787.17 2,630,805.77 1,462,997.77 5.19 2,340.42 MWD+SCC+SAG (2) 4,779.29 4.91 84.97 3,912.36 207.51 2,335.093,818.36 2,630,806.08 1,463,000.89 5.46 2,343.56 MWD+SCC+SAG (2) 4,811.09 3.03 92.31 3,944.08 207.60 2,337.293,850.08 2,630,806.14 1,463,003.09 6.11 2,345.76 MWD+SCC+SAG (2) 4,841.72 1.57 107.71 3,974.69 207.44 2,338.503,880.69 2,630,805.96 1,463,004.30 5.13 2,346.95 MWD+SCC+SAG (2) 4,873.62 0.92 173.16 4,006.58 207.05 2,338.943,912.58 2,630,805.56 1,463,004.74 4.55 2,347.38 MWD+SCC+SAG (2) 4,905.69 0.73 189.45 4,038.65 206.59 2,338.943,944.65 2,630,805.11 1,463,004.73 0.94 2,347.34 MWD+SCC+SAG (2) 4,969.34 0.85 190.95 4,102.29 205.73 2,338.784,008.29 2,630,804.24 1,463,004.56 0.19 2,347.13 MWD+SCC+SAG (2) 5,032.69 0.83 180.93 4,165.64 204.81 2,338.694,071.64 2,630,803.33 1,463,004.45 0.23 2,346.98 MWD+SCC+SAG (2) 5,095.53 0.97 174.64 4,228.47 203.83 2,338.734,134.47 2,630,802.34 1,463,004.47 0.27 2,346.96 MWD+SCC+SAG (2) 5,157.97 0.88 184.88 4,290.90 202.82 2,338.744,196.90 2,630,801.34 1,463,004.47 0.30 2,346.90 MWD+SCC+SAG (2) 8/6/2012 12:14:55PM COMPASS 2003.16 Build 69 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: ConocoPhillips (Alaska) Inc. -Expl Beluga River Beluga River ConocoPhillips (Alaska) Inc. Definitive Survey Report Well: Wellbore: BRU 244-23 BRU 244-23 Survey Calculation Method:Minimum Curvature Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) Design:BRU 244-23 Database:CPAI EDM Production MD Reference:Rig: 75.5+18.5 @ 94.00ft (Arctic Fox) North Reference: Well BRU 244-23 True MD (ft) Inc (°) Azi (°) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 5,220.92 0.93 184.21 4,353.84 201.83 2,338.664,259.84 2,630,800.35 1,463,004.37 0.08 2,346.76 MWD+SCC+SAG (2) 5,283.02 0.96 180.80 4,415.93 200.81 2,338.614,321.93 2,630,799.33 1,463,004.31 0.10 2,346.65 MWD+SCC+SAG (2) 5,348.79 0.91 177.32 4,481.70 199.74 2,338.634,387.70 2,630,798.25 1,463,004.31 0.12 2,346.60 MWD+SCC+SAG (2) 5,411.62 0.97 178.38 4,544.52 198.71 2,338.674,450.52 2,630,797.22 1,463,004.33 0.10 2,346.57 MWD+SCC+SAG (2) 5,474.04 0.84 192.81 4,606.93 197.73 2,338.584,512.93 2,630,796.25 1,463,004.23 0.42 2,346.42 MWD+SCC+SAG (2) 5,538.13 0.91 186.10 4,671.01 196.77 2,338.424,577.01 2,630,795.29 1,463,004.06 0.19 2,346.21 MWD+SCC+SAG (2) 5,600.10 0.93 189.75 4,732.97 195.78 2,338.294,638.97 2,630,794.31 1,463,003.91 0.10 2,346.01 MWD+SCC+SAG (2) 5,662.49 0.95 180.12 4,795.36 194.77 2,338.204,701.36 2,630,793.29 1,463,003.80 0.25 2,345.85 MWD+SCC+SAG (2) 5,724.41 0.98 188.35 4,857.27 193.73 2,338.124,763.27 2,630,792.26 1,463,003.71 0.23 2,345.71 MWD+SCC+SAG (2) 5,786.71 1.04 179.90 4,919.56 192.64 2,338.054,825.56 2,630,791.16 1,463,003.62 0.26 2,345.56 MWD+SCC+SAG (2) 5,849.89 0.97 172.60 4,982.73 191.53 2,338.124,888.73 2,630,790.06 1,463,003.67 0.23 2,345.56 MWD+SCC+SAG (2) 5,912.96 0.95 175.61 5,045.79 190.48 2,338.234,951.79 2,630,789.01 1,463,003.76 0.09 2,345.61 MWD+SCC+SAG (2) 5,977.81 1.04 177.26 5,110.63 189.36 2,338.295,016.63 2,630,787.88 1,463,003.81 0.15 2,345.60 MWD+SCC+SAG (2) 6,040.45 0.94 175.51 5,173.26 188.28 2,338.365,079.26 2,630,786.80 1,463,003.86 0.17 2,345.60 MWD+SCC+SAG (2) 6,102.85 0.90 193.14 5,235.65 187.29 2,338.295,141.65 2,630,785.82 1,463,003.78 0.46 2,345.47 MWD+SCC+SAG (2) 6,166.00 0.83 180.80 5,298.79 186.35 2,338.175,204.79 2,630,784.88 1,463,003.64 0.31 2,345.29 MWD+SCC+SAG (2) 6,228.49 0.83 179.87 5,361.28 185.44 2,338.175,267.28 2,630,783.97 1,463,003.62 0.02 2,345.23 MWD+SCC+SAG (2) 6,292.77 1.04 175.99 5,425.55 184.40 2,338.215,331.55 2,630,782.92 1,463,003.65 0.34 2,345.20 MWD+SCC+SAG (2) 6,355.33 1.06 180.61 5,488.10 183.25 2,338.245,394.10 2,630,781.78 1,463,003.67 0.14 2,345.16 MWD+SCC+SAG (2) 6,419.27 1.00 190.92 5,552.03 182.11 2,338.135,458.03 2,630,780.64 1,463,003.54 0.30 2,344.98 MWD+SCC+SAG (2) 6,480.08 1.11 186.42 5,612.83 181.01 2,337.965,518.83 2,630,779.54 1,463,003.35 0.23 2,344.74 MWD+SCC+SAG (2) 6,543.52 0.95 195.22 5,676.26 179.89 2,337.765,582.26 2,630,778.42 1,463,003.13 0.35 2,344.46 MWD+SCC+SAG (2) 6,606.01 0.92 190.97 5,738.74 178.90 2,337.525,644.74 2,630,777.43 1,463,002.88 0.12 2,344.17 MWD+SCC+SAG (2) 6,668.56 0.99 189.04 5,801.28 177.87 2,337.345,707.28 2,630,776.41 1,463,002.68 0.12 2,343.92 MWD+SCC+SAG (2) 6,731.77 0.90 200.89 5,864.48 176.87 2,337.085,770.48 2,630,775.41 1,463,002.41 0.34 2,343.60 MWD+SCC+SAG (2) 6,794.48 0.88 194.62 5,927.18 175.94 2,336.785,833.18 2,630,774.49 1,463,002.09 0.16 2,343.24 MWD+SCC+SAG (2) 6,857.18 1.06 196.55 5,989.88 174.92 2,336.505,895.88 2,630,773.47 1,463,001.79 0.29 2,342.89 MWD+SCC+SAG (2) 6,921.12 1.02 204.77 6,053.81 173.83 2,336.095,959.81 2,630,772.40 1,463,001.37 0.24 2,342.42 MWD+SCC+SAG (2) 6,984.25 0.99 203.47 6,116.93 172.82 2,335.646,022.93 2,630,771.39 1,463,000.90 0.06 2,341.90 MWD+SCC+SAG (2) 7,046.96 1.08 197.22 6,179.63 171.76 2,335.256,085.63 2,630,770.34 1,463,000.49 0.23 2,341.44 MWD+SCC+SAG (2) 7,110.80 1.06 190.80 6,243.45 170.61 2,334.966,149.45 2,630,769.19 1,463,000.19 0.19 2,341.08 MWD+SCC+SAG (2) 7,171.45 0.94 194.12 6,304.09 169.57 2,334.736,210.09 2,630,768.16 1,462,999.94 0.22 2,340.79 MWD+SCC+SAG (2) 7,236.00 1.21 187.11 6,368.63 168.38 2,334.526,274.63 2,630,766.97 1,462,999.71 0.46 2,340.50 MWD+SCC+SAG (2) 7,297.54 1.22 183.29 6,430.16 167.09 2,334.406,336.16 2,630,765.68 1,462,999.57 0.13 2,340.30 MWD+SCC+SAG (2) 7,361.72 1.23 187.32 6,494.33 165.72 2,334.276,400.33 2,630,764.31 1,462,999.42 0.14 2,340.09 MWD+SCC+SAG (2) 7,425.08 1.18 193.40 6,557.67 164.41 2,334.046,463.67 2,630,763.01 1,462,999.17 0.22 2,339.77 MWD+SCC+SAG (2) 7,486.86 1.19 190.50 6,619.44 163.16 2,333.776,525.44 2,630,761.76 1,462,998.88 0.10 2,339.42 MWD+SCC+SAG (2) 7,513.83 1.15 192.45 6,646.40 162.62 2,333.666,552.40 2,630,761.22 1,462,998.77 0.21 2,339.28 MWD+SCC+SAG (2) 7,553.00 1.15 192.45 6,685.56 161.85 2,333.496,591.56 2,630,760.46 1,462,998.58 0.00 2,339.06 PROJECTED to TD 8/6/2012 12:14:55PM COMPASS 2003.16 Build 69 Page 5 3000 4000 5000 6000 7000 8000 0 4 8 12 16 20 Me a s u r e d D e p t h Rig Days BRU 244-23 Days vs. Depth Start 8.75" Production 3435' MD / 2795.4' TVD 09:50 24 July 2012 Begin Wireline Logging Sperry SDL Released4 August 2012 20 July 2012 Sperry SDL Arrives on Location Run & Land 7" Casing TD Production Section 7553' MD \ 6685.6' TVD 19:40 on 27 July 2012 Surface Data Logging After Action Review Employee Name: Emil Opitz Date: 28 July 2012 Well: BRU 244-23 Hole Section: Production What went as, or better than, planned: Overall, doing a much better job than the previous well. Catching samples at the proper times, maintaining the gas detection and monitoring equipment, communicating with the rig crew. Restoring faith in the customer that we are capable of doing the job. Difficulties experienced: Setting up the network and connecting to MWD as the job began; a major issue was the inability to record/display data for the 1st 100' out of shoe, due to the networking issue - which was later figured out, at least in part. Air compressor died during drilling. Recommendations: Networking issue arose because we were using two IRIS computers; one in the MWD unit and one in the SDL unit. MWD needed the IRIS for depth tracking, and SDL needed it for all other functions. The problems arose when the two IRIS computers were assigned to the same data. Quickly found a fix for this issue and no other problems arose. Innovations and/or cost savings: None for this section.